10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C.

FORM 10-Q

QUARTERLY REPORT

For the Quarterly Period Ended March 31, 2015

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

(Mark One)

[ X ]	QUARTERLY REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Quarter Ended March 31, 2015
	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	Registrant, Address and Telephone Number	State of Incorporation	I.R.S. Employer Identification Number
1-16681	The Laclede Group, Inc. 700 Market Street St. Louis, MO 63101 Telephone Number 314-342-0500	Missouri	74-2976504
1-1822	Laclede Gas Company 700 Market Street St. Louis, MO 63101 Telephone Number 314-342-0500	Missouri	43-0368139
2-38960	Alabama Gas Corporation 2101 6th Avenue North Birmingham, Alabama 35203-8100 Telephone Number 205-326-8100	Alabama	63-0022000

Indicate by check mark whether each 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.

The Laclede Group, Inc.Yes [ X ]No [ ]

Laclede Gas CompanyYes [ X ]No [ ]

Alabama Gas CorporationYes [ X ]No [ ]

Indicate by check mark whether each registrant 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).

The Laclede Group, Inc.Yes [ X ]No [ ]

Laclede Gas CompanyYes [ X ]No [ ]

Alabama Gas CorporationYes [ X ]No [ ]

Indicate by check mark whether the registrant 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	Accelerated filer	Non- accelerated filer	Smaller reporting company
The Laclede Group, Inc.	X
Laclede Gas Company			X
Alabama Gas Corporation			X

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

The Laclede Group, Inc.Yes [ ]No [ X ]

Laclede Gas CompanyYes [ ]No [ X ]

Alabama Gas CorporationYes [ ]No [ X ]

The number of shares outstanding of each registrant’s common stock as of April 30, 2015 was as follows:

The Laclede Group, Inc.	Common Stock, par value $1.00 per share	43,318,933
Laclede Gas Company	Common Stock, par value $1.00 per share (all owned by The Laclede Group, Inc.)	24,577
Alabama Gas Corporation	Common Stock, par value $0.01 per share (all owned by the Laclede Group, Inc.)	1,972,052

Laclede Gas Company and Alabama Gas Corporation meet the conditions set forth in General Instructions H(1)(a) and (b) to Form 10-Q and are therefore filing this Form 10-Q with the reduced disclosure format specified in General Instructions H(2) to Form 10-Q.

This combined Form 10-Q represents separate filings by The Laclede Group, Inc., Laclede Gas Company and Alabama Gas Corporation. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants, except that information relating to Laclede Gas Company and Alabama Gas Corporation are also attributed to The Laclede Group, Inc.

TABLE OF CONTENTS			Page No.
PART I. FINANCIAL INFORMATION
GLOSSARY			4
Item 1	Financial Statements (Unaudited):
	The Laclede Group, Inc.
		Condensed Consolidated Statements of Income	6
		Consolidated Statements of Comprehensive Income	7
		Condensed Consolidated Balance Sheets	8
		Consolidated Statements of Common Shareholders' Equity	10
		Condensed Consolidated Statements of Cash Flows	11
	Laclede Gas Company
		Condensed Statements of Income	12
		Statements of Comprehensive Income	13
		Condensed Balance Sheets	14
		Statements of Common Shareholder's Equity	16
		Condensed Statements of Cash Flows	17
	Alabama Gas Corporation
		Condensed Statements of Income	18
		Condensed Balance Sheets	19
		Statements of Common Shareholder's Equity	21
		Condensed Statements of Cash Flows	22
	Notes to the Financial Statements		23
		Note 1. Summary of Significant Accounting Policies	23
		Note 2. Acquisitions	25
		Note 3. Earnings Per Common Share	26
		Note 4. Regulatory Matters	26
		Note 5. Fair Value of Financial Instruments	28
		Note 6. Fair Value Measurements	29
		Note 7. Concentrations of Credit Risk	32
		Note 8. Pension Plans and Other Postretirement Benefits	32
		Note 9. Information by Operating Segment	35
		Note 10. Commitments and Contingencies	38
Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations		41
Item 3	Quantitative and Qualitative Disclosures About Market Risk		61
Item 4	Controls and Procedures		62
PART II. OTHER INFORMATION
Item 1	Legal Proceedings		63
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds		63
Item 6	Exhibits		63
SIGNATURES			64
INDEX TO EXHIBITS			65

3

GLOSSARY OF KEY TERMS

Alagasco	Alabama Gas Corporation or Alabama Utility	ISRS	Infrastructure System Replacement Surcharge
Alabama Utility	Alabama Gas Corporation or Alagasco; the utility serving the Alabama region	LER	Laclede Energy Resources, Inc.
AOC	Administrative Order on Consent	MDNR	Missouri Department of Natural Resources
APSC	Alabama Public Service Commission	MGE	Missouri Gas Energy
ASC	Accounting Standards Codification	MGP	Manufactured Gas Plant
APUC	Algonquin Power and Utilities Corp.	Missouri Utilities	Laclede Gas Company, including MGE; the utilities serving the Missouri region
Bcf	Billion cubic feet	MMBtu	Million British thermal unit
BVCP	Brownfields/Voluntary Cleanup Program	MoPSC	Missouri Public Service Commission or MPSC
CCM	Cost Control Mechanism	NCP	National Oil and Hazardous Substances Pollution Contingency Plan
CERCLA	Comprehensive Environment Response, Compensation and Liability Act	NEG	New England Gas Company
Energen	Energen Corporation	NPL	National Priorities List
EPA	US Environmental Protection Agency	NSR	Negative Salvage Refund
ESR	Enhanced Stability Reserve	NYMEX	New York Mercantile Exchange, Inc.
ETE	Energy Transfers Equity, LP	O&M	Operations and Maintenance
FASB	Financial Accounting Standards Board	OTCBB	Over-the-Counter Bulletin Board
FERC	Federal Energy Regulatory Commission	PGA	Purchased Gas Adjustment
GAAP	Accounting principles generally accepted in the United States of America	PRP	Potential Responsible Party
Gas Utility	Operating segment including the regulated operations of Laclede Gas Company and Alabama Gas Corporation	RSE	Rate Stabilization and Equalization
Gas Marketing	Operating segment including Laclede Energy Resources (LER), a subsidiary engaged in the non-regulated marketing of natural gas and related activities	SEC	US Securities and Exchange Commission
GSA	Gas Supply Adjustment	SPA	Stock Purchase Agreement with Energen to purchase 100% of the common shares of Alabama Gas Corporation (Alagasco)
ICE	ICE Clear Europe	Spire	Laclede Group's compressed natural gas fueling solutions business
Index Range	Range of Alagasco's CCM, which is 2007 rate year O&M expense (Base Year) inflation-adjusted using the June Consumer Price Index for All Urban Consumers plus or minus 1.75%	US	United States

4

PART I. FINANCIAL INFORMATION

The interim financial statements included herein have been prepared by three separate registrants — The Laclede Group, Inc. (Laclede Group or the Company), Laclede Gas Company (Laclede Gas or Missouri Utilities) and Alabama Gas Corporation (Alagasco or Alabama Utility) — 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 each registrant's respective Form 10-K for the fiscal year or transition period, as applicable, ended September 30, 2014.

The Financial Information in this Part I includes separate financial statements (i.e., balance sheets, statements of income and comprehensive income, statements of common shareholders' equity and statements of cash flows) for Laclede Group, Laclede Gas and Alagasco. The notes to the financial statements and Management's Discussion and Analysis of Financial Condition and Results of Operations are also included and presented herein on a combined basis for the Laclede Group, Laclede Gas and Alagasco.

5

Item 1. Financial Statements

THE LACLEDE GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended   March 31,					Six Months Ended   March 31,
($ Millions, Except Per Share Amounts)	2015		2014			2015		2014
Operating Revenues:
Gas utility	$	847.0	$	634.4		$	1,428.4	$	1,069.6
Gas marketing and other	30.4		60.1			68.6		93.5
Total Operating Revenues	877.4		694.5			1,497.0		1,163.1
Operating Expenses:
Gas utility
Natural and propane gas	482.8		405.3			787.1		647.1
Other operation and maintenance expenses	103.8		72.0			200.9		134.3
Depreciation and amortization	32.2		20.1			64.2		40.1
Taxes, other than income taxes	55.7		41.8			93.7		70.4
Total Gas Utility Operating Expenses	674.5		539.2			1,145.9		891.9
Gas marketing and other	45.2		68.1			106.1		121.1
Total Operating Expenses	719.7		607.3			1,252.0		1,013.0
Operating Income	157.7		87.2			245.0		150.1
Other Income – Net	0.7		(0.3		)	2.1		1.4
Interest Charges:
Interest on long-term debt	16.5		8.6			33.7		18.3
Other interest charges	2.6		0.7			4.6		1.5
Total Interest Charges	19.1		9.3			38.3		19.8
Income Before Income Taxes	139.3		77.6			208.8		131.7
Income Tax Expense	44.9		25.4			67.3		43.9
Net Income	$	94.4	$	52.2		$	141.5	$	87.8
Weighted Average Number of Common Shares Outstanding:
Basic	43.1		32.6			43.1		32.6
Diluted	43.2		32.6			43.2		32.7
Basic Earnings Per Share of Common Stock	$	2.18	$	1.59		$	3.27	$	2.68
Diluted Earnings Per Share of Common Stock	$	2.18	$	1.59		$	3.26	$	2.68
Dividends Declared Per Share of Common Stock	$	0.46	$	0.44		$	0.92	$	0.88
See the accompanying Notes to the Financial Statements.

6

THE LACLEDE GROUP, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Net Income	$	94.4		$	52.2		$	141.5		$	87.8
Other Comprehensive Income (Loss), Before Tax:
Cash flow hedging derivative instruments:
Net hedging loss arising during the period	(0.6		)	(3.5		)	(6.5		)	(5.1		)
Reclassification adjustment for losses included in net income	2.3			3.2			2.2			2.0
Net unrealized gains (losses) on cash flow hedging derivative instruments	1.7			(0.3		)	(4.3		)	(3.1		)
Defined benefit pension and other postretirement plans:
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	0.1			0.1			0.2			0.2
Other Comprehensive Income (Loss), Before Tax	1.8			(0.2		)	(4.1		)	(2.9		)
Income Tax Expense (Benefit) Related to Items of Other Comprehensive Income	0.6			(0.1		)	(1.6		)	(1.1		)
Other Comprehensive Income (Loss), Net of Tax	1.2			(0.1		)	(2.5		)	(1.8		)
Comprehensive Income	$	95.6		$	52.1		$	139.0		$	86.0
See the accompanying Notes to the Financial Statements.

7

THE LACLEDE GROUP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

	March 31,			September 30,
($ Millions, Except Per Share Amounts)	2015			2014
ASSETS
Utility Plant	$	4,037.8		$	3,928.3
Less: Accumulated depreciation and amortization	1,213.1			1,168.6
Net Utility Plant	2,824.7			2,759.7
Non-utility Property (net of accumulated depreciation and amortization, $7.2 and $6.7 at March 31, 2015 and September 30, 2014, respectively)	10.5			9.2
Goodwill	946.0			937.8
Other investments	60.8			60.0
Total Other Property and Investments	1,017.3			1,007.0
Current Assets:
Cash and cash equivalents	46.9			16.1
Accounts receivable:
Utility	303.8			148.2
Other	70.1			86.5
Allowance for doubtful accounts	(18.6		)	(15.9		)
Delayed customer billings	61.7			10.8
Inventories:
Natural gas	90.8			245.5
Propane gas	11.9			11.7
Materials and supplies	14.3			13.0
Natural gas receivable	5.9			7.3
Derivative instrument assets	3.0			2.4
Unamortized purchased gas adjustments	—			54.0
Regulatory assets	27.4			26.8
Prepayments and other	20.0			21.6
Total Current Assets	637.2			628.0
Deferred Charges:
Regulatory assets	632.9			614.3
Other	68.6			65.0
Total Deferred Charges	701.5			679.3
Total Assets	$	5,180.7		$	5,074.0

8

THE LACLEDE GROUP, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS (Continued)

(UNAUDITED)

	March 31,			September 30,
	2015			2014
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock (par value $1.00 per share; 70.0 million shares authorized; 43.3 million and 43.2 million shares issued and outstanding, at March 31, 2015 and September 30, 2014, respectively)	$	43.3		$	43.2
Paid-in capital	1,033.3			1,029.4
Retained earnings	539.2			437.5
Accumulated other comprehensive loss	(4.2		)	(1.7		)
Total Common Stock Equity	1,611.6			1,508.4
Long-term debt (less current portion)	1,736.3			1,851.0
Total Capitalization	3,347.9			3,359.4
Current Liabilities:
Current portion of long-term debt	80.0			—
Notes payable	247.6			287.1
Accounts payable	160.1			176.7
Advance customer billings	8.4			32.2
Wages and compensation accrued	30.9			36.0
Dividends payable	20.5			19.9
Customer deposits	36.2			34.0
Interest accrued	14.9			15.1
Unamortized purchased gas adjustments	76.7			22.4
Taxes accrued	85.2			63.4
Deferred income taxes	—			9.9
Regulatory liabilities	38.5			41.3
Other	54.7			47.8
Total Current Liabilities	853.7			785.8
Deferred Credits and Other Liabilities:
Deferred income taxes	438.7			383.8
Pension and postretirement benefit costs	243.9			244.9
Asset retirement obligations	101.5			99.2
Regulatory liabilities	114.3			125.8
Other	80.7			75.1
Total Deferred Credits and Other Liabilities	979.1			928.8
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$	5,180.7		$	5,074.0
See the accompanying Notes to the Financial Statements.

9

THE LACLEDE GROUP, INC.

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

(UNAUDITED)

	Common Stock Issued			Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Loss
($ Millions, Except Per Share Amounts)	Shares	Amount											Total
BALANCE SEPTEMBER 30, 2013	32,696,836	$	32.7	$	594.3		$	420.1		$	(0.8	)	$	1,046.3
Net income	—	—		—			87.8			—			87.8
Dividend reinvestment plan	15,994	—		0.7			—			—			0.7
Stock-based compensation costs		—		2.4			—			—			2.4
Equity Incentive Plan	63,765	0.1		0.6			—			—			0.7
Employees’ taxes paid associated with restricted shares withheld upon vesting	—	—		(1.1		)	—			—			(1.1		)
Tax benefit – stock compensation	—	—		0.5			—			—			0.5
Dividends declared	—	—					(28.9		)	—			(28.9		)
Other comprehensive loss, net of tax	—	—		—			—			(1.8		)	(1.8		)
BALANCE MARCH 31, 2014	32,776,595	$	32.8	$	597.4		$	479.0		$	(2.6	)	$	1,106.6
BALANCE SEPTEMBER 30, 2014	43,178,405	$	43.2	$	1,029.4		$	437.5		$	(1.7	)	$	1,508.4
Net income	—	—		—			141.5			—			141.5
Dividend reinvestment plan	9,494	—		0.9			—			—			0.9
Stock-based compensation costs	—	—		(0.4		)	—			—			(0.4		)
Equity Incentive Plan	125,949	0.1		2.8			—			—			2.9
Tax benefit – stock compensation	—	—		0.6			—			—			0.6
Dividends declared	—	—					(39.8		)				(39.8		)
Other comprehensive loss, net of tax	—	—		—			—			(2.5		)	(2.5		)
BALANCE MARCH 31, 2015	43,313,848	$	43.3	$	1,033.3		$	539.2		$	(4.2	)	$	1,611.6
See the accompanying Notes to the Financial Statements.

10

THE LACLEDE GROUP, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED) 

	Six Months Ended   March 31,
($ Millions)	2015			2014
Operating Activities:
Net Income	$	141.5		$	87.8
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	64.7			40.5
Changes in assets and liabilities:
Accounts receivable	(139.4		)	(211.7		)
Unamortized purchased gas adjustments	108.2			15.9
Deferred purchased gas costs	(14.3		)	27.8
Accounts payable	(12.1		)	79.4
Delayed/advance customer billings – net	(74.7		)	(53.4		)
Taxes accrued	21.5			38.1
Inventories	153.1			114.2
Other assets and liabilities	(2.1		)	(1.3		)
Other	33.5			5.5
Net cash provided by operating activities	279.9			142.8
Investing Activities:
Capital expenditures	(129.5		)	(68.2		)
Proceeds from sale of right to acquire New England Gas Company	—			11.0
(Payments for) proceeds from final reconciliation of acquisitions	(8.6		)	23.9
Other	(0.4		)	(5.1		)
Net cash used in investing activities	(138.5		)	(38.4		)
Financing Activities:
Redemption and maturity of long-term debt	(34.7		)	(80.0		)
Repayment of short-term debt – net	(39.6		)	(38.0		)
Issuance of common stock	2.8			1.4
Dividends paid	(39.2		)	(28.5		)
Employees’ taxes paid associated with restricted shares withheld upon vesting	(1.6		)	(1.1		)
Other	1.7			(0.3		)
Net cash used in financing activities	(110.6		)	(146.5		)
Net Increase (Decrease) in Cash and Cash Equivalents	30.8			(42.1		)
Cash and Cash Equivalents at Beginning of Period	16.1			53.0
Cash and Cash Equivalents at End of Period	$	46.9		$	10.9
Supplemental disclosure of cash flow information:
Interest paid	$	(36.1	)	$	(19.7	)
Income taxes refunded	0.3			2.6
See the accompanying Notes to the Financial Statements.

11

LACLEDE GAS COMPANY

CONDENSED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended   March 31,					Six Months Ended   March 31,
($ Millions)	2015		2014			2015		2014
Operating Revenues:
Utility	$	615.7	$	638.7		$	1,078.1	$	1,073.9
Other	—		0.1			—		0.1
Total Operating Revenues	615.7		638.8			1,078.1		1,074.0
Operating Expenses:
Utility
Natural and propane gas	402.7		430.5			686.1		692.1
Other operation and maintenance expenses	69.6		72.2			134.4		134.7
Depreciation and amortization	20.5		20.1			40.7		40.1
Taxes, other than income taxes	42.3		41.8			71.5		70.4
Total Utility Operating Expenses	535.1		564.6			932.7		937.3
Other	—		(0.3		)	—		(0.1		)
Total Operating Expenses	535.1		564.3			932.7		937.2
Operating Income	80.6		74.5			145.4		136.8
Other Income – Net	0.4		(0.7		)	1.3		1.0
Interest Charges:
Interest on long-term debt	8.3		8.4			16.6		17.9
Other interest charges	1.2		0.7			2.2		1.5
Total Interest Charges	9.5		9.1			18.8		19.4
Income Before Income Taxes	71.5		64.7			127.9		118.4
Income Tax Expense	21.6		20.5			39.0		38.9
Net Income	$	49.9	$	44.2		$	88.9	$	79.5
See the accompanying Notes to the Financial Statements.

12

LACLEDE GAS COMPANY

STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015			2014
Net Income	$	49.9	$	44.2	$	88.9		$	79.5
Other Comprehensive Income (Loss), Before Tax:
Net gains (losses) on cash flow hedging derivative instruments:
Net hedging gains (losses) arising during the period	0.1		0.1		(1.3		)	0.1
Reclassification adjustment for losses (gains) included in net income	0.3		—		0.4			(0.1		)
Net unrealized gains (losses) on cash flow hedging derivative instruments	0.4		0.1		(0.9		)	—
Defined benefit pension and other postretirement plans:
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	—		0.1		0.1			0.2
Other Comprehensive Income (Loss), Before Tax	0.4		0.2		(0.8		)	0.2
Income Tax Expense (Benefit) Related to Items of Other Comprehensive Income	0.1		0.1		(0.3		)	0.1
Other Comprehensive Income (Loss), Net of Tax	0.3		0.1		(0.5		)	0.1
Comprehensive Income	$	50.2	$	44.3	$	88.4		$	79.6
See the accompanying Notes to the Financial Statements.

13

LACLEDE GAS COMPANY

CONDENSED BALANCE SHEETS

(UNAUDITED)

	March 31,			September 30,
($ Millions, Except Shares and Per Share Amounts)	2015			2014
ASSETS
Utility Plant	$	2,479.8		$	2,403.3
Less: Accumulated depreciation and amortization	566.2			542.3
Net Utility Plant	1,913.6			1,861.0
Goodwill	210.2			210.2
Other Property and Investments	56.5			55.7
Total Other Property and Investments	266.7			265.9
Current Assets:
Cash and cash equivalents	9.3			3.7
Accounts receivable:
Utility	224.1			111.1
Other	19.4			19.2
Allowance for doubtful accounts	(14.0		)	(10.7		)
Delayed customer billings	61.7			10.8
Receivables from associated companies	2.3			11.4
Inventories:
Natural gas	60.8			191.1
Propane gas	12.0			11.7
Materials and supplies	9.2			7.8
Unamortized purchased gas adjustments	—			54.0
Regulatory assets	17.4			18.0
Prepayments and other	16.2			15.5
Total Current Assets	418.4			443.6
Deferred Charges:
Regulatory assets	545.3			523.7
Other	11.9			10.8
Total Deferred Charges	557.2			534.5
Total Assets	$	3,155.9		$	3,105.0

14

LACLEDE GAS COMPANY

CONDENSED BALANCE SHEETS (Continued)

(UNAUDITED)

	March 31,			September 30,
	2015			2014
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock and Paid-in capital (par value $1.00 per share; 50,000 authorized; 24,577 shares issued and outstanding)	746.3			744.1
Retained earnings	314.7			265.6
Accumulated other comprehensive loss	(2.4		)	(1.9		)
Total Common Stock Equity	1,058.6			1,007.8
Long-term debt	808.0			807.9
Total Capitalization	1,866.6			1,815.7
Current Liabilities:
Notes payable	142.6			238.6
Notes payable – associated companies	10.4			—
Accounts payable	77.3			70.1
Accounts payable – associated companies	5.7			6.0
Advance customer billings	—			15.5
Wages and compensation accrued	26.9			30.3
Dividends payable	19.9			19.0
Customer deposits	15.2			14.8
Interest accrued	8.1			8.1
Taxes accrued	79.2			43.9
Unamortized purchase gas adjustments	39.1			—
Other	36.3			41.9
Total Current Liabilities	460.7			488.2
Deferred Credits and Other Liabilities:
Deferred income taxes	424.3			399.8
Pension and postretirement benefit costs	212.4			215.3
Asset retirement obligations	72.9			71.2
Regulatory liabilities	71.7			72.1
Other	47.3			42.7
Total Deferred Credits and Other Liabilities	828.6			801.1
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$	3,155.9		$	3,105.0
See the accompanying Notes to the Financial Statements.

15

LACLEDE GAS COMPANY

STATEMENTS OF COMMON SHAREHOLDER'S EQUITY

(UNAUDITED)

	Common Stock Issued			Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive (Loss) Income
($ Millions)	Shares	Amount										Total
BALANCE SEPTEMBER 30, 2013	24,549	$	0.1	$	738.1	$	237.8		$	(2.1	)	$	973.9
Net income	—	—		—		79.5			—			79.5
Stock-based compensation costs	—	—		1.8		—			—			1.8
Tax benefit – stock compensation	—	—		0.4		—			—			0.4
Dividends declared	—	—		—		(28.8		)	—			(28.8		)
Issuance of common stock to Laclede Group	18	—		0.7		—			—			0.7
Other comprehensive income , net of tax	—	—		—		—			0.1			0.1
BALANCE MARCH 31, 2014	24,567	$	0.1	$	741.0	$	288.5		$	(2.0	)	$	1,027.6
BALANCE SEPTEMBER 30, 2014	24,577	$	0.1	$	744.0	$	265.6		$	(1.9	)	$	1,007.8
Net income	—	—		—		88.9			—			88.9
Stock-based compensation costs	—	—		1.7		—			—			1.7
Tax benefit – stock compensation	—	—		0.5		—			—			0.5
Dividends declared	—	—		—		(39.8		)	—			(39.8		)
Other comprehensive loss, net of tax	—	—		—		—			(0.5		)	(0.5		)
BALANCE MARCH 31, 2015	24,577	$	0.1	$	746.2	$	314.7		$	(2.4	)	$	1,058.6
See the accompanying Notes to the Financial Statements.

16

LACLEDE GAS COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Six Months Ended March 31,
($ Millions)	2015			2014
Operating Activities:
Net Income	$	88.9		$	79.5
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	40.7			40.1
Changes in assets and liabilities:
Accounts Receivable	(100.9		)	(170.7		)
Unamortized purchased gas adjustments	93.0			15.9
Deferred purchased gas costs	(14.3		)	27.8
Accounts payable	11.4			55.3
Delayed/advance customer billings – net	(66.4		)	(53.4		)
Taxes accrued	35.4			36.8
Inventories	128.7			105.1
Other assets and liabilities	12.8			2.7
Other	(6.1		)	5.4
Net cash provided by operating activities	223.2			144.5
Investing Activities:
Capital expenditures	(93.4		)	(67.1		)
Proceeds from final reconciliation of acquisition of Missouri Gas Energy	—			23.9
Other	—			(4.8		)
Net cash used in investing activities	(93.4		)	(48.0		)
Financing Activities:
Redemption and maturity of first mortgage bonds	—			(80.0		)
Repayment of short-term debt – net	(96.1		)	(38.0		)
Borrowings from Laclede Group	16.8			121.8
Repayment of borrowings from Laclede Group	(6.4		)	(91.2		)
Dividends paid	(38.9		)	(28.3		)
Issuance of common stock to Laclede Group	—			0.7
Other	0.4			(0.4		)
Net cash used in financing activities	(124.2		)	(115.4		)
Net Increase (Decrease) in Cash and Cash Equivalents	5.6			(18.9		)
Cash and Cash Equivalents at Beginning of Period	3.7			23.9
Cash and Cash Equivalents at End of Period	$	9.3		$	5.0
Supplemental disclosure of cash flow information:
Interest paid	$	(18.4	)	$	(19.5	)
Income taxes refunded	0.6			1.2
See the accompanying Notes to the Financial Statements.

17

ALABAMA GAS CORPORATION

CONDENSED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Operating Revenues:
Utility	$	233.3	$	263.9	$	353.3	$	406.7
Total Operating Revenues	233.3		263.9		353.3		406.7
Operating Expenses:
Utility
Natural gas	96.4		128.1		142.8		180.1
Operation and maintenance	34.4		36.2		67.0		71.7
Depreciation and amortization	11.7		11.4		23.5		22.6
Taxes, other than income taxes	13.4		15.8		22.2		25.1
Total Operating Expenses	155.9		191.5		255.5		299.5
Operating Income	77.4		72.4		97.8		107.2
Other Income – Net	0.6		1.2		1.0		1.9
Interest Charges:
Interest on long-term debt	2.8		3.4		6.0		6.8
Other interest charges	0.7		0.6		1.3		1.1
Total Interest Charges	3.5		4.0		7.3		7.9
Income Before Income Taxes	74.5		69.6		91.5		101.2
Income Tax Expense	28.2		26.5		34.6		38.3
Net Income	$	46.3	$	43.1	$	56.9	$	62.9
See the accompanying Notes to the Financial Statements.

18

ALABAMA GAS CORPORATION

CONDENSED BALANCE SHEETS

(UNAUDITED)

	March 31,			September 30,
($ Millions, Except Per Share Amounts)	2015			2014
ASSETS
Utility Plant	$	1,558.0		$	1,525.1
Less: Accumulated depreciation and amortization	646.9			626.4
Net Utility Plant	911.1			898.7
Current Assets:
Cash and cash equivalents	35.4			5.6
Accounts receivable:
Utility	79.6			39.0
Other	5.2			5.1
Allowance for doubtful accounts	(4.6		)	(5.1		)
Inventories:
Natural gas	27.6			48.0
Materials and supplies	4.9			5.1
Regulatory assets	10.0			8.8
Deferred income taxes	—			2.3
Prepayments and other	3.3			1.6
Total Current Assets	161.4			110.4
Deferred Charges:
Regulatory assets	87.6			90.6
Deferred income taxes	249.1			277.8
Other	50.4			47.1
Total Deferred Charges	387.1			415.5
Total Assets	$	1,459.6		$	1,424.6

19

ALABAMA GAS CORPORATION

CONDENSED BALANCE SHEETS (Continued)

(UNAUDITED)

	March 31,		September 30,
	2015		2014
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock (par value $0.01 per share; 3.0 million shares authorized; 2.0 million shares issued and outstanding)	$	—	$	—
Paid-in capital	506.3		503.9
Retained earnings	402.6		345.7
Total Common Stock Equity	908.9		849.6
Long-term debt	135.0		249.8
Total Capitalization	1,043.9		1,099.4
Current Liabilities:
Current portion of long-term debt	80.0		—
Notes payable	25.0		16.0
Accounts payable	37.9		34.2
Accounts payable – associated companies	1.2		0.4
Advance customer billings	8.4		16.7
Wages and compensation accrued	4.0		5.7
Customer deposits	21.0		19.1
Interest accrued	3.6		3.9
Taxes accrued	23.0		30.0
Regulatory liabilities	37.9		40.7
Unamortized purchase gas adjustments	37.6		22.4
Other	11.1		6.8
Total Current Liabilities	290.7		195.9
Deferred Credits and Other Liabilities:
Pension and postretirement benefit costs	31.5		29.6
Asset retirement obligations	28.4		27.7
Regulatory liabilities	42.8		53.7
Other	22.3		18.3
Total Deferred Credits and Other Liabilities	125.0		129.3
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$	1,459.6	$	1,424.6
See the accompanying Notes to the Financial Statements.

20

ALABAMA GAS CORPORATION

STATEMENTS OF COMMON SHAREHOLDER'S EQUITY

(UNAUDITED)

	Common Stock Issued			Paid-in Capital		Retained Earnings
($ Millions)	Shares	Amount							Total
BALANCE SEPTEMBER 30, 2013	1,972,052	$	—	$	34.5	$	330.2		$	364.7
Net income	—	—		—		62.9			62.9
Dividends declared	—	—		—		(10.8		)	(10.8		)
BALANCE MARCH 31, 2014	1,972,052	$	—	$	34.5	$	382.3		$	416.8
BALANCE SEPTEMBER 30, 2014	1,972,052	$	—	$	503.9	$	345.7		$	849.6
Net income	—	—		—		56.9			56.9
Purchase accounting adjustments	—	—		2.4		—			2.4
BALANCE MARCH 31, 2015	1,972,052	$	—	$	506.3	$	402.6		$	908.9
See the accompanying Notes to the Financial Statements.

21

ALABAMA GAS CORPORATION

CONDENSED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Six Months Ended March 31,
($ Millions)	2015			2014
Operating Activities:
Net Income	$	56.9		$	62.9
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	23.5			22.6
Changes in assets and liabilities:
Accounts receivable	(44.0		)	(64.5		)
Unamortized purchase gas adjustments	15.2			23.8
Accounts payable	4.2			19.9
Advance customer billings	(8.3		)	(13.6		)
Taxes accrued	(7.0		)	18.5
Inventories	20.5			21.9
Other assets and liabilities	(7.0		)	29.0
Other	35.2			(3.7		)
Net cash provided by operating activities	89.2			116.8
Investing Activities:
Capital expenditures	(34.2		)	(34.4		)
Proceeds from sale of assets	—			—
Other	(0.2		)	3.1
Net cash used in investing activities	(34.4		)	(31.3		)
Financing Activities:
Redemption and maturity of long-term debt	(34.7		)	—
Issuance (repayment) of short-term debt – net	9.0			(49.0		)
Borrowings from affiliates	0.8			—
Dividends paid	—			(10.8		)
Other	(0.1		)	(0.1		)
Net cash used in financing activities	(25.0		)	(59.9		)
Net Increase in Cash and Cash Equivalents	29.8			25.6
Cash and Cash Equivalents at Beginning of Period	5.6			8.5
Cash and Cash Equivalents at End of Period	$	35.4		$	34.1
Supplemental disclosure of cash flow information:
Interest paid	$	(6.7	)	$	(6.8	)
Income taxes paid	—			(5.3		)
See the accompanying Notes to the Financial Statements.

22

THE LACLEDE GROUP, INC., LACLEDE GAS COMPANY AND ALABAMA GAS CORPORATION

NOTES TO THE FINANCIAL STATEMENTS

($ in millions, except per share amounts)

(UNAUDITED)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION - These notes are an integral part of the accompanying unaudited financial statements of The Laclede Group, Inc. (Laclede Group or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco or the Alabama Utility). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Collectively, Laclede Gas and Alagasco are referred to as the Utilities. The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial information with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the disclosures required for complete financial statements. In the opinion of management, the accompanying unaudited financial statements include 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 the Financial Statements contained in Laclede Group's, Laclede Gas' and Alagasco's Annual Reports on Form 10-K or 10-KT for the fiscal year or transition period, as applicable, ended September 30, 2014.

The consolidated financial position, results of operations, and cash flows of Laclede Group are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between the Utilities and their affiliates, as well as intercompany balances on the Utilities' Balance Sheets, have not been eliminated from the Utilities' financial statements. As a result of the Company's August 31, 2014 acquisition of Alagasco, the Company's results of operations for the three and six months ended March 31, 2015 include Alagasco, which impacts the comparability of the current year financial statements to prior years. For a further discussion of the acquisition, see Note 2, Alagasco Acquisition.

The Utilities are regulated natural gas distribution utilities. Due to the seasonal nature of the Utilities, Laclede Group’s earnings are typically concentrated during the heating season of November through April each fiscal year. As a result, the interim statements of income for Laclede Group are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year.

NATURE OF OPERATIONS - Laclede Group, headquartered in St. Louis, Missouri, is a public utility holding company. It has two key operating segments: Gas Utility and Gas Marketing. The Gas Utility segment is comprised of the operations of the Missouri Utilities and the Alabama Utility and serves St. Louis and eastern Missouri through legacy Laclede Gas, serves Kansas City and western Missouri through MGE, and serves central and northern Alabama through Alagasco. Laclede Group’s primary non-utility business, Laclede Energy Resources, Inc. (LER), included in the Gas Marketing segment, provides non-regulated natural gas services. The activities of other subsidiaries are described in Note 9, Information by Operating Segment, and are reported as Other. The Company's earnings are primarily derived from its Gas Utility segment.

REVENUE RECOGNITION - The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their 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 for Laclede Gas at March 31, 2015 and September 30, 2014 were $63.5 and $29.4, respectively.

Alagasco records natural gas distribution revenues in accordance with the tariff established by the Alabama Public Service Commission (APSC). The amount of accrued unbilled revenues, which is not recorded as revenue until billed, for Alagasco at March 31, 2015 and September 30, 2014 were $15.0 and $5.2, respectively.

Laclede Group's other subsidiaries, including LER, record revenues when earned, either when the product is delivered or when services are performed.

In the course of its business, LER 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 Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 815, “Derivatives and Hedging.” Those contracts are accounted for as executory contracts and recorded on an accrual basis. Revenues and expenses from such contracts are recorded using a gross presentation. Contracts not designated as normal purchases or normal sales are recorded as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. Certain of LER’s wholesale purchase and sale transactions entered on or after January 1, 2012 are classified as trading activities for financial reporting purposes. Under GAAP, revenues and expenses associated with trading activities are presented on a net basis in Gas

23

Marketing Operating Revenues in the Condensed Consolidated Statements of Income. This net presentation has no effect on operating income or net income.

GROSS RECEIPTS TAXES - Gross receipts taxes associated with the Utilities' services are imposed on the Utilities and billed to customers. These amounts are recorded gross in the Operating Revenues line in the Company's Condensed Consolidated Statements of Income and the Utilities' Condensed Statements of Income. Gross receipts taxes are expensed by the Utilities and are included in the "Taxes, other than income taxes" line in the Company's Condensed Consolidated Statements of Income and the Utilities' Condensed Statements of Income.

The following table presents gross receipts taxes recorded:

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Laclede Group	$	44.7	$	34.3	$	72.4	$	54.3
Laclede Gas	33.9		34.3		55.8		54.3
Alagasco	10.8		13.0		16.6		19.4

REGULATED OPERATIONS - The Utilities account for their regulated operations in accordance with FASB ASC Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. In addition, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. As authorized by the MoPSC, the Purchased Gas Adjustment (PGA) clauses allow the Missouri Utilities to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. Similarly, Alagasco's rate schedules for natural gas distribution charges contain a Gas Supply Adjustment (GSA) rider, which permits the pass-through to customers of changes in the cost of gas supply. Regulatory assets and liabilities related to the PGA clauses and GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. See additional discussion on regulated operations in Note 4, Regulatory Matters.

TRANSACTIONS WITH AFFILIATES - Transactions between the Company and its affiliates have been eliminated from the consolidated financial statements of Laclede Group. Alagasco had no significant transactions with affiliates. Laclede Gas had the following transactions with affiliates:

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Sales of natural gas from Laclede Gas to LER	$	1.9	$	4.2	$	2.9	$	4.3
Sales of natural gas from LER to Laclede Gas	16.0		25.0		41.3		44.5
Transportation services provided by Laclede Pipeline Company to Laclede Gas	0.2		0.2		0.5		0.5

GOODWILL - Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. The following table represents total goodwill of Laclede Group and Laclede Gas, by acquisition, all included in the Gas Utility segment:

	Laclede Group				Laclede Gas
($ Millions)	March 31, 2015		September 30, 2014		March 31, 2015		September 30, 2014
Acquisition of MGE	$	210.2	$	210.2	$	210.2	$	210.2
Acquisition of Alagasco	735.8		727.6		—		—
Total	$	946.0	$	937.8	$	210.2	$	210.2

Alagasco has no goodwill on its balance sheet as push down accounting was not applied. As part of the Alagasco acquisition, the Company initially recorded $727.6 of goodwill. As part of the final reconciliation of net assets, $8.6 was paid by the Company to Energen Corporation (Energen) on January 6, 2015. This payment, offset partly by other immaterial purchase

24

price adjustments in the second quarter of 2015, resulted in goodwill of $735.8 as of March 31, 2015 related to the Alagasco acquisition.

UTILITY PLANT - Laclede Gas had accrued capital expenditures of $4.2 and $3.0 as of March 31, 2015 and September 30, 2014. Alagasco had accrued capital expenditures of $4.7 and $5.0 as of March 31, 2015 and September 30, 2014.

REVISIONS TO PRIOR FINANCIAL STATEMENTS - In the Statements of Shareholder’s Equity in Alagasco's most recent Annual Report on Form 10-KT, $31.7 was misclassified between common stock and paid-in capital, with no impact on total shareholder’s equity. The prior period balances have been corrected in this filing. In addition, certain current and noncurrent assets and liabilities in the prior period have been adjusted to conform with the current period presentation for Laclede Group, Laclede Gas and Alagasco.

NEW ACCOUNTING PRONOUNCEMENTS - In May 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers. This standard is intended to improve the financial reporting requirements for revenue from contracts with customers by providing a principles-based approach to the recognition of revenue. The core principle of the standard is when an entity transfers goods or services to customers it will recognize revenue in an amount that reflects the consideration the entity expects to be entitled to for those goods or services. The standard outlines a five-step model and related application guidance, which replaces most existing revenue recognition guidance. ASU 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The guidance is currently effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early adoption not permitted. In April 2015, the FASB proposed (for public comment) a one-year deferral of the effective date (which also would permit early application as of the standard's original effective date). The Company, Laclede Gas and Alagasco are currently assessing the available transition methods and the potential impacts of the standard, which must be adopted by the first quarter of fiscal 2018 (or fiscal 2019, if the effective date is delayed as proposed).

In April 2015, the FASB issued ASU No. 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs. Currently different balance sheet presentation requirements exist for debt issuance costs and debt discount and premium. Debt issuance costs are recorded as a deferred charge (asset), while debt discount and debt premium costs are recorded as a liability adjustment. This standard will require debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The guidance is effective for fiscal years beginning after December 15, 2015 and interim periods within those years, with early adoption permitted. The application of this standard will be retrospective, wherein the balance sheet of each individual period presented will be adjusted to reflect the period-specific impacts of applying the new guidance. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2017.

2. ALAGASCO ACQUISITION

The Company completed the acquisition of 100% of the common stock of Alagasco (Alagasco Transaction) from Energen for $1,600.0, including cash and assumed debt. The acquisition date (Closing Date) was September 2, 2014, with an effective time under the Stock Purchase Agreement of 11:59 p.m. on August 31, 2014. The Alagasco Transaction was subject to certain post-closing adjustments for cash, indebtedness and working capital as discussed below. Total cash consideration paid at closing, net of cash acquired and debt assumed, was $1,305.2. Subsequently, the Company and Energen agreed to a final reconciliation of net assets, and $8.6 was paid by the Company to Energen on January 6, 2015, effectively increasing the total net consideration to $1,313.8. This payment, offset partly by other immaterial purchase price adjustments in the second quarter of 2015, increased goodwill related to the transaction from $727.6 recorded as of September 30, 2014, to $735.8 as of March 31, 2015. The Alagasco Transaction was accounted for under the acquisition method of accounting in accordance with FASB ASC Topic 805, “Business Combinations.” The Company determined that the Alagasco Transaction met the scope exceptions for pushdown accounting, and as such the excess consideration transferred over the fair value of assets acquired was recorded at Laclede Group. The Company and Energen made an election under Section 338(h)(10) of the Internal Revenue Code of 1986, as amended, to treat the Alagasco Transaction as a deemed purchase and sale of assets for tax purposes. As a result, the existing deferred tax assets and liabilities were re-measured as of the Closing Date.

25

3. EARNINGS PER COMMON SHARE

	Three Months Ended March 31,				Six Months Ended March 31,
(Millions, except per share amounts)	2015		2014		2015		2014
Basic EPS:
Net Income	$	94.4	$	52.2	$	141.5	$	87.8
Less: Income allocated to participating securities	0.3		0.2		0.5		0.3
Net Income Available to Common Shareholders	$	94.1	$	52.0	$	141.0	$	87.5
Weighted Average Shares Outstanding	43.1		32.6		43.1		32.6
Basic Earnings Per Share of Common Stock	$	2.18	$	1.59	$	3.27	$	2.68
Diluted EPS:
Net Income	$	94.4	$	52.2	$	141.5	$	87.8
Less: Income allocated to participating securities	0.3		0.2		0.5		0.3
Net Income Available to Common Shareholders	$	94.1	$	52.0	$	141.0	$	87.5
Weighted Average Shares Outstanding	43.1		32.6		43.1		32.6
Dilutive Effect of Stock Options, Restricted Stock and Restricted Stock Units	0.1		—		0.1		0.1
Weighted Average Diluted Shares	43.2		32.6		43.2		32.7
Diluted Earnings Per Share of Common Stock	$	2.18	$	1.59	$	3.26	$	2.68

There were 0.4 and 0.3 shares of restricted stock and stock units subject to performance or market conditions for the three and six months ended March 31, 2015 and 2014, respectively, excluded from the calculation of diluted EPS. Also, Laclede Group's 2014 2.0% Series Equity Units issued in June 2014 are potentially dilutive securities but were anti-dilutive for the three and six months ended March 31, 2015; accordingly, they were excluded from the calculation of weighted average diluted shares for those periods.

4. REGULATORY MATTERS

As explained in Note 1, Summary of Significant Accounting Policies, Laclede Gas and Alagasco account for regulated operations in accordance with FASB ASC Topic 980, "Regulated Operations." The following regulatory assets and regulatory liabilities, including purchase gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of March 31, 2015 and September 30, 2014.

26

	Laclede Group				Laclede Gas				Alagasco
	March 31,		September 30,		March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014		2015		2014
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	21.4	$	21.4	$	15.0	$	15.0	$	6.4	$	6.4
Unamortized purchased gas adjustments	—		54.0		—		54.0		—		—
Other	6.0		5.4		2.4		3.0		3.6		2.4
Total Regulatory Assets (current)	27.4		80.8		17.4		72.0		10.0		8.8
Non-current:
Future income taxes due from customers	125.6		117.0		125.6		117.0		—		—
Pension and postretirement benefit costs	420.8		431.5		357.9		365.4		62.9		66.1
Accretion and depreciation of asset retirement obligations	19.1		18.4		—		—		19.1		18.4
Purchased gas costs	18.6		4.3		18.6		4.3		—		—
Energy efficiency	20.4		18.9		20.4		18.9		—		—
Other	28.4		24.2		22.8		18.1		5.6		6.1
Total Regulatory Assets (non-current)	632.9		614.3		545.3		523.7		87.6		90.6
Total Regulatory Assets	$	660.3	$	695.1	$	562.7	$	595.7	$	97.6	$	99.4
Regulatory Liabilities:
Current:
RSE adjustment	$	9.9	$	19.8	$	—	$	—	$	9.9	$	19.8
Unbilled service margin	15.0		5.2		—		—		15.0		5.2
Refundable negative salvage	10.8		13.4		—		—		10.8		13.4
Unamortized purchased gas adjustments	76.7		22.4		39.1		—		37.6		22.4
Other	2.8		2.9		0.6		0.6		2.2		2.3
Total Regulatory Liabilities (current)	115.2		63.7		39.7		0.6		75.5		63.1
Non-current:
Postretirement liabilities	25.1		26.2		—		—		25.1		26.2
Refundable negative salvage	17.0		26.8		—		—		17.0		26.8
Accrued cost of removal	59.9		60.5		59.9		60.5		—		—
Other	12.3		12.3		11.8		11.6		0.7		0.7
Total Regulatory Liabilities (non-current)	114.3		125.8		71.7		72.1		42.8		53.7
Total Regulatory Liabilities	$	229.5	$	189.5	$	111.4	$	72.7	$	118.3	$	116.8

27

A portion of the Company's and Laclede Gas' regulatory assets are not earning a return, as shown in the schedule below:

	Laclede Group				Laclede Gas
	March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014
Regulatory Assets Not Earning a Return:
Future income taxes due from customers	$	125.6	$	117.0	$	125.6	$	117.0
Pension and postretirement benefit costs	232.3		240.9		232.3		240.9
Other	15.2		16.0		15.2		16.0
Total Regulatory Assets Not Earning a Return	$	373.1	$	373.9	$	373.1	$	373.9

Like all the Company's regulatory assets, these regulatory assets are expected to be recovered from customers in future rates. The Company and Laclede Gas expect these items to be recovered over a period not to exceed 15 years consistent with precedent set by the Missouri Public Service Commission (MoPSC). The portion of regulatory assets related to pensions and other postemployment benefits that pertains to unfunded differences between the projected benefit obligation and plan assets also does not earn a rate of return. Alagasco does not have any regulatory assets that are not earning a return.

5. FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts of 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.

Laclede Group

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	46.9	$	46.9	$	46.9	$	—	$	—
Short-term debt	247.6		247.6		—		247.6		—
Long-term debt, including current portion	1,816.3		1,971.0		—		1,971.0		—
As of September 30, 2014
Cash and cash equivalents	$	16.1	$	16.1	$	16.1	$	—	$	—
Short-term debt	287.1		287.1		—		287.1		—
Long-term debt	1,851.0		1,937.3		—		1,937.3		—

28

Laclede Gas

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	9.3	$	9.3	$	9.3	$	—	$	—
Short-term debt	153.0		—		—		153.0		—
Long-term debt	808.0		909.5		—		909.5		—
As of September 30, 2014
Cash and cash equivalents	$	3.7	$	3.7	$	3.7	$	—	$	—
Short-term debt	238.6		238.6		—		238.6		—
Long-term debt	807.9		876.2		—		876.2		—

Alagasco

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	35.4	$	35.4	$	35.4	$	—	$	—
Short-term debt	25.0		25.0		—		25.0		—
Long-term debt, including current portion	215.0		235.1		—		235.1		—
As of September 30, 2014
Cash and cash equivalents	$	5.6	$	5.6	$	5.6	$	—	$	—
Short-term debt	16.0		16.0		—		16.0		—
Long-term debt	249.8		266.4		—		266.4		—

6. FAIR VALUE MEASUREMENTS

The following tables for Laclede Group, Laclede Gas, and Alagasco categorize the assets and liabilities in the balance sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.

The mutual funds included in Level 1 are valued based on exchange-quoted market prices of individual securities. The mutual funds included in Level 2 are valued based on the closing net asset value per unit.

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 Over-the-Counter Bulletin Board (OTCBB), 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. The Alagasco interest rate swaps fall into this latter Level 2 classification. 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 Level 3 balances as of March 31, 2015 and September 30, 2014 consisted of gas commodity contracts. The Company’s and the Utilities' 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 mutual funds are included in the "Other investments" line of the balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exists between the Company or Laclede Gas and the counterparty to a derivative contract.

29

Laclede Group

($ Millions)	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, 2015
ASSETS
Gas Utility
U. S. stock/bond mutual funds	$	16.4	$	3.9	$	—	$	—		$	20.3
NYMEX natural gas contracts	0.6		—		—		(0.6		)	—
Subtotal	17.0		3.9		—		(0.6		)	20.3
Gas Marketing
NYMEX natural gas contracts	3.4		1.7		—		(4.3		)	0.8
Natural gas commodity contracts	—		2.7		0.5		(0.5		)	2.7
Total	$	20.4	$	8.3	$	0.5	$	(5.4	)	$	23.8
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	14.1	$	—	$	—	$	(14.1	)	$	—
OTCBB natural gas contracts	—		14.5		—		—			14.5
NYMEX gasoline and heating oil contracts	1.0		—		—		(1.0		)	—
Interest rate swaps	—		2.9		—		—			2.9
Subtotal	15.1		17.4		—		(15.1		)	17.4
Gas Marketing
NYMEX natural gas contracts	1.9		3.5		—		(5.4		)	—
Natural gas commodity contracts	—		0.8		—		(0.5		)	0.3
Total	$	17.0	$	21.7	$	—	$	(21.0	)	$	17.7
As of September 30, 2014
ASSETS
Gas Utility
U. S. stock/bond mutual funds	$	15.7	$	3.9	$	—	$	—		$	19.6
NYMEX natural gas contracts	2.4		—		—		(2.4		)	—
OTCBB natural gas contracts	—		0.1		—		(0.1		)	—
Subtotal	18.1		4.0		—		(2.5		)	19.6
Gas Marketing
NYMEX natural gas contracts	1.0		1.2		—		(1.8		)	0.4
Natural gas commodity contracts	—		2.7		0.2		(0.2		)	2.7
Total	$	19.1	$	7.9	$	0.2	$	(4.5	)	$	22.7
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	5.2	$	—	$	—	$	(5.2	)	$	—
OTCBB natural gas contracts	—		4.1		—		(0.1		)	4.0
Gasoline and heating oil contracts	0.2		—		—		(0.2		)	—
Subtotal	5.4		4.1		—		(5.5		)	4.0
Gas Marketing
NYMEX natural gas contracts	1.1		0.7		—		(1.8		)	—
Natural gas commodity contracts	—		0.7		—		(0.2		)	0.5
Total	$	6.5	$	5.5	$	—	$	(7.5	)	$	4.5

30

Laclede Gas

($ Millions)	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, 2015
ASSETS
U. S. stock/bond mutual funds	$	16.4	$	3.9	$	—	$	—		$	20.3
NYMEX natural gas contracts	0.6		—		—		(0.6		)	—
Total	17.0		3.9		—		(0.6		)	20.3
LIABILITIES
NYMEX natural gas contracts	14.1		—		—		(14.1		)	—
OTCBB natural gas contracts	—		14.5		—		—			14.5
Gasoline and heating oil contracts	1.0		—		—		(1.0		)	—
Total	$	15.1	$	14.5	$	—	$	(15.1	)	$	14.5
As of September 30, 2014
ASSETS
U. S. stock/bond mutual funds	$	15.7	$	3.9	$	—	$	—		$	19.6
NYMEX natural gas contracts	2.4		—		—		(2.4		)	—
OTCBB natural gas contracts	—		0.1		—		(0.1		)	—
Total	18.1		4.0		—		(2.5		)	19.6
LIABILITIES
NYMEX/ICE natural gas contracts	5.2		—		—		(5.2		)	—
OTCBB natural gas contracts	—		4.1		—		(0.1		)	4.0
NYMEX gasoline and heating oil contracts	0.2		—		—		(0.2		)	—
Total	$	5.4	$	4.1	$	—	$	(5.5	)	$	4.0

Alagasco

($ Millions)	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, 2015
LIABILITIES
Interest rate swaps	$	—	$	2.9	$	—	$	—	$	2.9
Total	$	—	$	2.9	$	—	$	—	$	2.9
As of September 30, 2014
LIABILITIES
Interest rate swaps	$	—	$	—	$	—	$	—	$	—
Total	$	—	$	—	$	—	$	—	$	—

31

7. CONCENTRATIONS OF CREDIT RISK

Other than in LER (the Gas Marketing segment), Laclede Group has no significant concentrations of credit risk.

A significant portion of LER’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. The concentration of transactions with these counterparties has 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. LER records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in LER's accounts receivable attributable to energy producers and their marketing affiliates totaled $7.5 at March 31, 2015. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $5.7. LER's accounts receivable attributable to utility companies and their marketing affiliates comprised $15.6 of total accounts receivable at March 31, 2015, while net receivable amounts from these customers, reflecting netting arrangements, were $14.1.

LER also has concentrations of credit risk with certain individually significant counterparties and with pipeline companies associated with its natural gas receivable amounts. At March 31, 2015, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure) totaled $9.8. These five counterparties are either investment-grade rated or owned by investment-grade rated companies. Net receivable amounts from these five customers on the same date, reflecting netting arrangements, were $9.3.

8. PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

This footnote includes all pension plans of the Company whether historical plans or those acquired as part of the purchase of certain assets and liabilities of MGE on September 1, 2013 or those acquired in the Alagasco Transaction effective August 31, 2014. The net pension and postretirement obligations were re-measured at the applicable acquisition dates as well as at the fiscal year end.

Pension Plans

The pension plans of Laclede Group consist of plans for employees at the Missouri Utilities and plans covering employees of Alagasco.

The Missouri Utilities have non-contributory, defined benefit, trusteed forms of pension plans covering the majority of their employees. Plan assets consist primarily of corporate and US government obligations and a growth segment consisting of exposure to equity markets, commodities, real estate and inflation-indexed securities, achieved through derivative instruments and investments in diversified mutual funds.

Alagasco has non-contributory, defined benefit, trusteed forms of pension plans covering the majority of its employees. Qualified plan assets are comprised of United States equities consisting of mutual and commingled funds with varying strategies, global equities consisting of mutual funds, alternative investments of limited partnerships and commingled and mutual funds, and fixed income investments.

32

The net periodic pension cost included the following components:

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Laclede Group
Service cost – benefits earned during the period	$	4.3		$	2.5		$	8.6		$	4.9
Interest cost on projected benefit obligation	7.4			6.0			14.9			12.0
Expected return on plan assets	(9.3		)	(6.7		)	(18.7		)	(13.3		)
Amortization of prior service cost	0.1			0.1			0.2			0.2
Amortization of actuarial loss	2.0			1.7			3.9			3.5
Loss on lump-sum settlements	—			1.3			—			1.3
Sub-total	4.5			4.9			8.9			8.6
Regulatory adjustment	4.8			1.6			9.7			4.5
Net pension cost	$	9.3		$	6.5		$	18.6		$	13.1

Laclede Gas
Service cost – benefits earned during the period	$	2.9		$	2.5		$	5.7		$	4.9
Interest cost on projected benefit obligation	5.9			6.0			11.8			12.0
Expected return on plan assets	(7.3		)	(6.7		)	(14.6		)	(13.3		)
Amortization of prior service cost	0.1			0.1			0.2			0.2
Amortization of actuarial loss	2.0			1.7			3.9			3.5
Loss on lump-sum settlements	—			1.3			—			1.3
Sub-total	3.6			4.9			7.0			8.6
Regulatory adjustment	3.4			1.6			6.8			4.5
Net pension cost	$	7.0		$	6.5		$	13.8		$	13.1

Alagasco
Service cost – benefits earned during the period	$	1.4		$	1.5		$	2.9		$	3.6
Interest cost on projected benefit obligation	1.5			1.2			3.1			2.9
Expected return on plan assets	(2.0		)	(1.5		)	(4.1		)	(3.7		)
Amortization of prior service cost	—			0.1			—			0.1
Amortization of actuarial loss	—			0.7			—			2.0
Loss on lump-sum settlements	—			10.1			—			10.9
Sub-total	0.9			12.1			1.9			15.8
Regulatory adjustment	1.4			(9.8		)	2.9			(10.6		)
Net pension cost	$	2.3		$	2.3		$	4.8		$	5.2

Pursuant to the provisions of the Missouri Utilities' and Alagasco's pension plans, pension obligations may be satisfied by lump-sum cash payments. Pursuant to a MoPSC 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 in a specific year. Lump-sum payments during the six months ended March 31, 2015 were $12.7 for the Missouri Utilities and $2.6 for Alagasco.

The funding policy of the Utilities 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 2015 contributions to Laclede Gas' pension plans through March 31, 2015 were $9.1 to the qualified trusts and $0.2 to the non-qualified plans. There were no fiscal 2015 contributions to the Alagasco pension plans through March 31, 2015.

Contributions to the Missouri Utilities' pension plans for the remaining six months of fiscal 2015 are anticipated to be approximately $17.3 to the qualified trusts and $0.3 to the non-qualified plans. There are no expected contributions to Alagasco's pension plans for the remaining six months of fiscal 2015.

33

Postretirement Benefits

The Utilities provide certain life insurance benefits at retirement. Laclede Gas plans provide for medical insurance after early retirement until age 65. For retirements prior to January 1, 2015, the MGE plans provided medical insurance after retirement until death. For retirements after January 1, 2015, the MGE plans provide medical insurance after early retirement until age 65. The transition obligation not yet included in postretirement benefit cost is being amortized over 20 years. Under the Alagasco plans, medical insurance is currently available upon retirement until death for certain retirees depending on the type of employee and the date the employee was originally hired.

Net periodic postretirement benefit cost for the Company consisted of the following components:

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Laclede Group
Service cost – benefits earned during the period	$	3.2		$	2.8		$	6.4		$	5.6
Interest cost on accumulated postretirement benefit obligation	2.8			2.2			5.6			4.4
Expected return on plan assets	(3.3		)	(1.7		)	(6.6		)	(3.4		)
Amortization of prior service credit	0.2			—			0.4			—
Amortization of actuarial loss	1.2			1.5			2.5			3.0
Sub-total	4.1			4.8			8.3			9.6
Regulatory adjustment	(2.7		)	(2.4		)	(5.4		)	(4.8		)
Net postretirement benefit cost	$	1.4		$	2.4		$	2.9		$	4.8

Laclede Gas
Service cost – benefits earned during the period	$	3.1		$	2.8		$	6.2		$	5.6
Interest cost on accumulated postretirement benefit obligation	2.2			2.2			4.3			4.4
Expected return on plan assets	(2.1		)	(1.7		)	(4.1		)	(3.4		)
Amortization of prior service cost	0.2			—			0.4			—
Amortization of actuarial loss	1.2			1.5			2.5			3.0
Sub-total	4.6			4.8			9.3			9.6
Regulatory adjustment	(2.3		)	(2.4		)	(4.6		)	(4.8		)
Net postretirement benefit cost	$	2.3		$	2.4		$	4.7		$	4.8

Alagasco
Service cost – benefits earned during the period	$	0.1		$	0.1		$	0.2		$	0.4
Interest cost on accumulated postretirement benefit obligation	0.6			0.5			1.3			1.2
Expected return on plan assets	(1.2		)	(1.1		)	(2.5		)	(2.1		)
Amortization of actuarial loss and other	—			(0.4		)	—			(0.5		)
Amortization of transition obligation	—			0.1			—			0.3
Sub-total	(0.5		)	(0.8		)	(1.0		)	(0.7		)
Regulatory adjustment	(0.4		)	—			(0.8		)	—
Net postretirement benefit cost	$	(0.9	)	$	(0.8	)	$	(1.8	)	$	(0.7	)

Missouri and Alabama 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. The Missouri Utilities established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi Trusts as its external funding mechanisms. The assets of the VEBA and Rabbi Trusts consist primarily of money market securities and mutual funds invested in stocks and bonds.

The Utilities' 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 2015 contributions to the postretirement plans through March 31, 2015 were $4.4 for the Missouri Utilities. Contributions to the postretirement plans for the remaining six months of fiscal year 2015 are anticipated to be $13.6 to the qualified trusts and $0.3 paid directly to participants from the Missouri Utilities' funds. For Alagasco, there were no contributions to the postretirement plans during the first six months of fiscal year 2015, and there are none expected for the remaining six months.

34

9. INFORMATION BY OPERATING SEGMENT

The Company has two key operating segments: Gas Utility and Gas Marketing. The Gas Utility segment comprises the regulated operations of the Utilities, consisting of Laclede Gas and Alagasco. Laclede Gas and Alagasco are public utilities engaged in the retail distribution and sale of natural gas serving an area in eastern Missouri through its legacy Laclede Gas assets, an area in western Missouri through its MGE assets, and central and northern Alabama through its Alagasco assets. The Gas Marketing segment includes the results of LER, a subsidiary engaged in the non-regulated marketing of natural gas and related activities, and LER Storage Services, Inc., which utilizes natural gas storage contracts for providing natural gas sales. Other includes:

• unallocated corporate items, including certain debt and associated interest costs,

• Laclede Pipeline Company, a subsidiary of Laclede Group which operates a propane pipeline under Federal Energy Regulatory Commission (FERC) jurisdiction, and

• Laclede Group’s subsidiaries that are engaged in, among other activities, oil production, real estate development, compression of natural gas, and financial investments in other enterprises. All subsidiaries are wholly owned.

Accounting policies and intersegment transactions are described in Note 1, Summary of Significant Accounting Policies.

35

($ Millions)	Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Three Months Ended March 31, 2015
Operating Revenues:
Revenues from external customers	$	847.0	$	30.0	$	0.4		$	—		$	877.4
Intersegment revenues	2.0		14.1		0.5			(16.6		)	—
Total Operating Revenues	849.0		44.1		0.9			(16.6		)	877.4
Operating Expenses:
Gas Utility
Natural and propane gas	499.1		—		—			(16.3		)	482.8
Other operation and maintenance	104.0		—		—			(0.2		)	103.8
Depreciation and amortization	32.2		—		—			—			32.2
Taxes, other than income taxes	55.7		—		—			—			55.7
Total Gas Utility Operating Expenses	691.0		—		—			(16.5		)	674.5
Gas Marketing	—		43.5		—			—			43.5
Other	—		—		1.8			(0.1		)	1.7
Total Operating Expenses	691.0		43.5		1.8			(16.6		)	719.7
Operating Income (Loss)	$	158.0	$	0.6	$	(0.9	)	$	—		$	157.7
Net Economic Earnings (Loss)	$	96.5	$	2.1	$	(1.0	)	$	—		$	97.6
Three Months Ended March 31, 2014
Operating Revenues:
Revenues from external customers	$	634.4	$	59.9	$	0.2		$	—		$	694.5
Intersegment revenues	4.2		20.6		0.6			(25.4		)	—
Total Operating Revenues	638.6		80.5		0.8			(25.4		)	694.5
Operating Expenses:
Gas Utility
Natural and propane gas	430.5		—		—			(25.2		)	405.3
Other operation and maintenance	72.2		—		—			(0.2		)	72.0
Depreciation and amortization	20.1		—		—			—			20.1
Taxes, other than income taxes	41.8		—		—			—			41.8
Total Gas Utility Operating Expenses	564.6		—		—			(25.4		)	539.2
Gas Marketing	—		65.0		—			—			65.0
Other	—		—		3.1			—			3.1
Total Operating Expenses	564.6		65.0		3.1			(25.4		)	607.3
Operating Income (Loss)	$	74.0	$	15.5	$	(2.3	)	$	—		$	87.2
Net Economic Earnings (Loss)	$	44.7	$	7.1	$	(0.1	)	$	—		$	51.7

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($ Millions)	Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Six Months Ended March 31, 2015
Operating Revenues:
Revenues from external customers	$	1,428.4	$	67.8	$	0.8		$	—		$	1,497.0
Intersegment revenues	3.0		38.5		1.0			(42.5		)	—
Total Operating Revenues	1,431.4		106.3		1.8			(42.5		)	1,497.0
Operating Expenses:
Gas Utility
Natural and propane gas	828.9		—		—			(41.8		)	787.1
Other operation and maintenance	201.4		—		—			(0.5		)	200.9
Depreciation and amortization	64.2		—		—			—			64.2
Taxes, other than income taxes	93.7		—		—			—			93.7
Total Gas Utility Operating Expenses	1,188.2		—		—			(42.3		)	1,145.9
Gas Marketing	—		102.1		—			—			102.1
Other	—		—		4.2			(0.2		)	4.0
Total Operating Expenses	1,188.2		102.1		4.2			(42.5		)	1,252.0
Operating Income (Loss)	$	243.2	$	4.2	$	(2.4	)	$	—		$	245.0
Net Economic Earnings (Loss)	$	146.3	$	2.5	$	(5.5	)	$	—		$	143.3
Six Months Ended March 31, 2014
Operating Revenues:
Revenues from external customers	$	1,069.6	$	93.1	$	0.4		$	—		$	1,163.1
Intersegment revenues	4.3		40.1		1.0			(45.4		)	—
Total Operating Revenues	1,073.9		133.2		1.4			(45.4		)	1,163.1
Operating Expenses:
Gas Utility
Natural and propane gas	692.1		—		—			(45.0		)	647.1
Other operation and maintenance	134.7		—		—			(0.4		)	134.3
Depreciation and amortization	40.1		—		—			—			40.1
Taxes, other than income taxes	70.4		—		—			—			70.4
Total Gas Utility Operating Expenses	937.3		—		—			(45.4		)	891.9
Gas Marketing	—		116.8		—			—			116.8
Other	—		—		4.3			—			4.3
Total Operating Expenses	937.3		116.8		4.3			(45.4		)	1,013.0
Operating Income (Loss)	$	136.6	$	16.4	$	(2.9	)	$	—		$	150.1
Net Economic Earnings (Loss)	$	80.5	$	7.9	$	(0.4	)	$	—		$	88.0

The Company's total assets by segment were as follows:

	March 31,			September 30,
($ Millions)	2015			2014
Total Assets:
Gas Utility	$	4,615.6		$	4,520.0
Gas Marketing	131.7			156.7
Other	1,590.8			1,575.7
Eliminations	(1,157.4		)	(1,178.4		)
Total Assets	$	5,180.7		$	5,074.0

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The following table reconciles the Company's Net Income (GAAP) to Net Economic Earnings (Non-GAAP):

	Three Months Ended March 31,						Six Months Ended March 31,
($ Millions)	2015			2014			2015			2014
Net income (GAAP)	$	94.4		$	52.2		$	141.5		$	87.8
Unrealized loss (gain) on energy-related derivative contracts	2.6			(1.7		)	(0.4		)	(1.3		)
Lower of cost or market inventory adjustments	(1.0		)	(0.5		)	0.2			(0.6		)
Realized loss (gain) on economic hedges prior to sale of the physical commodity	0.1			(0.1		)	0.1			(0.1		)
Acquisition, divestiture and restructuring activities	1.5			1.8			1.9			2.2
Net Economic Earnings (Non-GAAP)	$	97.6		$	51.7		$	143.3		$	88.0

10. COMMITMENTS AND CONTINGENCIES

Commitments

The Company and the Utilities have entered into contracts with various counterparties, expiring on dates through 2019, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at March 31, 2015 are estimated at approximately $1,595.0, $750.4, and $521.5 for the Company, Laclede Gas, and Alagasco, respectively. Additional contracts are generally entered into prior to or during the heating season of November through April. The Missouri Utilities recover their costs from customers in accordance with their PGA clause and Alagasco recovers its cost through its GSA rider.

Contingencies

Laclede Gas

Similar to other natural gas utility companies, 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, the Company or Laclede Gas may incur additional environmental liabilities that may result in additional costs.

In the natural gas industry, many gas distribution companies like Laclede Gas and MGE have incurred environmental liabilities associated with sites they or their predecessor companies formerly owned or operated where 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. Laclede Gas has enrolled the two sites in the City of St. Louis in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP). MGE has enrolled all of its owned former manufactured gas plant sites in the BVCP.

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.

In conjunction with redevelopment of one of the sites located in the City of St. Louis, 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 coverage, 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.

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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, Laclede Gas 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. Accordingly, Laclede Gas was able to enter into a cost sharing agreement for remedial investigation with other potentially responsible parties. Pending Missouri Department of Natural Resources approval, the remedial investigation of the site will begin. 

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.

On March 10, 2015, Laclede Gas received a Section 104(e) information request from Region 7 of the United States Environmental Protection Agency (EPA) in respect to the former Thompson Chemical/Superior Solvents site located at 60 Chouteau Avenue in St. Louis, Missouri. Laclede Gas is currently reviewing its records, and responses are due to the EPA on May 26, 2015. In turn, Laclede Gas has issued a Freedom of Information Act request to the EPA dated April 3, 2015, in an effort to identify the basis of the EPA’s inquiry.

MGE has seven owned MGP sites enrolled in the BVCP, including Joplin MGP #1, St. Joseph MGP #1, Kansas City Coal Gas Station B, Kansas City Station A Railroad, Kansas City Coal Gas Station A North, Kansas City Coal Gas Station A South, and Independence MGP #2. Source removal has been conducted at all of the owned sites since 2003 with the exception of Joplin, which is in the early stages of site analysis and characterization. Remediation efforts at these sites are at various stages of completion, ranging from groundwater monitoring and sampling following source removal activities to early site characterization in Joplin. As part of its participation in the BVCP, MGE communicates regularly with the MDNR with respect to its remediation efforts and monitoring activities at these sites.

To date, costs incurred for all Missouri Utilities' MGP sites for investigation, remediation and monitoring 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. The actual future costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remediation actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and government regulations, the ultimate ability of other potential responsible parties to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries.

In 2013, Laclede Gas retained an outside consultant to conduct probabilistic cost modeling of 19 former MGP sites owned or operated by Laclede Gas or MGE. The purpose of this analysis was to develop an estimated range of probabilistic future liability for each site. That analysis, completed in August 2014, provided a range of demonstrated possible future expenditures to investigate, monitor and remediate all 19 MGP sites from $8.1 to $39.3 based upon current available facts, technology and laws and regulations.

Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable. To the extent such costs (less any amounts received from insurance proceeds or as contributions from other potential responsible parties), are incurred prior to a rate case, Laclede Gas would request from the MoPSC authority to defer such costs and collect them in the next rate case. The Company does not expect potential liabilities that may arise from remediating these sites to have a material impact on the future financial position or results of operations of Laclede Gas or the Company.

Alagasco

Alagasco 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 Alagasco's financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Alagasco may be required to incur additional costs.

Alagasco is in the chain of title of nine former MGP sites, four of which it still owns, and five former manufactured gas distribution sites, one of which it still owns. Management expects that, should future remediation of the sites be required, Alagasco’s share of the remediation costs will not materially affect the financial position of Alagasco. During 2011, a removal action was completed at the Huntsville, Alabama MGP site pursuant to an Administrative Settlement Agreement and Order on Consent among the EPA, Alagasco and the current site owner.

In 2012, Alagasco responded to an EPA Request for Information Pursuant to Section 104 of Comprehensive Environment Response, Compensation, and Liability Act (CERCLA) relating to the 35th Avenue Superfund Site located in North Birmingham,

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Jefferson County, Alabama. The Request related to a former site of a manufactured gas distribution facility owned by Alagasco and located in the vicinity of the 35th Avenue Superfund Site. In September 2013, Alagasco received from the EPA a General Notice Letter and Invitation to Conduct a Removal Action at the 35th Avenue Superfund Site. The letter identifies Alagasco as a potentially responsible party (PRP) under CERCLA for the cleanup of the Site or costs the EPA incurs in cleaning up the site. The EPA also offered the PRP group the opportunity to conduct Phase I of the proposed removal action which involved removal activities at approximately 50 residences that purportedly exceed certain risk levels for contamination. All Phase I work was conducted by EPA without PRP participation, and is completed or close to completion. In August of 2014, EPA offered the PRP group the opportunity to conduct Phase II of the proposed removal action which involved removal activities at approximately 30 additional residences that purportedly exceed certain risk levels for contamination. Alagasco has not agreed to undertake any of the proposed removal activities.

Alagasco has discussed its designation as a PRP with the EPA (including an in-person meeting in Atlanta), and Alagasco has requested additional information from the EPA regarding the testing and removal activities and its designation as a PRP. To this point, Alagasco has not been provided information that would allow it to determine the extent, if any, of its potential liability with respect to the 35th Avenue Superfund Site.

Alagasco has also been approached by a law firm regarding entry into an agreement to toll the statute of limitations with potential plaintiffs related to purported damages allegedly incurred by such potential plaintiffs in connection with the 35th Avenue Superfund Site, and is considering whether to enter into such a tolling arrangement.

The EPA published a proposal to add the 35th Avenue Superfund Site to its National Priorities List (NPL). CERCLA requires that the National Oil and Hazardous Substances Pollution Contingency Plan (NCP) include a list of national priorities among the known releases or threatened releases of hazardous substances, pollutants or contaminants throughout the United States. The NPL constitutes this list. Alagasco submitted comments in opposition to the proposed listing on January 20, 2015.

Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable. To the extent such costs (less any amounts received from insurance proceeds or as contributions from other potential responsible parties) are incurred, Alagasco would defer such costs and recover them over a period of time in accordance with Alagasco's Enhanced Stability Reserve (ESR). Alagasco does not expect potential liabilities that may arise from remediating these sites to have a material impact on the future financial position or results of operations of Alagasco or the Company.

On December 17, 2013, an incident occurred at a Housing Authority apartment complex in Birmingham, Alabama which resulted in one fatality, personal injuries and property damage. Alagasco is cooperating with the National Transportation Safety Board which is investigating the incident. Alagasco has been named as a defendant in several lawsuits arising from the incident, and additional lawsuits and claims may be filed against Alagasco.

Alagasco is, from time to time, a party to various pending or threatened legal proceedings and has accrued a provision for its estimated liability. Certain of these lawsuits include claims for punitive damages in addition to other specified relief. Alagasco recognizes its liability for contingencies when information available indicates both a loss is probable and the amount of the loss can be reasonably estimated. Based upon information presently available, and in light of available legal and other defenses, contingent liabilities arising from threatened and pending litigation are not considered material in relation to the financial position of Alagasco. It should be noted, however, that there is uncertainty in the valuation of pending claims and prediction of litigation results.

Laclede Group

The Company, Laclede Gas and Alagasco are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcomes of such matters will not have a material effect on the statements of income, balance sheets, and statements of cash flows of the Company, Laclede Gas, or Alagasco.

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

($ in millions, except per share amounts)

This section analyzes the financial condition and results of operations of The Laclede Group, Inc. (Laclede Group or the Company), Laclede Gas Company (Laclede Gas), and Alabama Gas Corporation (Alagasco). Laclede Gas and Alagasco are wholly owned subsidiaries of the Company. Collectively, Laclede Gas and Alagasco are referred to as the Utilities. This section includes management’s view of factors that affect the respective business of the Company, Laclede Gas, and Alagasco, explanations of past financial results including changes in earnings and costs from the prior periods, and the effects of such factors on the Company's, Laclede Gas' and Alagasco's 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;

• The results of litigation;

• The availability and access, in general, of funds to meet our debt obligations prior to or when they become due and to fund our operations and necessary capital expenditures, either through (i) cash on hand, (ii) operating cash flow, or (iii) access to the capital markets;

• Retention of, ability to attract, ability to collect from, and conservation efforts of, customers;

• Our ability to comply with all covenants in our indentures and credit facilities any violations of which, if not cured in a timely manner, could trigger a default of our obligations;

• 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, including but not limited to labor disputes and future wage and employee benefit costs including changes in discount rates and returns on benefit plan assets.

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

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RESULTS OF OPERATIONS

Overview

The Company has two key operating segments: Gas Utility and Gas Marketing. Laclede Group’s earnings are primarily derived from its Gas Utility segment, which reflects the regulated activities of the Utilities.

Gas Utility

The Gas Utility segment consists of the regulated businesses of Laclede Gas and Alagasco. Laclede Gas and Alagasco are public utilities engaged in the retail distribution and sale of natural gas serving an area in eastern Missouri through Laclede Gas, an area in western Missouri, through MGE (collectively, the Missouri Utilities) and central and northern Alabama through Alagasco (the Alabama Utility) (collectively, the Utilities). The earnings of the Utilities are primarily generated by the sale of heating energy. The Utilities' earnings are typically concentrated during the heating season of November through April each fiscal year.

Gas Marketing

Laclede Energy Resources (LER) 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 subject to more fluctuations in market conditions than the Utilities. LER entered into a 10-year contract for 1 Bcf of natural gas storage effective August 1, 2013 and has an additional 1 Bcf storage contracted through January 2016.

Other

Other includes:

• unallocated corporate items, including certain debt and associated interest costs,

• Laclede Pipeline Company, a subsidiary of Laclede Group which operates a propane pipeline under Federal Energy Regulatory Commission (FERC) jurisdiction, and

• Laclede Group’s subsidiaries that are engaged in, among other activities, oil production, real estate development, compression of natural gas, and financial investments in other enterprises. All subsidiaries are wholly owned.

EARNINGS

Net income reported by Laclede Group, Laclede Gas and Alagasco are determined in accordance with accounting principles generally accepted in the United States of America (GAAP). Management also uses the non-GAAP measures of net economic earnings, net economic earnings per share, and operating margin when evaluating and reporting results of operations. These non-GAAP operating metrics should not be considered as an alternative to, or more meaningful than, GAAP measures such as net income. These non-GAAP measures are described below and reconciled to the Company's most directly comparable GAAP measures on the following pages.

Non-GAAP Measures - Net Economic Earnings and Net Economic Earnings Per Share

Net Economic Earnings and Net Economic Earnings Per Share are non-GAAP measures that exclude from net income the after-tax impacts of fair value accounting and timing adjustments associated with energy-related transactions as well as acquisition, divestiture, and restructuring activities. These fair value and timing adjustments are made in instances 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

42

uses these non-GAAP measures to evaluate both the Utilities and LER, the net effect of adjustments on the Utilities' earnings are minimal. This is due to gains or losses on Laclede Gas' natural gas derivative instruments being deferred pursuant to its PGA clause, as authorized by the MoPSC; and gains or losses on any Alagasco natural gas derivative instruments being deferred pursuant to its GSA rider, as authorized by the APSC. 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 impact related to unique acquisition, divestiture, and restructuring activities when evaluating on-going performance, and therefore excludes these impacts from net economic earnings. Management believes that this presentation provides a useful representation of operating performance by facilitating comparisons of year-over-year results.

The definition and measurement of net economic earnings provided above is consistent with that used by management and the Board of Directors in assessing the Company's, Laclede Gas' and Alagasco's performance as well as determining performance under the Company's, Laclede Gas', and Alagasco's incentive compensation plans. Further, the Company believes this better enables an investor to view the Company's, Laclede Gas' and Alagasco's performance in that period on a basis that would be comparable to prior periods.

Non-GAAP Measure - Operating Margin

In addition to operating revenues and operating expenses, management also uses the non-GAAP measure of operating margin when evaluating results of operations. As shown in tables within the discussions below, operating margin is calculated by subtracting from operating revenues the natural and propane gas expense and gross receipts tax expense that are collected in revenues. The Utilities pass on to their customers (subject to prudence review by the MoPSC and APSC) increases and decreases in the wholesale cost of natural gas in accordance with their PGA clauses (Missouri Utilities) and GSA rider (Alagasco). The wholesale cost of natural gas similarly impacts the Company's non-regulated businesses and the amounts they can charge their customers. 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 and has no direct effect on operating margin. As these costs are included in operating revenues and operating expenses and management does not have any control over these amounts, management believes that operating margin is a more useful measure. In addition, it is management's belief that operating margin and the remaining operating expenses are more useful measures in assessing the Company's and the Utilities' performance because management has more ability to influence these items.

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THREE MONTHS ENDED MARCH 31, 2015

LACLEDE GROUP

Net Income and Net Economic Earnings

Reconciliation of the Company's Net Economic Earnings to the most comparable GAAP measure, Net Income, is as follows:

($ Millions, except per share amounts)		Gas Utility			Gas Marketing			Other			Consolidated			Per Share Amounts**
Three Months Ended March 31, 2015
	Net Income (Loss) (GAAP)	$	96.2		$	0.3		$	(2.1	)	$	94.4		$	2.18
	Unrealized (gain) loss on energy-related derivatives*	(0.1		)	2.7			—			2.6			0.06
	Lower of cost or market inventory adjustments*	—			(1.0		)	—			(1.0		)	(0.02		)
	Realized loss on economic hedges prior      to the sale of the physical commodity*	—			0.1			—			0.1			—
	Acquisition, divestiture and restructuring activities*	0.4			—			1.1			1.5			0.03
	Net Economic Earnings (Loss) (Non-GAAP)	$	96.5		$	2.1		$	(1.0	)	$	97.6		$	2.25
Three Months Ended March 31, 2014
	Net Income (Loss) (GAAP)	$	44.1		$	9.4		$	(1.3	)	$	52.2		$	1.59
	Unrealized gain on energy-related derivatives*	—			(1.7		)	—			(1.7		)	(0.04		)
	Lower of cost or market inventory adjustments*	—			(0.5		)	—			(0.5		)	(0.02		)
	Realized gain on economic hedges prior      to the sale of the physical commodity*	—			(0.1		)	—			(0.1		)	(0.01		)
	Acquisition, divestiture and restructuring activities*	0.6			—			1.2			1.8			0.06
	Net Economic Earnings (Loss) (Non-GAAP)	$	44.7		$	7.1		$	(0.1	)	$	51.7		$	1.58

* 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.

** 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.

Consolidated

Laclede Group’s net income was $94.4 for the three months ended March 31, 2015, compared with $52.2 for the three months ended March 31, 2014. Basic and diluted earnings per share for the three months ended March 31, 2015 were $2.18, compared with basic and diluted earnings per share of $1.59 for the three months ended March 31, 2014. Net income increased due to improved results reported by Laclede Group's Gas Utility segment, which reflects the inclusion of $46.3 from Alagasco operations and $5.8 growth in the Missouri Utilities' net income. The increased net income from the Gas Utility segment was partially offset by a $9.1 decrease in net income from the Gas Marketing segment and a slightly higher loss from other non-utility activities. Laclede Group's net economic earnings were $97.6 for the three months ended March 31, 2015, up from $51.7 for the same period last year due largely to the inclusion of Alagasco. Net economic earnings per share were $2.25 for the three months ended March 31, 2015, up from $1.58 for last year's second quarter, reflecting the accretive impact of the Alagasco acquisition.

Gas Utility

Gas Utility net income and net economic earnings increased by $52.1 and $51.8, respectively. The increase was primarily due to higher operating margin of $131.0, reflecting the inclusion of Alagasco operating margin totaling $126.1 and growth in the Missouri Utilities. These benefits were partially offset by an increase in other operating expenses of $34.9 (including $37.0 from Alagasco offset in part by lower costs at the Missouri Utilities), an increase in depreciation and amortization expenses of $12.1 (including $11.7 from Alagasco), and a $3.9 increase in interest expense (including $3.5 from Alagasco).

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Gas Marketing

The Gas Marketing segment reported GAAP net income totaling $0.3 for the three months ended March 31, 2015, a decrease of $9.1 compared with the same period last year. Net economic earnings for the three months ended March 31, 2015 decreased $5.0 compared with the three months ended March 31, 2014. The decreases in net income and net economic earnings were primarily attributable to the prior year benefiting from extreme cold weather by $5.6, with the impact to net economic earnings being mitigated by $4.1 in net favorable derivative impact year over year, as discussed below.

Other

The combined net loss for the Company's other non-utility activities was $0.8 higher for the three months ended March 31, 2015 compared with the same period last year. Net loss in the current year was affected by $5.9 higher interest expense, primarily relating to Laclede Group debt issued for the Alagasco acquisition, partly offset by a tax benefit and lower operating expenses of the Company's other non-utility activities, including Spire natural gas fueling solutions and unallocated corporate expenses.

Operating Revenues and Operating Expenses

Reconciliations of the Company's operating margin to the most directly comparable GAAP measure are shown below.

($ Millions)		Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Three Months Ended March 31, 2015
	Operating revenues	$	849.0	$	44.1	$	0.9		$	(16.6	)	$	877.4
	Natural and propane gas expense	499.1		42.0		0.1			(16.3		)	524.9
	Gross receipts tax expense	44.1		—		—			—			44.1
	Operating margin (non-GAAP)	305.8		2.1		0.8			(0.3		)	308.4
	Depreciation and amortization	32.2		0.1		0.2			—			32.5
	Other operating expenses	115.6		1.4		1.5			(0.3		)	118.2
	Operating income (loss) (GAAP)	$	158.0	$	0.6	$	(0.9	)	$	—		$	157.7
Three Months Ended March 31, 2014
	Operating revenues	$	638.6	$	80.5	$	0.8		$	(25.4	)	$	694.5
	Natural and propane gas expense	430.5		63.6		—			(25.2		)	468.9
	Gross receipts tax expense	33.3		0.1		—			—			33.4
	Operating margin (non-GAAP)	174.8		16.8		0.8			(0.2		)	192.2
	Depreciation and amortization	20.1		0.1		0.1			—			20.3
	Other operating expenses	80.7		1.2		3.0			(0.2		)	84.7
	Operating income (loss) (GAAP)	$	74.0	$	15.5	$	(2.3	)	$	—		$	87.2

Consolidated

Laclede Group reported operating revenues of $877.4 for the three months ended March 31, 2015 compared with $694.5 for the same period last year. Laclede Group's operating margin increased $116.2 for the three months ended March 31, 2015 compared with the same period last year due to an increase in the Gas Utility segment partially offset by a decrease in Gas Marketing, as discussed separately below. Depreciation and amortization expenses were $32.5 for the three months ended March 31, 2015, compared with $20.3 for the same period last year. Other operating expenses were $118.2 for the three months ended March 31, 2015, compared with $84.7 for the same period last year. The increase was due to the inclusion of Alagasco other operating expenses and depreciation and amortization expenses totaling $37.0 and $11.7, respectively. The inclusion of Alagasco expenses were partly offset by lower operating expenses at Laclede Gas, primarily driven by efficiencies resulting from our recent acquisitions.

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Gas Utility

Operating Revenues -Gas Utility operating revenues for the three months ended March 31, 2015 were $849.0, or $210.4 more than the same period last year. The increase in Gas Utility operating revenues was attributable to the following factors:

($ Millions)	Variance
Alagasco
Customer revenue	$	233.3
Laclede Gas
Higher Infrastructure System Replacement Surcharge (ISRS) revenues and base rate increases	4.2
Variable rate design for MGE	8.6
Higher wholesale gas costs passed on to customers	3.6
Lower system and off-system sales volumes and other variations	(39.3		)
Total Laclede Gas revenue variance	(22.9		)
Total Variation	$	210.4

Temperatures in the Missouri Utilities’ service areas during the three months ended March 31, 2015 were 11.6% warmer than the same period a year earlier, resulting in comparatively lower gas usage on a per customer basis, but were 3.3% colder than normal. The Missouri Utilities' total system therms sold and transported were 777.4 million for the three months ended March 31, 2015, compared with 878.2 million for the same period last year. This decrease versus the prior year period was due to warmer temperatures and decreased heating demand in our service areas, reducing the demand for gas supply resources.

Operating Margin- Gas Utility operating margin was $305.8 for the three months ended March 31, 2015, a $131.0 increase over the same period last year. The increase was attributable to the following factors:

($ Millions)	Variance
Operating margin from Alagasco	$	126.1
Variable rate design for MGE	8.6
Higher Infrastructure System Replacement Surcharge (ISRS) and base rate increases	4.2
Customer growth activity	1.1
Lower system and off-system sales volumes and other variations	(9.0		)
Total Variation	$	131.0

As shown, the increase was primarily attributable to the addition of Alagasco and a rate structure change with MGE creating a more seasonal earnings pattern, partially offset by the return of more normal weather (and consequently, more normal volumes and levels of asset optimization) in the current year.

Operating Expenses -Other operating expenses and depreciation and amortization expenses for the three months ended March 31, 2015 increased $34.9 and $12.1, respectively, from the same period last year. The increase was primarily due to the inclusion of Alagasco operating expenses and depreciation and amortization expenses totaling $37.0 and $11.7, respectively, partly offset by $2.0 lower expenses at Laclede Gas.

Gas Marketing

Operating Revenues -Operating revenues decreased $36.4 versus the prior year period. Of this decline, $29.7 was due to very favorable market conditions last year resulting from the extreme cold. The second quarter of Fiscal 2014 benefited from higher volumes sold and higher per unit gas sales prices as the extremely cold weather in the Midwest resulted in a constrained pipeline infrastructure that created higher market volatility between differing regions. The remaining $6.7 revenue variance was due to differences in net mark-to-market impacts on derivatives between the current year and prior year period.

Operating Margin- Gas Marketing operating margin during the three months ended March 31, 2015 decreased $14.7 from the same period last year. The decrease in operating margin is primarily due to the prior year quarter achieving $9.0 higher sales margins reflecting greater market volatility and basis differentials resulting from the extremely cold weather, combined with the current year experiencing $6.7 lower pre-tax income associated with unrealized gains on derivatives offset by higher inventory adjustments expenses associated with lower of cost or market.

Other

Operating Revenues and Operating Expenses -Other operating revenues increased by $0.1 during the three months ended March 31, 2015 versus the prior year due to higher throughput at the Spire compressed natural gas station. Other operating

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expenses decreased by $1.5 during the three months ended March 31, 2015 from the same period a year earlier, reflecting infrastructure development expenditures incurred in the 2014 quarter that were not repeated in 2015.

Interest Charges

Consolidated interest charges during the three months ended March 31, 2015 increased $9.8 from the same period last year. The increase was primarily due to the addition of Alagasco interest expense of $3.5 and the net effect of the Company's August 2014 issuance of long-term debt totaling $625.0 and the June 2014 issuance of equity units totaling $143.8. For the three months ended March 31, 2015 and 2014, average short-term borrowings were $377.5 and $105.9, respectively, and the average interest rates on these borrowings were 0.7% and 0.3%, respectively.

Income Taxes

Consolidated income tax expense during the three months ended March 31, 2015 increased $19.5 from the same period last year primarily due to higher pre-tax income partially offset by a lower effective tax rate. The current year rate of 32.2% is about 0.5 percentage points lower than the prior year rate primarily due to an increase in the proportion of expenses being capitalized for tax purposes.

LACLEDE GAS

	Three Months Ended   March 31,
($ Millions)	2015		2014
Operating revenues	$	615.7	$	638.8
Natural and propane gas expense	402.7		430.5
Gross receipts tax expense	33.3		33.3
Operating margin (non-GAAP)	179.7		175.0
Depreciation and amortization	20.5		20.1
Other operating expenses	78.6		80.4
Operating income (GAAP)	$	80.6	$	74.5
Net Income	$	49.9	$	44.2

Operating revenues during the three months ended March 31, 2015 decreased $23.1 from the same period last year primarily due to lower system sales, partially offset by the introduction at MGE of variable rate design and higher wholesale gas costs passed on to customers. Operating margin during the three months ended March 31, 2015 increased $4.7 from the same period last year due primarily to base rate increases and modest customer growth. Other Operating expenses during the three months ended March 31, 2015 decreased $1.8 from the same period last year due principally to cost efficiencies. Net income during the three months ended March 31, 2015 increased $5.7 from the same period last year, primarily due to the factors discussed above.

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ALAGASCO

	Three Months Ended   March 31,
($ Millions)	2015		2014
Operating revenues	$	233.3	$	263.9
Natural gas expense	96.4		128.1
Gross receipts tax expense	10.8		13.0
Operating margin (non-GAAP)	126.1		122.8
Depreciation and amortization	11.7		11.4
Other operating expenses	37.0		39.0
Operating income (GAAP)	$	77.4	$	72.4
Net Income	$	46.3	$	43.1

Operating revenues during the three months ended March 31, 2015 decreased $30.6 versus the same period last year due to the impact of a $10.9 decrease in customer usage, which was higher in 2014 as a result of colder weather, and $28.1 due to lower gas prices passed through to customers, partially offset by revenue reduction for RSE adjustments being $7.7 less in 2015 versus 2014. Operating margin increased $3.3 versus the prior year period, principally due to lower RSE adjustments in the current year. Other operating expenses during the three months ended March 31, 2015 decreased $2.0 from the same period last year, primarily driven by lower bad debt and professional services expenses. Net income during three months ended March 31, 2015 increased $3.2 from the same period last year, primarily due to the factors discussed above.

For further information on the GSA and Rate Stabilization and Equalization (RSE) mechanisms, please see Note 1, Summary of Significant Accounting Policies, and Note 3, Regulatory Matters, of Alagasco's Annual Report on Form 10-KT for the transition period ended September 30, 2014 .

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SIX MONTHS ENDED MARCH 31, 2015

LACLEDE GROUP

Net Income and Net Economic Earnings

Reconciliation of the Company's Net Economic Earnings to the most comparable GAAP number, Net Income, is as follows:

		Gas Utility			Gas Marketing			Other			Total			Per Share Amounts**
Six Months Ended March 31, 2015
	Net Income (Loss) (GAAP)	$	145.8		$	2.5		$	(6.8	)	$	141.5		$	3.26
	Unrealized gain on energy-related derivatives*	(0.1		)	(0.3		)	—			(0.4		)	(0.01		)
	Lower of cost or market inventory adjustments*	—			0.2			—			0.2			0.01
	Realized loss on economic hedges prior      to the sale of the physical commodity*	—			0.1			—			0.1			—
	Acquisition, divestiture and restructuring activities*	0.6			—			1.3			1.9			0.05
	Net Economic Earnings (Loss) (Non-GAAP)	$	146.3		$	2.5		$	(5.5	)	$	143.3		$	3.31
Six Months Ended March 31, 2014
	Net Income (Loss) (GAAP)	$	79.5		$	9.9		$	(1.6	)	$	87.8		$	2.68
	Unrealized gain on energy-related derivatives*	—			(1.3		)	—			(1.3		)	(0.05		)
	Lower of cost or market inventory adjustments*	—			(0.6		)	—			(0.6		)	(0.02		)
	Realized gain on economic hedges prior      to the sale of the physical commodity*	—			(0.1		)	—			(0.1		)	—
	Acquisition, divestiture and restructuring activities*	1.0			—			1.2			2.2			0.07
	Net Economic Earnings (Loss) (Non-GAAP)	$	80.5		$	7.9		$	(0.4	)	$	88.0		$	2.68

* 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.

** 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.

Consolidated

Laclede Group’s net income was $141.5 for the six months ended March 31, 2015, compared with $87.8 for the six months ended March 31, 2014. Basic and diluted earnings per share for the six months ended March 31, 2015 were $3.27 and $3.26 respectively, compared with basic and diluted earnings per share of $2.68 for the six months ended March 31, 2014. Net income increased primarily due to improved results reported by Laclede Group's Gas Utility segment, which reflects the inclusion of $56.9 from Alagasco operations and $9.4 income growth from the Missouri Utilities. The higher Gas Utility results were partially offset by decreased earnings from the Gas Marketing segment of $7.4 and a $5.2 higher loss in Other. Net economic earnings were $143.3 for the six months ended March 31, 2015, up from $88.0 for the same period last year. The corresponding net economic earnings per share were $3.31 and $2.68, respectively.

Gas Utility

Gas Utility net income and net economic earnings increased by $66.3 and $65.8, respectively, for the six months ended March 31, 2015, compared with the six months ended March 31, 2014. The increase was primarily due to higher operating margin (a non-GAAP measure, as discussed below) of $202.5, which reflects the inclusion of Alagasco operating margin totaling $193.9 and $8.6 growth generated by the Missouri Utilities. These benefits were partially offset by an increase in other operating expenses of $71.8 (including $72.6 from Alagasco) and an increase in depreciation and amortization expenses of $24.1 (including $23.5 from Alagasco), as well as higher interest expense totaling $6.7 and increased income tax expense of $34.7, both primarily attributable to the inclusion of Alagasco in fiscal 2015 results.

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Gas Marketing

The Gas Marketing segment reported GAAP net income totaling $2.5, a decrease of $7.4 compared with the same period last year. Net economic earnings for the six months ended March 31, 2015 decreased $5.4 compared with the six months ended March 31, 2014. The decreases in net income and net economic earnings were primarily attributable to a decrease in operating margin, as discussed below.

Other

Other operations reported a higher combined net loss of $5.2 as compared with the same period last year. The increase in net loss was primarily the result of $11.7 in higher interest expense relating to the 2014 debt issued to finance the Alagasco acquisition, offset by an income tax benefit and slightly lower operating expenses of the Company's other non-utility activities, including Spire natural gas fueling solutions and unallocated corporate expenses.

Operating Revenues and Operating Expenses

Reconciliations of the Company's operating margin to the most directly comparable GAAP measure are shown in the table below:

		Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Six Months Ended March 31, 2015
	Operating revenues	$	1,431.4	$	106.3	$	1.8		$	(42.5	)	$	1,497.0
	Natural and propane gas expense	828.9		99.1		0.2			(42.0		)	886.2
	Gross receipts tax expense	71.0		0.1		—			—			71.1
	Operating margin (non-GAAP)	531.5		7.1		1.6			(0.5		)	539.7
	Depreciation and amortization	64.2		0.2		0.3			—			64.7
	Other operating expenses	224.1		2.7		3.7			(0.5		)	230.0
	Operating income (loss) (GAAP)	$	243.2	$	4.2	$	(2.4	)	$	—		$	245.0
Six Months Ended March 31, 2014
	Operating revenues	$	1,073.9	$	133.2	$	1.4		$	(45.4	)	$	1,163.1
	Natural and propane gas expense	692.1		114.1		—			(45.0		)	761.2
	Gross receipts tax expense	52.8		0.1		—			—			52.9
	Operating margin (non-GAAP)	329.0		19.0		1.4			(0.4		)	349.0
	Depreciation and amortization	40.1		0.2		0.2			—			40.5
	Other operating expenses	152.3		2.4		4.1			(0.4		)	158.4
	Operating income (loss) (GAAP)	$	136.6	$	16.4	$	(2.9	)	$	—		$	150.1

Consolidated

Laclede Group reported operating revenues of $1,497.0 for the six months ended March 31, 2015 compared with $1,163.1 for the same period last year. Laclede Group's operating margin increased $190.7 for the six months ended March 31, 2015 compared with the same period last year due to higher Gas Utility operating margin offsetting lower Gas Marketing results, as discussed below. Depreciation and amortization expenses were $64.7 for the six months ended March 31, 2015, compared with $40.5 for the same period last year. Other operating expenses were $230.0 for the six months ended March 31, 2015, compared with $158.4 for the same period last year. The increase was primarily due to Alagasco operating expenses and depreciation and amortization expenses totaling $72.6 and $23.5, respectively.

Gas Utility

Operating Revenues - Gas Utility operating revenues for the six months ended March 31, 2015 were $1,431.4, or $357.5 more than the same period last year. The increase in Gas Utility operating revenues was attributable to the following factors:

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	Variance
Customer revenue from Alagasco	$	353.3
Lower system and off-system sales volumes and other variations	(39.8		)
MGE Variable Rate	11.2
Higher wholesale gas costs passed on to the Missouri Utilities' customers	29.7
Base rate increases and ISRS charges	8.4
Higher optimization of assets in the prior year	(5.3		)
Total Variation	$	357.5

Temperatures in Laclede Gas’ service areas during the six months ended March 31, 2015 were 9.9% warmer than the same period last year, resulting in lower gas usage and operating revenues on a year-over-year comparative basis, but 2.1% colder than normal. The Missouri Utilities' total system therms sold and transported were 1,320.7 million for the six months ended March 31, 2015, compared with 1,440.7 million for the same period last year. Total off-system therms sold and transported were 124.4 million for the six months ended March 31, 2015, compared with 107.7 million for the same period last year. This increase was due to warmer temperatures and decreased heating demand in the Missouri service areas, increasing the gas supply resources available for off-system sales or capacity release.

Operating Margin - Gas Utility operating margin was $531.5 for the six months ended March 31, 2015, a $202.5 increase over the same period last year. The increase was attributable to the following factors:

	Variance
Operating margin from Alagasco	$	193.9
MGE variable rate design	11.2
Infrastructure System Replacement Charges and higher base rate	8.4
Customer growth activity	1.4
Lower system and off-system sales volumes and other variations	(10.5		)
Higher optimization of assets in the prior year	(1.9		)
Total Variation	$	202.5

The increase was primarily due to the impact of Alagasco's operating margin totaling $193.9, and the Missouri Utilities' base rate increases and ISRS charges, offset partially by lower system volumes due to the warmer weather experienced in the current year compared to the prior year.

Operating Expenses - Other operating expenses and depreciation and amortization expenses for the six months ended March 31, 2015 increased $71.8 and $24.1, respectively, from the same period last year. The increase was primarily due to the inclusion of Alagasco operating expenses and depreciation and amortization expenses totaling $72.6 and $23.5, respectively, in the first six months of fiscal year 2015. The increase due to the inclusion of Alagasco was partially offset by lower other operating expense at Laclede Gas due to the impact of warmer weather reflected in lower provision for uncollectible accounts, lower maintenance costs and lower employee-related expenses. The remaining depreciation and amortization expense increase of $0.6 was primarily due to additional depreciable property.

Gas Marketing

Operating Revenues - Gas Marketing operating revenues during the six months ended March 31, 2015 decreased $26.9 from the same period last year due to the prior year benefiting from higher volumes sold and higher per unit gas sales prices as the colder weather in the Midwest resulted in a constrained pipeline infrastructure creating higher market volatility between differing regions. The prior year period also benefited from mark-to-market impact on derivatives and inventory.

Operating Margin - Gas Marketing operating margin during the six months ended March 31, 2015 decreased $11.9 from the same period last year. Of this decrease, $9.4 was primarily attributable to higher sales margins last year (reflecting higher market volatility and basis differentials of natural gas prices) and the expiration of a favorable gas supply contract in the first quarter of fiscal 2014. The remaining variance was due to $2.5 higher pre-tax income in the prior year associated with unrealized gains on derivatives and inventory adjustments associated with lower of cost or market.

Other

Operating Revenues and Operating Expenses - Other operating revenues increased by $0.4 for the six months ended March 31, 2015 compared to the first half of fiscal 2014. The increase is primarily attributable to higher Spire compressed natural gas revenues. Other operating expenses were slightly below last year's levels during the six months ended March 31, 2015.

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Interest Charges

Consolidated

Interest charges during the six months ended March 31, 2015 increased $18.5 from the same period last year. The increase was primarily due to the Company's August 2014 issuance of long-term debt totaling $625.0, the June 2014 issuance of equity units totaling $143.8, and the inclusion of Alagasco interest expense in the current year totaling $7.3, partially offset by Laclede Gas' early redemption of $80.0 of 6.35% first mortgage bonds on January 6, 2014. For the six months ended March 31, 2015 and 2014, average short-term borrowings were $358.0 and $99.5, respectively, and the average interest rates on those borrowings were 0.6% and 0.3%, respectively.

Gas Utility

Interest charges during the six months ended March 31, 2015 increased $6.7 from the same period last year. The increase was primarily due to the inclusion of Alagasco interest expense in the current year totaling $7.3, offset by the early redemption of $80.0 of 6.35% first mortgage bonds on January 6, 2014. For the six months ended March 31, 2015 and 2014, average short-term borrowings were $297.7 and $138.7, respectively, and the average interest rates on those borrowings were 0.5% and 0.3%, respectively.

Income Taxes

Consolidated income tax expense during the six months ended March 31, 2015 increased $23.4 from the same period last year primarily due to higher pre-tax income partially offset by a lower effective tax rate. The current year rate of 32.2% is about 1.1 percentage points lower than the prior year rate primarily due to an increase in the proportion of expenses being capitalized for tax purposes.

LACLEDE GAS

	Six Months Ended   March 31,
($ Millions)	2015		2014
Operating revenues	$	1,078.1	$	1,074.0
Natural and propane gas expense	686.1		692.1
Gross receipts tax expense	54.4		52.8
Operating margin (non-GAAP)	337.6		329.1
Depreciation and amortization	40.7		40.1
Other operating expenses	151.5		152.2
Operating income (GAAP)	$	145.4	$	136.8
Net Income	$	88.9	$	79.5

Operating revenues during the six months ended March 31, 2015 increased $4.1 from the same period last year primarily due to higher wholesale gas costs passed on to customers, higher pricing and ISRS charges, offset by the impact of lower volumes. Operating margin increased $8.5 primarily due to higher ISRS charges, base rate increases and modest customer growth. Other operating expenses during the six months ended March 31, 2015 decreased $0.7 from the same period last year, partly offset higher depreciation. Net income increased $9.4, primarily due to the factors discussed above.

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ALAGASCO

	Six Months Ended   March 31,
($ Millions)	2015		2014
Operating revenues	$	353.3	$	406.7
Natural gas expense	142.8		180.1
Gross receipts tax expense	16.6		19.4
Operating margin (non-GAAP)	193.9		207.2
Depreciation and amortization	23.5		22.6
Other operating expenses	72.6		77.4
Operating income (GAAP)	$	97.8	$	107.2
Net Income	$	56.9	$	62.9

Operating revenues for the six months ended March 31, 2015 decreased $53.4 from the same period last year. The primary drivers were due to the impact of the regulatory treatment of the gain on the sale of the Metro Operations Center of $10.9 in the first quarter of 2014, lower natural gas prices passed onto customers of $35.8 and lower customer usage offset by RSE adjustments. Operating margin decreased $13.3 primarily due to the sale of the Metro Operations Center discussed above, lower gas costs, and decreased customer usage, partially offset by RSE adjustments in the first quarter. Other operating expenses for the six months ended March 31, 2015 decreased $4.8 from the same period last year primarily driven by decreases in professional services, labor and employee-related expenses, business development and operations. Net income during six months ended March 31, 2015 decreased $6.0 from the same period last year primarily due to the factors discussed above.

For further information on the GSA and RSE mechanisms, please see Note 1, Summary of Significant Accounting Policies, and Note 3, Regulatory Matters, of Alagasco's Annual Report on Form 10-KT for the transition period ended September 30, 2014.

REGULATORY AND OTHER MATTERS

Laclede Gas

On December 19, 2014, the MoPSC Staff proposed a contingent disallowance of approximately $1.0 related to Laclede Gas' recovery of its purchase gas costs applicable to fiscal 2013. Laclede Gas opposes the disallowance and believes that it can demonstrate that its actions are in all cases reasonable and justified.

On April 17, 2015, Laclede Gas resubmitted ISRS filings for Laclede Gas and MGE totaling $5.5 and $2.9, respectively, to replace filings originally made on January 30, 2015. This was done as part of an agreement to reserve treatment of certain projects until a later date and fully include actual results of other projects previously estimated.

Alagasco

For GAAP purposes for the three and six months ended March 31, 2015, Alagasco recorded an estimated net reduction to operating revenues of $8.5 and $12.7, respectively, to bring the expected rate of return on average common equity at the end of the year to within the allowed range of return.

Under the provisions of RSE there was no annual increase to rates required for Rate Year 2015. For the Rate Year ended September 30, 2014, Alagasco had a $3.2 reduction in rates effective December 1, 2014.

For the Rate Year ended September 30, 2014, Alagasco's operations and maintenance (O&M) expenses fell below the Index Range of the Cost Control Mechanism (CCM) resulting in Alagasco benefiting by one half of the difference, or $2.4 pre-tax, with the related impact to rates effective December 1, 2014. The Company also filed for a Negative Salvage Refund (NSR) pass back of $13.4 effective December 1, 2014.

Laclede Group

Please see the Environmental Matters section for information relative to environmental matters. Laclede Group, Laclede Gas and Alagasco are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcomes of these matters will not have a material effect on the consolidated financial position, results of operations, or cash flows of the Company, Laclede Gas or Alagasco.

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CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources is based upon our financial statements, which have been prepared in accordance with 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 financial statements are described in Item 7 of the Company's, Laclede Gas' and Alagasco's Annual Reports on Form 10-K or 10-KT for the fiscal year or transition period, as applicable, ended September 30, 2014 and include the following:

• Regulatory accounting,

• Employee benefits and postretirement obligations, and

• Asset retirement obligations.

Additionally, goodwill is a critical accounting policy also included in the Company's and Laclede Gas' Annual Reports on Form

10-K for the fiscal year ended September 30, 2014.

There were no significant changes to these critical accounting policies during the six months ended March 31, 2015.

For discussion of other significant accounting policies, see Note 1 of the Notes to the Financial Statements included in this Form 10-Q as well as Note 1 of the Notes to the Financial Statements included in the Company’s, Laclede Gas', and Alagasco's Annual Reports on Form 10-K or 10-KT for the fiscal year or transition period, as applicable, ended September 30, 2014.

ACCOUNTING PRONOUNCEMENTS

The Company, Laclede Gas and Alagasco have evaluated or are in the process of evaluating the impact that recently issued accounting standards will have on the companies' financial position or results of operations upon adoption. For disclosures related to the adoption of new accounting standards, see the New Accounting Pronouncements section of Note 1 of the Notes to the Financial Statements.

FINANCIAL CONDITION

Cash Flows

Laclede Group

The Company’s short-term borrowing requirements typically peak during colder months when the Utilities borrow money to cover the lag between purchases of natural gas and customer payments for that gas. Changes in the wholesale cost of natural gas (including cash payments for margin deposits associated with the Missouri Utilities’ use of natural gas derivative instruments), variations in the timing of collections of gas cost under the Missouri Utilities’ PGA clauses and Alagasco's GSA rider, 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 Utilities' cash provided by or used in operating activities.

Net cash provided by operating activities was $279.9 for the six months ended March 31, 2015, compared with $142.8 for the six months ended March 31, 2014. The increase was primarily due to the inclusion of Alagasco, which provided $89.2 of cash from operating activities. The remaining $47.9 was driven by the seasonality in accounts receivable balances, timing of collections of gas costs under the PGA, and a larger drop in natural gas inventory levels. These increases in net cash provided were partially offset by the effects of seasonality of accounts payable associated with natural gas purchases, higher deferred purchased costs of gas under the PGA, and other working capital changes.

Net cash used in investing activities for the six months ended March 31, 2015 was $138.5, compared with $38.4 for the six months ended March 31, 2014. The increase was driven by higher capital expenditures of approximately $61.3, including $34.2 at Alagasco and a $26.3 increase at Laclede Gas, as discussed separately below. Additionally, the current year period included a payment for the final reconciliation amount associated with the Alagasco acquisition, whereas the prior year period included the receipt of $23.9 from Energy Transfers Equity, LP (ETE) for the final reconciliation amount associated with the MGE acquisition and the receipt of $11.0 associated with the sale of New England Gas Company (NEG) to Algonquin Power & Utilities Corp. (APUC).

Net cash used in financing activities was $110.6 for the six months ended March 31, 2015, compared with $146.5 for the six months ended March 31, 2014. The decrease reflects lower amounts of long-term debt repayments, partially offset by an increase in dividends paid due to both an increase in shares outstanding and a higher dividend rate.

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Laclede Gas

Net cash provided by operating activities was $223.2 for the six months ended March 31, 2015, compared with $144.5 for the six months ended March 31, 2014. The increase in cash provided during the six months ended March 31, 2015 was primarily due to timing of collections of gas costs under the PGA, the seasonality of accounts receivable balances, a larger drop in natural gas inventory levels, and increased net income. These increases were partially offset by the seasonality of accounts payable associated with natural gas purchases, higher deferred purchased costs of gas under the PGA, and other working capital changes.

Net cash used in investing activities for the six months ended March 31, 2015 was $93.4, compared with $48.0 for the six months ended March 31, 2014. The increase in cash used is attributable to capital expenditures in the six month period for Laclede Gas and MGE being $26.3 above prior year levels, primarily due to facilities improvements, MGE integration, pipeline replacement and the timing of meter purchases. In addition, net cash used in the prior year period was reduced by the receipt of funds from ETE for the final reconciliation amount associated with the MGE acquisition.

Net cash used in financing activities was $124.2 for the six months ended March 31, 2015, compared with $115.4 for the six months ended March 31, 2014. The increase in cash used reflects higher net repayments of short-term debt, lower net borrowing from Laclede Group, and higher dividends paid to Laclede Group, largely offset by the effect of the redemption in the prior year of $80.0 of long-term debt.

Alagasco

Net cash provided by operating activities totaled $89.2 for the six months ended March 31, 2015, compared with $116.8 for the six months ended March 31, 2014. This decrease in cash provided consisted primarily of increased working capital needs.

Net cash used in investing activities for the six months ended March 31, 2015 was $34.4, compared with $31.3 for the six months ended March 31, 2014. This decrease in cash used was related to a decrease in capital expenditures, principally due to timing.

Net cash used in financing activities was $25.0 for the six months ended March 31, 2015, compared with $59.9 for the six months ended March 31, 2014. This decrease in cash used reflects short-term debt net issuances in the current year as compared to short-term debt net repayments last year and $10.8 of dividends paid last year, partially offset by the redemption of $34.7 of long-term debt in the current period.

LIQUIDITY AND CAPITAL RESOURCES

Cash and Cash Equivalents

Laclede Group had no short-term investments as of or in the six months ended March 31, 2015.

Laclede Gas had no temporary cash investments as of March 31, 2015. The balance of short-term investments ranged between $0 and $10.0 during the six months ended March 31, 2015. Laclede Group elected to provide a portion of Laclede Gas’ short-term funding through intercompany lending during the six months ended March 31, 2015.

Alagasco had no short-term investments as of or in the six months ended March 31, 2015. Its bank deposits were used to support working capital needs of the business.

Short-term Debt

The Company’s and the Utilities' 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, 2015, Laclede Gas had a syndicated line of credit of $450.0 in place with nine banks which matures on September 3, 2019. The largest portion provided by a single bank under the line is 15.6%. The Laclede Gas line of credit includes a covenant limiting total debt, including short-term debt, to no more than 70% of total capitalization. As defined in the line of credit, total debt was 47% of total capitalization on March 31, 2015.

On September 2, 2014, Alagasco entered into a new $150.0 syndicated line of credit with twelve banks and extinguished the line that was in place prior to its acquisition by Laclede Group. The largest portion provided by a single bank is 10%. The line of credit, which matures on September 2, 2019, has a covenant limiting total debt to 70% of Alagasco's total capital. As defined in the line of credit, total debt was 21% of total capitalization on March 31, 2015.

Short-term cash requirements outside of the Utilities have generally been funded by Laclede Group or met with internally generated funds. At March 31, 2015, Laclede Group had a $150.0 syndicated line of credit with nine banks maturing on September 3, 2019, with the largest portion provided by a single bank being 15.6%. 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 defined in the line of credit, this ratio stood at 56% on March 31, 2015. Laclede Group’s line may be used to provide for the funding needs of various subsidiaries.

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Laclede Group

Information about Laclede Group's consolidated short-term borrowings (excluding the current portion of long-term debt) during the six months ended March 31, 2015 and as of March 31, 2015, is presented below:

($ Millions)	Laclede Gas Short Term Borrowings	Laclede Group Bank Line Borrowings	Alagasco Bank Line Borrowings	Total Short-Term Borrowings
Six Months Ended March 31, 2015
Weighted average borrowings outstanding	$267.3	$60.1	$30.6	$358.0
Weighted average interest rate	0.4%	1.4%	1.1%	0.6%
Range of borrowings outstanding	$142.6 – $341.0	$32.5 – $80.0	$14.0 – $69.5	$247.6 – $488.5
As of March 31, 2015
Borrowings outstanding at end of period	$142.6	$80.0	$25.0	$247.6
Weighted average interest rate	0.6%	1.4%	0.9%	0.9%

Based on average short-term borrowings for the six months ended March 31, 2015, an increase in the average interest rate of 100 basis points would decrease the Company's pre-tax earnings and cash flows by approximately $3.6 on an annual basis, portions of which may be offset through the application of PGA carrying costs.

Laclede Gas

Information about Laclede Gas' short-term borrowings during the six months ended March 31, 2015 and as of March 31, 2015, is presented below:

($ Millions)	External Short Term Borrowings *	Laclede Gas Borrowings from Laclede Group	Total Short-Term Borrowings
Six Months Ended March 31, 2015
Weighted average borrowings outstanding	$267.3	$0.1	$267.4
Weighted average interest rate	0.4%	0.4%	0.4%
Range of borrowings outstanding	$142.6 -$341.0	$0.0 - $10.4	$153.0 - $341.0
As of March 31, 2015
Borrowings outstanding at end of period	$142.6	$10.4	$153.0
Weighted average interest rate	0.6%	0.6%	0.6%

* External short-term borrowings consist primarily of commercial paper, but include one day of borrowing under the bank line of credit.

Based on average short-term borrowings for the six months ended March 31, 2015, an increase in the average interest rate of 100 basis points would decrease Laclede Gas’ pre-tax earnings and cash flows by approximately $2.7 on an annual basis, portions of which may be offset through the application of PGA carrying costs.

Alagasco

Information about Alagasco's short-term borrowings (excluding the current portion of long-term debt) during the six months ended March 31, 2015 and as of March 31, 2015, is presented below:

($ Millions)	Total Short-Term Borrowings
Six Months Ended March 31, 2015
Weighted average borrowings outstanding	$30.6
Weighted average interest rate	1.1%
Range of borrowings outstanding	$14.0 - $69.5
As of March 31, 2015
Borrowings outstanding at end of period	$25.0
Weighted average interest rate	0.9%

Based on average short-term borrowings for the six months ended March 31, 2015, an increase in the average interest rate of 100 basis points would decrease Alagasco's pre-tax earnings and cash flows by approximately $0.3 on an annual basis, portions of which may be offset by gas supply adjustment storage carrying cost.

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Long-term Debt and Equity

Laclede Group

At March 31, 2015, including the current portion but excluding unamortized discounts and net hedging gains, Laclede Group had fixed-rate long-term debt totaling $1,568.8 and floating rate debt of $250.0, of which $810.0 was issued by Laclede Gas and $215.0 was issued by Alagasco. With the exception of the $250.0 floating rate senior notes issued by Laclede Group, the long-term debt issues are fixed-rate and 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 the Company were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to the Utilities' 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 Company's $1,818.8 senior long-term debt, $25.0 have no call options, $675.0 have make-whole call options, $725.0 are callable at par one to six months prior to maturity and $250.0 are callable at par one year prior to maturity. The remainder of the Company's long-term debt is $143.8 of junior subordinated notes associated with its equity units.

Of Laclede Gas' $810.0 in long-term debt, $25.0 have no call option, $435.0 have make-whole call options, and $350.0 are callable at par three to six months prior to maturity. All of Alagasco's debt outstanding as of March 31, 2015 has make-whole call options. None of the debt has any put options.

Pursuant to a call notice issued on December 15, 2014, Alagasco redeemed $34.7 of debt effective January 15, 2015. As of March 31, 2015, the current portion of long-term debt for Alagasco consisted of an $80.0 fixed-rate note maturing on December 1, 2015.

Laclede Group has a shelf registration statement on Form S-3 on file with the SEC for the issuance and sale of up to 168,698 shares of its common stock under its Dividend Reinvestment and Direct Stock Purchase Plan. There were 142,886 and 136,944shares at March 31, 2015, and April 30, 2015, respectively, remaining available for issuance under this Form S-3. Laclede Group also has a shelf registration statement on Form S-3 on file with the SEC for the issuance of equity and debt securities, which expires August 6, 2016. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions.

Laclede Gas

Laclede Gas has authority from the MoPSC 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 $518.0. As of April 30, 2015, $369.7 remains available under this authorization, which is effective through June 30, 2015. Laclede Gas issued no securities under this authorization during the six months ended March 31, 2015. On April 15, 2015, Laclede Gas filed with the MoPSC for a new financing authorization. A ruling on this application is expected to be received before the expiration of the current authorization. Laclede Gas has a shelf registration statement on Form S-3 on file with the SEC for the issuance of first mortgage bonds, unsecured debt and preferred stock, which expires August 6, 2016. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions, as well as future MoPSC authorizations.

Laclede Gas’ outstanding first mortgage bonds contain restrictions on its ability to pay cash dividends on its common stock. As of March 31, 2015, all of Laclede Gas’ retained earnings were free from such restrictions.

Alagasco

Alagasco has no standing authority to issue long-term debt, but must petition the APSC for each planned issuance. On November 3, 2014, Alagasco received authorization and approval from the APSC to borrow $35.0 for the purpose of funding the redemption, without premium, of the $34.7 in existing long-term debt, referenced above, which carried an annual interest rate of 5.7%. Pursuant to a call notice issued on December 15, 2014, Alagasco redeemed $34.7 of debt effective January 15, 2015. On February 3, 2015, Alagasco received authorization and approval from the APSC to borrow $80.0 for the purpose of refinancing the scheduled maturity on December 1, 2015, of $80.0 of existing debt. As of March 31, 2015, the current portion of long-term debt for Alagasco consisted of this $80.0 fixed-rate note maturing on December 1, 2015.

Other

Gas Utility capital expenditures were $127.6 for the six months ended March 31, 2015, compared with $67.1 for the same period last year. Besides the addition of $34.2 for Alagasco, the increase in capital expenditures to $93.4 for Laclede Gas is primarily attributable to facilities improvements, MGE integration, pipeline replacement and the timing of meter purchases.

The Company's capitalization at March 31, 2015 consisted of 47.8% of Laclede Group common stock equity and 52.2% long-term debt, compared to 44.9% of Laclede Group common stock equity and 55.1% on long-term debt at September 30, 2014. The decline in the proportion of long-term debt is due primarily to the redemption of $34.7 and the reclassification of $80.0 to "current," both at Alagasco.

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The Company’s, Laclede Gas’, and Alagasco'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, Laclede Gas and Alagasco remain at investment grade, but are subject to review and change by the rating agencies.

It is management’s view that the Company, Laclede Gas and Alagasco have adequate access to capital markets and will have sufficient capital resources, both internal and external, to meet anticipated capital requirements, which primarily include capital expenditures, interest payments on long-term debt, scheduled maturities of long-term debt, short-term seasonal needs, and dividends.

CONTRACTUAL OBLIGATIONS

During the six months ended March 31, 2015, there have been no material changes outside the ordinary course of business to the estimated contractual obligations from the disclosure provided in the Company's and Laclede Gas' Form 10-K and Alagasco's Form 10-KT/A for the period ended September 30, 2014, except for changes in principal and interest payments on long-term debt and natural gas purchase obligations for Alagasco, which also affect consolidated amounts for Laclede Group. The following tables summarize amounts for those categories as of March 31, 2015 for Laclede Group and Alagasco.

Laclede Group

			Payments Due By Period
($ Millions)	Total		Remaining Fiscal Year 2015		Fiscal Years 2016-2017		Fiscal Years 2018-2019		Fiscal Years 2020 and Thereafter
Principal Payment on Long-term Debt	$	1,818.8	$	—	$	330.0	$	275.0	$	1,213.8
Interest Payment on Long-term Debt	1,002.7		36.8		137.2		117.7		711.0
Purchase Obligations - Natural Gas	1,595.0		391.0		699.4		375.3		129.3

Alagasco

			Payments Due By Period
($ Millions)	Total		Remaining Fiscal Year 2015		Fiscal Years 2016-2017		Fiscal Years 2018-2019		Fiscal Years 2020 and Thereafter
Principal Payment on Long-term Debt	$	215.0	$	—	$	80.0	$	—	$	135.0
Interest Payment on Long-term Debt	86.6		5.5		15.5		13.3		52.3
Purchase Obligations - Natural Gas	521.5		71.8		255.9		136.6		57.2

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MARKET RISK

Commodity Price Risk

Gas Utilities

The Utilities' commodity price risk, which arises from market fluctuations in the price of natural gas, is primarily managed through the operation of the Missouri Utilities' PGA clauses and Alagasco's GSA rider. The PGA clauses allow the Missouri Utilities to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. Laclede Gas 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. Alagasco's tariff provides the Company the opportunity to adjust the GSA each month dependent on whether the estimated balance and amount of GSA adjustment falls within certain parameters. Laclede Gas and Alagasco are 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 Laclede Gas’ use of natural gas derivative instruments are allowed to be passed on to the Laclede Gas' customers through the operation of its PGA clauses. Accordingly, the Utilities do 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 clauses or the GSA rider. While Alagasco is permitted to purchase or sell financial instruments under its natural gas risk management program, it did not have any open commodity derivative positions as of March 31, 2015.

Gas Marketing

In the course of its business, Laclede Group’s non-regulated gas marketing subsidiary, LER, enters into contracts to purchase and sell natural gas at fixed prices and natural gas index-based prices. Commodity price risk associated with these contracts has the potential to impact earnings and cash flows. To minimize this risk, LER has a risk management policy that provides for daily monitoring of a number of business measures, including fixed-price commitments. In accordance with the risk management policy, LER manages the price risk associated with its fixed-price commitments. This risk is currently managed either by closely matching the offsetting physical purchase or sale of natural gas at fixed-prices or through the use of natural gas futures, options, and swap contracts traded on or cleared through the NYMEX and ICE to lock in margins. At March 31, 2015 and September 30, 2014, 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:

($ Millions)	Derivative Fair Values			Cash Margin		Derivatives and Cash Margin
Net balance of derivative assets as of September 30, 2014	$	0.4		$	2.1	$	2.5
Changes in fair value	0.3			—		0.3
Settlements/purchases - net	(1.0		)	—		(1.0		)
Changes in cash margin	—			2.1		2.1
Net balance of derivative (liabilities) assets as of March 31, 2015	$	(0.3	)	$	4.2	$	3.9

	As of March 31, 2015
	Maturity by Fiscal Year
($ Millions)	Total			2015			2016			2017			2018			2019
Fair values of exchange-traded/cleared natural gas derivatives - net	$	(1.6	)	$	(2.7	)	$	1.2		$	(0.1	)	$	—		$	—
MMBtu – net (short) long futures/swap/option positions	(1.6		)	6.4			(9.1		)	1.0			0.1			—
Fair values of basis swaps - net	$	1.3		$	0.6		$	0.3		$	0.4		$	—		$	—
MMBtu – net short basis swap positions	(11.9		)	(5.3		)	(2.6		)	(3.5		)	(0.5		)	—

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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 2016:

($ Millions)
Net balance of derivative assets as of September 30, 2014	$	2.1
Changes in fair value	0.6
Settlements	(0.4		)
Net balance of derivative assets as of March 31, 2015	$	2.3

Counterparty Credit Risk

LER has concentrations of counterparty credit risk in that a significant portion of its transactions are 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. 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 7, Concentrations of Credit Risk, of the Notes to the Financial Statements.

Interest Rate Risk

The Company, Laclede Gas, and Alagasco are subject to interest rate risk associated with long-term and short-term debt issuances. Based on average short-term borrowings during the six months ended March 31, 2015, an increase of 100 basis points in the underlying average interest rate for short-term debt would have caused an increase in annual interest expense of approximately $3.6, $2.7 and $0.3 for the Company, Laclede Gas and Alagasco, respectively, on an annual basis. Portions of such increases may be offset through the application of PGA carrying costs. At March 31, 2015, Laclede Group had $250.0 of variable rate long-term debt. An increase of 100 basis points in the underlying average interest rate for the variable long term note would cause an increase in interest expense of approximately $2.5 on an annual basis. At March 31, 2015, Laclede Group had fixed-rate long-term debt totaling $1,568.8, including $810.0 issued by Laclede Gas and $215.0 issued by Alagasco. 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 issuer were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to the Utilities' 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.

During the second quarter of fiscal 2015, Alagasco entered into certain interest rate swap transactions to protect itself against adverse movement in interest rates in anticipation of the issuance of $115 of long-term debt. Alagasco received prior approval from the APSC to enter into these hedges. As a result, the $2.9 mark-to-market loss recognized for the quarter ended March 31, 2015 was recorded as a regulatory asset. At March 31, 2015, the notional amount of interest rate swaps outstanding was $80.5 with stated maturities ranging from 2025 to 2045 and fixed interest rates ranging between 2.18% and 2.85%. In April 2015, Alagasco entered into an additional hedge with a notional amount of $24.0 and terms within the same range.

ENVIRONMENTAL MATTERS

The Missouri Utilities and Alagasco own and operate 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, Laclede Gas' or Alagasco's financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas and Alagasco may be required to incur additional costs. For information relative to environmental matters, see Note 10 of the Notes to the Financial Statements included in Item 1.

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OFF-BALANCE SHEET ARRANGEMENTS

At March 31, 2015, none of Laclede Group or its subsidiary companies had off-balance-sheet financing arrangements, other than operating leases entered into in the ordinary course of business. None of Laclede Group or its subsidiaries expects to engage in any significant off-balance-sheet financing arrangements in the near future.

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 55 of this report.

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Item 4. Controls and Procedures

Disclosure Controls and Procedures - Laclede Group

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.

SEC guidance permits the exclusion of an evaluation of the effectiveness of a registrant's disclosure controls and procedures as they relate to the internal control over financial reporting for an acquired business during the first year following such acquisition. Effective August 31, 2014, we acquired Alagasco. Alagasco’s business constituted 31.2 percent and 28.2 percent of net and total assets, respectively, as of March 31, 2015, and 23.6 percent of revenues for the six months then ended. Management's evaluation and conclusion as to the effectiveness of the design and operation of the Company’s disclosure controls and procedures as of the end of the period covered by this report excludes any evaluation of the internal control over financial reporting of Alagasco.

Changes in Internal Control over Financial Reporting - Laclede Group

After the acquisition of Alagasco effective August 31, 2014, management began to integrate some controls of Alagasco with those of the Company’s corporate level controls, although a complete integration is not expected and Alagasco will retain distinct controls in some areas.

Except for the activities described above, there were no changes in the Company’s internal control over financial reporting that occurred during the quarter ended March 31, 2015 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Disclosure Controls and Procedures - Laclede Gas

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 the 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.

Changes in Internal Control over Financial Reporting - Laclede Gas

There were no changes in Laclede Gas’ internal control over financial reporting that occurred during the quarter ended March 31, 2015 that have materially affected, or are reasonably likely to materially affect, Laclede Gas’ internal control over financial reporting.

Disclosure Controls and Procedures - Alagasco

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 the 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.

Changes in Internal Control over Financial Reporting - Alagasco

Effective August 31, 2014, the Company acquired Alagasco as described in Note 2, Alagasco Acquisition. Post-acquisition, management began to integrate some controls of Alagasco with corporate level controls of Laclede Group, although a complete integration is not expected and Alagasco will retain distinct controls in some areas.

Other than those changes described above, there were no changes in Alagasco’s internal control over financial reporting that occurred during the quarter ended March 31, 2015 that have materially affected, or are reasonably likely to materially affect, Alagasco’s internal control over financial reporting.

62

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For a description of environmental matters and legal proceedings, see Note 10, Commitments and Contingencies, of the Notes to the Financial Statements in Item 1 of Part 1. For a description of pending regulatory matters, see Note 4, Regulatory Matters.

The registrants are involved in litigation, claims and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcomes of these matters will not have a material effect on any registrant's financial position or results of operations reflected in the financial statements presented herein.

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

During the three months ended March 31, 2015, the only repurchases of Laclede Group's 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, 2015 – January 31, 2015	289	$53.26	—	—
February 1, 2015 – February 28, 2015	—	$—	—	—
March 1, 2015 – March 31, 2015	—	$—	—	—
Total	289	53.26	—	—

Item 6. Exhibits

(a) See Exhibit Index.

63

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		The Laclede Group, Inc.
Dated:	May 6, 2015	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Executive Vice President, Chief Financial Officer
			(Authorized Signatory and Principal Financial Officer)

		Laclede Gas Company
Dated:	May 6, 2015	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer
			(Authorized Signatory and Principal Financial Officer)

		Alabama Gas Corporation
Dated:	May 6, 2015	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer
			(Authorized Signatory and Principal Financial Officer)

64

INDEX TO EXHIBITS

Exhibit No.
10.1	-	The Laclede Group 2015 Equity Incentive Plan filed as the Appendix to the Company's Definitive Proxy Statement on Form DEF 14A filed December 19, 2014 and incorporated herein by reference (File No. 1-16681).
31.1	-	CEO and CFO Certifications under Exchange Act Rule 13a-14(a) of The Laclede Group, Inc.
31.2	-	CEO and CFO Certifications under Exchange Act Rule 13a-14(a) of Laclede Gas Company.
31.3	-	CEO and CFO Certifications under Exchange Act Rule 13a-14(a) of Alabama Gas Corporation.
32.1	-	CEO and CFO Section 1350 Certifications of The Laclede Group, Inc.
32.2	-	CEO and CFO Section 1350 Certifications of Laclede Gas Company.
32.3	-	CEO and CFO Section 1350 Certifications of Alabama Gas Corporation.
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 for each registrant formatted in extensible business reporting language (XBRL): (i) Document and Entity Information; (ii) unaudited Condensed Consolidated Statements of Income and Condensed Statements of Income for the three and six months ended March 31, 2015 and 2014; (iii) unaudited Consolidated Statements of Comprehensive Income and Statements of Comprehensive Income for the three and six months ended March 31, 2015 and 2014; (iv) unaudited Condensed Consolidated Balance Sheets and Condensed Balance Sheets at March 31, 2015 and September 30, 2014; (v) unaudited Consolidated Statements of Common Shareholders' Equity and Statements of Common Shareholder's Equity for the six months ended March 31, 2015 and 2014; (vi) unaudited Condensed Consolidated Statements of Cash Flows and Condensed Statements of Cash Flows for the six months ended March 31, 2015 and 2014, and (vii) combined Notes to the Financial Statements. We also make available on our website the Interactive Data Files submitted as Exhibit 101 to this Quarterly Report. 

65

EX-31.1

Exhibit 31.1

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:	May 6, 2015	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			President and Chief Executive Officer

CERTIFICATION

I, Steven P. Rasche, 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:	May 6, 2015	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Executive Vice President and Chief Financial Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Suzanne Sitherwood, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Laclede Gas Company;

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

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

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

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

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

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

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

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

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

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

Date:	May 6, 2015	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			Chairman of the Board and Chief Executive Officer

CERTIFICATION

I, Steven P. Rasche, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Laclede Gas Company;

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

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

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

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

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

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

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

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

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

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

Date:	May 6, 2015	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

EX-31.3

Exhibit 31.3

CERTIFICATION

I, Suzanne Sitherwood, certify that:

1. I have reviewed this quarterly report Form 10-Q of Alabama Gas Corporation;

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

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

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

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

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

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

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

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

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

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

Date:	May 6, 2015	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			Chairman of the Board and Chief Executive Officer

CERTIFICATION

I, Steven P. Rasche, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	May 6, 2015	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

EX-32.1

Exhibit 32.1

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, 2015 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, 2015 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.

Date:	May 6, 2015	Signature:	/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, Steven P. Rasche, 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, 2015 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, 2015 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.

Date:	May 6, 2015	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Executive Vice President and Chief Financial Officer

EX-32.2

Exhibit 32.2

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, Chairman of the Board and Chief Executive Officer of Laclede Gas Company, hereby certify that

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2015 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, 2015 fairly presents, in all material respects, the financial condition and results of operations of Laclede Gas Company.

Date:	May 6, 2015	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			Chairman of the Board and Chief Executive Officer

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Steven P. Rasche, Chief Financial Officer of Laclede Gas Company, hereby certify that

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2015 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, 2015 fairly presents, in all material respects, the financial condition and results of operations of Laclede Gas Company.

Date:	May 6, 2015	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

EX-32.3

Exhibit 32.3

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, Chairman of the Board and Chief Executive Officer of Alabama Gas Corporation, hereby certify that

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2015 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, 2015 fairly presents, in all material respects, the financial condition and results of operations of Alabama Gas Corporation.

Date:	May 6, 2015	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			Chairman of the Board and Chief Executive Officer

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Steven P. Rasche, Director and Chief Financial Officer of Alabama Gas Corporation, hereby certify that

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2015 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, 2015 fairly presents, in all material respects, the financial condition and results of operations of Alabama Gas Corporation.

Date:	May 6, 2015	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

XML

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Net Periodic Cost (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	$ 4.3	$ 2.5	$ 8.6	$ 4.9
Interest cost on projected benefit obligation	7.4	6.0	14.9	12.0
Expected return on plan assets	(9.3)	(6.7)	(18.7)	(13.3)
Amortization of prior service cost	0.1	0.1	0.2	0.2
Amortization of actuarial loss	2.0	1.7	3.9	3.5
Loss on lump-sum settlements	0	1.3	0	1.3
Sub-total	4.5	4.9	8.9	8.6
Regulatory adjustment	4.8	1.6	9.7	4.5
Net pension cost	9.3	6.5	18.6	13.1
Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	3.2	2.8	6.4	5.6
Interest cost on projected benefit obligation	2.8	2.2	5.6	4.4
Expected return on plan assets	(3.3)	(1.7)	(6.6)	(3.4)
Amortization of prior service cost	0.2	0	0.4	0
Amortization of actuarial loss	1.2	1.5	2.5	3.0
Sub-total	4.1	4.8	8.3	9.6
Regulatory adjustment	(2.7)	(2.4)	(5.4)	(4.8)
Net pension cost	1.4	2.4	2.9	4.8
Laclede Gas | Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	2.9	2.5	5.7	4.9
Interest cost on projected benefit obligation	5.9	6.0	11.8	12.0
Expected return on plan assets	(7.3)	(6.7)	(14.6)	(13.3)
Amortization of prior service cost	0.1	0.1	0.2	0.2
Amortization of actuarial loss	2.0	1.7	3.9	3.5
Loss on lump-sum settlements	0	1.3	0	1.3
Sub-total	3.6	4.9	7.0	8.6
Regulatory adjustment	3.4	1.6	6.8	4.5
Net pension cost	7.0	6.5	13.8	13.1
Laclede Gas | Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	3.1	2.8	6.2	5.6
Interest cost on projected benefit obligation	2.2	2.2	4.3	4.4
Expected return on plan assets	(2.1)	(1.7)	(4.1)	(3.4)
Amortization of prior service cost	0.2	0	0.4	0
Amortization of actuarial loss	1.2	1.5	2.5	3.0
Sub-total	4.6	4.8	9.3	9.6
Regulatory adjustment	(2.3)	(2.4)	(4.6)	(4.8)
Net pension cost	2.3	2.4	4.7	4.8
Alagasco | Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	1.4	1.5	2.9	3.6
Interest cost on projected benefit obligation	1.5	1.2	3.1	2.9
Expected return on plan assets	(2.0)	(1.5)	(4.1)	(3.7)
Amortization of prior service cost	0	0.1	0	0.1
Amortization of actuarial loss	0	0.7	0	2.0
Loss on lump-sum settlements	0	10.1	0	10.9
Sub-total	0.9	12.1	1.9	15.8
Regulatory adjustment	1.4	(9.8)	2.9	(10.6)
Net pension cost	2.3	2.3	4.8	5.2
Alagasco | Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	0.1	0.1	0.2	0.4
Interest cost on projected benefit obligation	0.6	0.5	1.3	1.2
Expected return on plan assets	(1.2)	(1.1)	(2.5)	(2.1)
Amortization of transition obligation	0	0.1	0	0.3
Amortization of actuarial loss	0	(0.4)	0	(0.5)
Sub-total	(0.5)	(0.8)	(1.0)	(0.7)
Regulatory adjustment	(0.4)	0	(0.8)	0
Net pension cost	$ (0.9)	$ (0.8)	$ (1.8)	$ (0.7)

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REGULATORY MATTERS - Schedule of Regulatory Assets Not Earnings a Return (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2015	Sep. 30, 2014
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	$ 373.1	$ 373.9
Future income taxes due from customers
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	125.6	117.0
Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	232.3	240.9
Other
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	15.2	16.0
Laclede Gas
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	373.1	373.9
Laclede Gas | Future income taxes due from customers
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	125.6	117.0
Laclede Gas | Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	232.3	240.9
Laclede Gas | Other
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	$ 15.2	$ 16.0

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INFORMATION BY OPERATING SEGMENT (Tables)

6 Months Ended

Mar. 31, 2015

Segment Reporting [Abstract]

Schedule of operating segment information

($ Millions)	Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Three Months Ended March 31, 2015
Operating Revenues:
Revenues from external customers	$	847.0	$	30.0	$	0.4		$	—		$	877.4
Intersegment revenues	2.0		14.1		0.5			(16.6		)	—
Total Operating Revenues	849.0		44.1		0.9			(16.6		)	877.4
Operating Expenses:
Gas Utility
Natural and propane gas	499.1		—		—			(16.3		)	482.8
Other operation and maintenance	104.0		—		—			(0.2		)	103.8
Depreciation and amortization	32.2		—		—			—			32.2
Taxes, other than income taxes	55.7		—		—			—			55.7
Total Gas Utility Operating Expenses	691.0		—		—			(16.5		)	674.5
Gas Marketing	—		43.5		—			—			43.5
Other	—		—		1.8			(0.1		)	1.7
Total Operating Expenses	691.0		43.5		1.8			(16.6		)	719.7
Operating Income (Loss)	$	158.0	$	0.6	$	(0.9	)	$	—		$	157.7
Net Economic Earnings (Loss)	$	96.5	$	2.1	$	(1.0	)	$	—		$	97.6
Three Months Ended March 31, 2014
Operating Revenues:
Revenues from external customers	$	634.4	$	59.9	$	0.2		$	—		$	694.5
Intersegment revenues	4.2		20.6		0.6			(25.4		)	—
Total Operating Revenues	638.6		80.5		0.8			(25.4		)	694.5
Operating Expenses:
Gas Utility
Natural and propane gas	430.5		—		—			(25.2		)	405.3
Other operation and maintenance	72.2		—		—			(0.2		)	72.0
Depreciation and amortization	20.1		—		—			—			20.1
Taxes, other than income taxes	41.8		—		—			—			41.8
Total Gas Utility Operating Expenses	564.6		—		—			(25.4		)	539.2
Gas Marketing	—		65.0		—			—			65.0
Other	—		—		3.1			—			3.1
Total Operating Expenses	564.6		65.0		3.1			(25.4		)	607.3
Operating Income (Loss)	$	74.0	$	15.5	$	(2.3	)	$	—		$	87.2
Net Economic Earnings (Loss)	$	44.7	$	7.1	$	(0.1	)	$	—		$	51.7

($ Millions)	Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Six Months Ended March 31, 2015
Operating Revenues:
Revenues from external customers	$	1,428.4	$	67.8	$	0.8		$	—		$	1,497.0
Intersegment revenues	3.0		38.5		1.0			(42.5		)	—
Total Operating Revenues	1,431.4		106.3		1.8			(42.5		)	1,497.0
Operating Expenses:
Gas Utility
Natural and propane gas	828.9		—		—			(41.8		)	787.1
Other operation and maintenance	201.4		—		—			(0.5		)	200.9
Depreciation and amortization	64.2		—		—			—			64.2
Taxes, other than income taxes	93.7		—		—			—			93.7
Total Gas Utility Operating Expenses	1,188.2		—		—			(42.3		)	1,145.9
Gas Marketing	—		102.1		—			—			102.1
Other	—		—		4.2			(0.2		)	4.0
Total Operating Expenses	1,188.2		102.1		4.2			(42.5		)	1,252.0
Operating Income (Loss)	$	243.2	$	4.2	$	(2.4	)	$	—		$	245.0
Net Economic Earnings (Loss)	$	146.3	$	2.5	$	(5.5	)	$	—		$	143.3
Six Months Ended March 31, 2014
Operating Revenues:
Revenues from external customers	$	1,069.6	$	93.1	$	0.4		$	—		$	1,163.1
Intersegment revenues	4.3		40.1		1.0			(45.4		)	—
Total Operating Revenues	1,073.9		133.2		1.4			(45.4		)	1,163.1
Operating Expenses:
Gas Utility
Natural and propane gas	692.1		—		—			(45.0		)	647.1
Other operation and maintenance	134.7		—		—			(0.4		)	134.3
Depreciation and amortization	40.1		—		—			—			40.1
Taxes, other than income taxes	70.4		—		—			—			70.4
Total Gas Utility Operating Expenses	937.3		—		—			(45.4		)	891.9
Gas Marketing	—		116.8		—			—			116.8
Other	—		—		4.3			—			4.3
Total Operating Expenses	937.3		116.8		4.3			(45.4		)	1,013.0
Operating Income (Loss)	$	136.6	$	16.4	$	(2.9	)	$	—		$	150.1
Net Economic Earnings (Loss)	$	80.5	$	7.9	$	(0.4	)	$	—		$	88.0

The Company's total assets by segment were as follows:

	March 31,			September 30,
($ Millions)	2015			2014
Total Assets:
Gas Utility	$	4,615.6		$	4,520.0
Gas Marketing	131.7			156.7
Other	1,590.8			1,575.7
Eliminations	(1,157.4		)	(1,178.4		)
Total Assets	$	5,180.7		$	5,074.0

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

The following table reconciles the Company's Net Income (GAAP) to Net Economic Earnings (Non-GAAP):

	Three Months Ended March 31,						Six Months Ended March 31,
($ Millions)	2015			2014			2015			2014
Net income (GAAP)	$	94.4		$	52.2		$	141.5		$	87.8
Unrealized loss (gain) on energy-related derivative contracts	2.6			(1.7		)	(0.4		)	(1.3		)
Lower of cost or market inventory adjustments	(1.0		)	(0.5		)	0.2			(0.6		)
Realized loss (gain) on economic hedges prior to sale of the physical commodity	0.1			(0.1		)	0.1			(0.1		)
Acquisition, divestiture and restructuring activities	1.5			1.8			1.9			2.2
Net Economic Earnings (Non-GAAP)	$	97.6		$	51.7		$	143.3		$	88.0

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COMMITMENTS AND CONTINGENCIES - Commitments (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2015
Long-term Purchase Commitment [Line Items]
Minimum total payments required for natural gas contracts	$ 1,595.0
Laclede Gas
Long-term Purchase Commitment [Line Items]
Minimum total payments required for natural gas contracts	750.4
Alagasco
Long-term Purchase Commitment [Line Items]
Minimum total payments required for natural gas contracts	$ 521.5

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CONCENTRATIONS OF CREDIT RISK (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2015 counterparty
Concentration Risk [Line Items]
Number of large counterparties for which credit risk is disclosed	5
Energy Producers And Their Affiliates
Concentration Risk [Line Items]
Accounts receivable	7.5
Net receivable amount	5.7
Utility Companies And Their Affiliates
Concentration Risk [Line Items]
Accounts receivable	15.6
Net receivable amount	14.1
Largest Counterparties
Concentration Risk [Line Items]
Accounts receivable	9.8
Net receivable amount	9.3

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ALAGASCO ACQUISITION

6 Months Ended

Mar. 31, 2015

Business Combinations [Abstract]

ALAGASCO ACQUISITION

ALAGASCO ACQUISITION

The Company completed the acquisition of 100% of the common stock of Alagasco (Alagasco Transaction) from Energen for $1,600.0, including cash and assumed debt. The acquisition date (Closing Date) was September 2, 2014, with an effective time under the Stock Purchase Agreement of 11:59 p.m. on August 31, 2014. The Alagasco Transaction was subject to certain post-closing adjustments for cash, indebtedness and working capital as discussed below. Total cash consideration paid at closing, net of cash acquired and debt assumed, was $1,305.2. Subsequently, the Company and Energen agreed to a final reconciliation of net assets, and $8.6 was paid by the Company to Energen on January 6, 2015, effectively increasing the total net consideration to $1,313.8. This payment, offset partly by other immaterial purchase price adjustments in the second quarter of 2015, increased goodwill related to the transaction from $727.6 recorded as of September 30, 2014, to $735.8 as of March 31, 2015. The Alagasco Transaction was accounted for under the acquisition method of accounting in accordance with FASB ASC Topic 805, “Business Combinations.” The Company determined that the Alagasco Transaction met the scope exceptions for pushdown accounting, and as such the excess consideration transferred over the fair value of assets acquired was recorded at Laclede Group. The Company and Energen made an election under Section 338(h)(10) of the Internal Revenue Code of 1986, as amended, to treat the Alagasco Transaction as a deemed purchase and sale of assets for tax purposes. As a result, the existing deferred tax assets and liabilities were re-measured as of the Closing Date.

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COMMITMENTS AND CONTINGENCIES - Contingencies (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2014 site	Aug. 30, 2014	Dec. 31, 2013 Resident
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP) 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		$ 8.1
Maximum cost estimate for a one-time contractual transfer of risk		$ 39.3
Alagasco
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)	9
Number of former manufactured gas distribution	5
Previous Ownership | Missouri Gas Energy (MGE)
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)	7
Previous Ownership | Laclede Gas
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)	19
Current Ownership | Alagasco
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)	4
Number of former manufactured gas distribution	1
Removal Action, Phase I | 35th Avenue Superfund Site
Loss Contingencies [Line Items]
Number of residents at high levels of contamination			50
Removal Action, Phase II | 35th Avenue Superfund Site
Loss Contingencies [Line Items]
Number of residents at high levels of contamination		30

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Goodwill (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014
Goodwill [Line Items]
Goodwill	$ 946.0		$ 937.8
Laclede Gas
Goodwill [Line Items]
Goodwill	210.2		210.2
Missouri Gas Energy (MGE)
Goodwill [Line Items]
Goodwill	210.2		210.2
Missouri Gas Energy (MGE) | Laclede Gas
Goodwill [Line Items]
Goodwill	210.2		210.2
Alagasco
Goodwill [Line Items]
Goodwill	735.8	727.6	727.6
Alagasco | Laclede Gas
Goodwill [Line Items]
Goodwill	$ 0		$ 0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Inter-company Transactions (Details) (Affiliated Entity, USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Regulated Operation | Laclede Gas | Laclede Energy Resources
Related Party Transaction [Line Items]
Revenue from related parties	$ 16.0	$ 25.0	$ 41.3	$ 44.5
Regulated Operation | Laclede Energy Resources | Laclede Gas
Related Party Transaction [Line Items]
Revenue from related parties	1.9	4.2	2.9	4.3
Unregulated Operation | Laclede Gas | Laclede Pipeline Company
Related Party Transaction [Line Items]
Revenue from related parties	$ 0.2	$ 0.2	$ 0.5	$ 0.5

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ALAGASCO ACQUISITION - Alabama Gas Corporation (Details) (USD $) In Millions, unless otherwise specified	0 Months Ended		1 Months Ended	3 Months Ended
	Jan. 06, 2015	Sep. 02, 2014	Jan. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Sep. 02, 2014
Business Acquisition [Line Items]
Goodwill				$ 946.0		$ 937.8
Alagasco
Business Acquisition [Line Items]
Percentage of voting interest acquired		100.00%					100.00%
Total consideration transferred		1,600.0
Payments to acquire businesses, net of cash acquired		1,305.2	1,313.8
Final reconciliation of net assets payments to acquire businesses	8.6			8.6
Goodwill				$ 735.8	$ 727.6	$ 727.6

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EARNINGS PER COMMON SHARE (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Basic EPS:
Net Income	$ 94.4	$ 52.2	$ 141.5	$ 87.8
Less: Income allocated to participating securities	0.3	0.2	0.5	0.3
Net Income Available to Common Shareholders	94.1	52.0	141.0	87.5
Weighted Average Shares Outstanding, Basic (in Shares)	43.1	32.6	43.1	32.6
Basic Earnings Per Share of Common Stock (in dollars per share)	$ 2.18	$ 1.59	$ 3.27	$ 2.68
Diluted EPS:
Net Income	94.4	52.2	141.5	87.8
Less: Income allocated to participating securities	0.3	0.2	0.5	0.3
Net Income Available to Common Shareholders	$ 94.1	$ 52.0	$ 141.0	$ 87.5
Weighted Average Shares Outstanding, Basic (in Shares)	43.1	32.6	43.1	32.6
Dilutive Effect of Stock Options, Restricted Stock and Restricted Stock Units (in shares)	0.1	0	0.1	0.1
Weighted Average Diluted Shares (in shares)	43.2	32.6	43.2	32.7
Diluted Earnings Per Share of Common Stock (in dollars per share)	$ 2.18	$ 1.59	$ 3.26	$ 2.68
Restricted stock and stock units subject to performance and/or market conditions
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Outstanding shares excluded from calculation of diluted EPS (in shares)	0.4	0.3

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION - These notes are an integral part of the accompanying unaudited financial statements of The Laclede Group, Inc. (Laclede Group or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco or the Alabama Utility). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Collectively, Laclede Gas and Alagasco are referred to as the Utilities. The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial information with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the disclosures required for complete financial statements. In the opinion of management, the accompanying unaudited financial statements include 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 the Financial Statements contained in Laclede Group's, Laclede Gas' and Alagasco's Annual Reports on Form 10-K or 10-KT for the fiscal year or transition period, as applicable, ended September 30, 2014.

The consolidated financial position, results of operations, and cash flows of Laclede Group are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between the Utilities and their affiliates, as well as intercompany balances on the Utilities' Balance Sheets, have not been eliminated from the Utilities' financial statements. As a result of the Company's August 31, 2014 acquisition of Alagasco, the Company's results of operations for the three and six months ended March 31, 2015 include Alagasco, which impacts the comparability of the current year financial statements to prior years. For a further discussion of the acquisition, see Note 2, Alagasco Acquisition.

The Utilities are regulated natural gas distribution utilities. Due to the seasonal nature of the Utilities, Laclede Group’s earnings are typically concentrated during the heating season of November through April each fiscal year. As a result, the interim statements of income for Laclede Group are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year.

NATURE OF OPERATIONS - Laclede Group, headquartered in St. Louis, Missouri, is a public utility holding company. It has two key operating segments: Gas Utility and Gas Marketing. The Gas Utility segment is comprised of the operations of the Missouri Utilities and the Alabama Utility and serves St. Louis and eastern Missouri through legacy Laclede Gas, serves Kansas City and western Missouri through MGE, and serves central and northern Alabama through Alagasco. Laclede Group’s primary non-utility business, Laclede Energy Resources, Inc. (LER), included in the Gas Marketing segment, provides non-regulated natural gas services. The activities of other subsidiaries are described in Note 9, Information by Operating Segment, and are reported as Other. The Company's earnings are primarily derived from its Gas Utility segment.

REVENUE RECOGNITION - The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their 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 for Laclede Gas at March 31, 2015 and September 30, 2014 were $63.5 and $29.4, respectively.

Alagasco records natural gas distribution revenues in accordance with the tariff established by the Alabama Public Service Commission (APSC). The amount of accrued unbilled revenues, which is not recorded as revenue until billed, for Alagasco at March 31, 2015 and September 30, 2014 were $15.0 and $5.2, respectively.

Laclede Group's other subsidiaries, including LER, record revenues when earned, either when the product is delivered or when services are performed.

In the course of its business, LER 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 Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 815, “Derivatives and Hedging.” Those contracts are accounted for as executory contracts and recorded on an accrual basis. Revenues and expenses from such contracts are recorded using a gross presentation. Contracts not designated as normal purchases or normal sales are recorded as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. Certain of LER’s wholesale purchase and sale transactions entered on or after January 1, 2012 are classified as trading activities for financial reporting purposes. Under GAAP, revenues and expenses associated with trading activities are presented on a net basis in Gas Marketing Operating Revenues in the Condensed Consolidated Statements of Income. This net presentation has no effect on operating income or net income.

GROSS RECEIPTS TAXES - Gross receipts taxes associated with the Utilities' services are imposed on the Utilities and billed to customers. These amounts are recorded gross in the Operating Revenues line in the Company's Condensed Consolidated Statements of Income and the Utilities' Condensed Statements of Income. Gross receipts taxes are expensed by the Utilities and are included in the "Taxes, other than income taxes" line in the Company's Condensed Consolidated Statements of Income and the Utilities' Condensed Statements of Income.

The following table presents gross receipts taxes recorded:

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Laclede Group	$	44.7	$	34.3	$	72.4	$	54.3
Laclede Gas	33.9		34.3		55.8		54.3
Alagasco	10.8		13.0		16.6		19.4

REGULATED OPERATIONS - The Utilities account for their regulated operations in accordance with FASB ASC Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. In addition, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. As authorized by the MoPSC, the Purchased Gas Adjustment (PGA) clauses allow the Missouri Utilities to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. Similarly, Alagasco's rate schedules for natural gas distribution charges contain a Gas Supply Adjustment (GSA) rider, which permits the pass-through to customers of changes in the cost of gas supply. Regulatory assets and liabilities related to the PGA clauses and GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. See additional discussion on regulated operations in Note 4, Regulatory Matters.

TRANSACTIONS WITH AFFILIATES - Transactions between the Company and its affiliates have been eliminated from the consolidated financial statements of Laclede Group. Alagasco had no significant transactions with affiliates. Laclede Gas had the following transactions with affiliates:

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Sales of natural gas from Laclede Gas to LER	$	1.9	$	4.2	$	2.9	$	4.3
Sales of natural gas from LER to Laclede Gas	16.0		25.0		41.3		44.5
Transportation services provided by Laclede Pipeline Company to Laclede Gas	0.2		0.2		0.5		0.5

GOODWILL - Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. The following table represents total goodwill of Laclede Group and Laclede Gas, by acquisition, all included in the Gas Utility segment:

	Laclede Group				Laclede Gas
($ Millions)	March 31, 2015		September 30, 2014		March 31, 2015		September 30, 2014
Acquisition of MGE	$	210.2	$	210.2	$	210.2	$	210.2
Acquisition of Alagasco	735.8		727.6		—		—
Total	$	946.0	$	937.8	$	210.2	$	210.2

Alagasco has no goodwill on its balance sheet as push down accounting was not applied. As part of the Alagasco acquisition, the Company initially recorded $727.6 of goodwill. As part of the final reconciliation of net assets, $8.6 was paid by the Company to Energen Corporation (Energen) on January 6, 2015. This payment, offset partly by other immaterial purchase price adjustments in the second quarter of 2015, resulted in goodwill of $735.8 as of March 31, 2015 related to the Alagasco acquisition.

UTILITY PLANT - Laclede Gas had accrued capital expenditures of $4.2 and $3.0 as of March 31, 2015 and September 30, 2014. Alagasco had accrued capital expenditures of $4.7 and $5.0 as of March 31, 2015 and September 30, 2014.

REVISIONS TO PRIOR FINANCIAL STATEMENTS - In the Statements of Shareholder’s Equity in Alagasco's most recent Annual Report on Form 10-KT, $31.7 was misclassified between common stock and paid-in capital, with no impact on total shareholder’s equity. The prior period balances have been corrected in this filing. In addition, certain current and noncurrent assets and liabilities in the prior period have been adjusted to conform with the current period presentation for Laclede Group, Laclede Gas and Alagasco.

NEW ACCOUNTING PRONOUNCEMENTS - In May 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers. This standard is intended to improve the financial reporting requirements for revenue from contracts with customers by providing a principles-based approach to the recognition of revenue. The core principle of the standard is when an entity transfers goods or services to customers it will recognize revenue in an amount that reflects the consideration the entity expects to be entitled to for those goods or services. The standard outlines a five-step model and related application guidance, which replaces most existing revenue recognition guidance. ASU 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The guidance is currently effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early adoption not permitted. In April 2015, the FASB proposed (for public comment) a one-year deferral of the effective date (which also would permit early application as of the standard's original effective date). The Company, Laclede Gas and Alagasco are currently assessing the available transition methods and the potential impacts of the standard, which must be adopted by the first quarter of fiscal 2018 (or fiscal 2019, if the effective date is delayed as proposed).

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REGULATORY MATTERS - Schedule of Regulatory Assets and Liabilities (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2015	Sep. 30, 2014
Regulatory Assets [Line Items]
Regulatory Assets: Current	$ 27.4	$ 26.8
Regulatory Assets: Non-current	632.9	614.3
Total Regulatory Assets	660.3	695.1
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	38.5	41.3
Regulatory Liabilities: Non-current	114.3	125.8
Total Regulatory Liabilities	229.5	189.5
RSE adjustment
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	9.9	19.8
Unbilled service margin
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	15.0	5.2
Refundable negative salvage
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	10.8	13.4
Regulatory Liabilities: Non-current	17.0	26.8
Unamortized purchased gas adjustments
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	76.7	22.4
Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	2.8	2.9
Regulatory Liabilities: Non-current	12.3	12.3
Postretirement liabilities
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	25.1	26.2
Accrued cost of removal
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	59.9	60.5
Total Regulatory Liabilities (current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	115.2	63.7
Total Regulatory Liabilities (non-current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	114.3	125.8
Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets: Current	21.4	21.4
Regulatory Assets: Non-current	420.8	431.5
Unamortized purchased gas adjustments
Regulatory Assets [Line Items]
Regulatory Assets: Current	0	54.0
Future income taxes due from customers
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	125.6	117.0
Accretion and depreciation of asset retirement obligations
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	19.1	18.4
Purchased gas costs
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	18.6	4.3
Energy efficiency
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	20.4	18.9
Other
Regulatory Assets [Line Items]
Regulatory Assets: Current	6.0	5.4
Regulatory Assets: Non-current	28.4	24.2
Total Regulatory Assets (current)
Regulatory Assets [Line Items]
Regulatory Assets: Current	27.4	80.8
Total Regulatory Assets (non-current)
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	632.9	614.3
Laclede Gas
Regulatory Assets [Line Items]
Regulatory Assets: Current	17.4	18.0
Regulatory Assets: Non-current	545.3	523.7
Total Regulatory Assets	562.7	595.7
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	71.7	72.1
Total Regulatory Liabilities	111.4	72.7
Laclede Gas | RSE adjustment
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	0	0
Laclede Gas | Unbilled service margin
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	0	0
Laclede Gas | Refundable negative salvage
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	0	0
Regulatory Liabilities: Non-current	0	0
Laclede Gas | Unamortized purchased gas adjustments
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	39.1	0
Laclede Gas | Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	0.6	0.6
Regulatory Liabilities: Non-current	11.8	11.6
Laclede Gas | Postretirement liabilities
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	0	0
Laclede Gas | Accrued cost of removal
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	59.9	60.5
Laclede Gas | Total Regulatory Liabilities (current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	39.7	0.6
Laclede Gas | Total Regulatory Liabilities (non-current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	71.7	72.1
Laclede Gas | Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets: Current	15.0	15.0
Regulatory Assets: Non-current	357.9	365.4
Laclede Gas | Unamortized purchased gas adjustments
Regulatory Assets [Line Items]
Regulatory Assets: Current	0	54.0
Laclede Gas | Future income taxes due from customers
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	125.6	117.0
Laclede Gas | Accretion and depreciation of asset retirement obligations
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	0	0
Laclede Gas | Purchased gas costs
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	18.6	4.3
Laclede Gas | Energy efficiency
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	20.4	18.9
Laclede Gas | Other
Regulatory Assets [Line Items]
Regulatory Assets: Current	2.4	3.0
Regulatory Assets: Non-current	22.8	18.1
Laclede Gas | Total Regulatory Assets (current)
Regulatory Assets [Line Items]
Regulatory Assets: Current	17.4	72.0
Laclede Gas | Total Regulatory Assets (non-current)
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	545.3	523.7
Alagasco
Regulatory Assets [Line Items]
Regulatory Assets: Current	10.0	8.8
Regulatory Assets: Non-current	87.6	90.6
Total Regulatory Assets	97.6	99.4
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	37.9	40.7
Regulatory Liabilities: Non-current	42.8	53.7
Total Regulatory Liabilities	118.3	116.8
Alagasco | RSE adjustment
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	9.9	19.8
Alagasco | Unbilled service margin
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	15.0	5.2
Alagasco | Refundable negative salvage
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	10.8	13.4
Regulatory Liabilities: Non-current	17.0	26.8
Alagasco | Unamortized purchased gas adjustments
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	37.6	22.4
Alagasco | Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	2.2	2.3
Regulatory Liabilities: Non-current	0.7	0.7
Alagasco | Postretirement liabilities
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	25.1	26.2
Alagasco | Accrued cost of removal
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	0	0
Alagasco | Total Regulatory Liabilities (current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	75.5	63.1
Alagasco | Total Regulatory Liabilities (non-current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	42.8	53.7
Alagasco | Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets: Current	6.4	6.4
Regulatory Assets: Non-current	62.9	66.1
Alagasco | Unamortized purchased gas adjustments
Regulatory Assets [Line Items]
Regulatory Assets: Current	0	0
Alagasco | Future income taxes due from customers
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	0	0
Alagasco | Accretion and depreciation of asset retirement obligations
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	19.1	18.4
Alagasco | Purchased gas costs
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	0	0
Alagasco | Energy efficiency
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	0	0
Alagasco | Other
Regulatory Assets [Line Items]
Regulatory Assets: Current	3.6	2.4
Regulatory Assets: Non-current	5.6	6.1
Alagasco | Total Regulatory Assets (current)
Regulatory Assets [Line Items]
Regulatory Assets: Current	10.0	8.8
Alagasco | Total Regulatory Assets (non-current)
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	$ 87.6	$ 90.6

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INFORMATION BY OPERATING SEGMENT - Schedule of Operating Segment Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014	Sep. 30, 2014
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	$ 877.4	$ 694.5	$ 1,497.0	$ 1,163.1
Total Operating Revenues	877.4	694.5	1,497.0	1,163.1
Gas utility
Natural and propane gas	482.8	405.3	787.1	647.1
Other operation and maintenance expenses	103.8	72.0	200.9	134.3
Depreciation and amortization	32.2	20.1	64.2	40.1
Taxes, other than income taxes	55.7	41.8	93.7	70.4
Total Gas Utility Operating Expenses	674.5	539.2	1,145.9	891.9
Gas Marketing	43.5	65.0	102.1	116.8
Other	1.7	3.1	4.0	4.3
Total Operating Expenses	719.7	607.3	1,252.0	1,013.0
Operating Income	157.7	87.2	245.0	150.1
Net Economic Earnings (Loss)	97.6	51.7	143.3	88.0
ASSETS
Total Assets	5,180.7		5,180.7		5,074.0
Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0	0	0	0
Gas Utility
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	847.0	634.4	1,428.4	1,069.6
Total Operating Revenues	849.0	638.6	1,431.4	1,073.9
Gas utility
Natural and propane gas	499.1	430.5	828.9	692.1
Other operation and maintenance expenses	104.0	72.2	201.4	134.7
Depreciation and amortization	32.2	20.1	64.2	40.1
Taxes, other than income taxes	55.7	41.8	93.7	70.4
Total Gas Utility Operating Expenses	691.0	564.6	1,188.2	937.3
Gas Marketing	0	0	0	0
Other	0	0	0	0
Total Operating Expenses	691.0	564.6	1,188.2	937.3
Operating Income	158.0	74.0	243.2	136.6
Net Economic Earnings (Loss)	96.5	44.7	146.3	80.5
ASSETS
Total Assets	4,615.6		4,615.6		4,520.0
Gas Utility | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	2.0	4.2	3.0	4.3
Gas Marketing
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	30.0	59.9	67.8	93.1
Total Operating Revenues	44.1	80.5	106.3	133.2
Gas utility
Natural and propane gas	0	0	0	0
Other operation and maintenance expenses	0	0	0	0
Depreciation and amortization	0	0	0	0
Taxes, other than income taxes	0	0	0	0
Total Gas Utility Operating Expenses	0	0	0	0
Gas Marketing	43.5	65.0	102.1	116.8
Other	0	0	0	0
Total Operating Expenses	43.5	65.0	102.1	116.8
Operating Income	0.6	15.5	4.2	16.4
Net Economic Earnings (Loss)	2.1	7.1	2.5	7.9
ASSETS
Total Assets	131.7		131.7		156.7
Gas Marketing | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	14.1	20.6	38.5	40.1
Other
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0.4	0.2	0.8	0.4
Total Operating Revenues	0.9	0.8	1.8	1.4
Gas utility
Natural and propane gas	0	0	0	0
Other operation and maintenance expenses	0	0	0	0
Depreciation and amortization	0	0	0	0
Taxes, other than income taxes	0	0	0	0
Total Gas Utility Operating Expenses	0	0	0	0
Gas Marketing	0	0	0	0
Other	1.8	3.1	4.2	4.3
Total Operating Expenses	1.8	3.1	4.2	4.3
Operating Income	(0.9)	(2.3)	(2.4)	(2.9)
Net Economic Earnings (Loss)	(1.0)	(0.1)	(5.5)	(0.4)
ASSETS
Total Assets	1,590.8		1,590.8		1,575.7
Other | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0.5	0.6	1.0	1.0
Eliminations
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0	0	0	0
Total Operating Revenues	(16.6)	(25.4)	(42.5)	(45.4)
Gas utility
Natural and propane gas	(16.3)	(25.2)	(41.8)	(45.0)
Other operation and maintenance expenses	(0.2)	(0.2)	(0.5)	(0.4)
Depreciation and amortization	0	0	0	0
Taxes, other than income taxes	0	0	0	0
Total Gas Utility Operating Expenses	(16.5)	(25.4)	(42.3)	(45.4)
Gas Marketing	0	0	0	0
Other	(0.1)	0	(0.2)	0
Total Operating Expenses	(16.6)	(25.4)	(42.5)	(45.4)
Operating Income	0	0	0	0
Net Economic Earnings (Loss)	0	0	0	0
ASSETS
Total Assets	(1,157.4)		(1,157.4)		(1,178.4)
Eliminations | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	$ (16.6)	$ (25.4)	$ (42.5)	$ (45.4)

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Operating Revenues:
Gas utility	$ 847.0	$ 634.4	$ 1,428.4	$ 1,069.6
Gas marketing and other	30.4	60.1	68.6	93.5
Total Operating Revenues	877.4	694.5	1,497.0	1,163.1
Gas utility
Natural and propane gas	482.8	405.3	787.1	647.1
Other operation and maintenance expenses	103.8	72.0	200.9	134.3
Depreciation and amortization	32.2	20.1	64.2	40.1
Taxes, other than income taxes	55.7	41.8	93.7	70.4
Total Gas Utility Operating Expenses	674.5	539.2	1,145.9	891.9
Gas marketing and other	45.2	68.1	106.1	121.1
Total Operating Expenses	719.7	607.3	1,252.0	1,013.0
Operating Income	157.7	87.2	245.0	150.1
Other Income – Net	0.7	(0.3)	2.1	1.4
Interest Charges:
Interest on long-term debt	16.5	8.6	33.7	18.3
Other interest charges	2.6	0.7	4.6	1.5
Total Interest Charges	19.1	9.3	38.3	19.8
Income Before Income Taxes	139.3	77.6	208.8	131.7
Income Tax Expense	44.9	25.4	67.3	43.9
Net Income	94.4	52.2	141.5	87.8
Weighted Average Number of Common Shares Outstanding:
Basic (in shares)	43.1	32.6	43.1	32.6
Diluted (in shares)	43.2	32.6	43.2	32.7
Basic Earnings Per Share of Common Stock (in dollars per share)	$ 2.18	$ 1.59	$ 3.27	$ 2.68
Diluted Earnings Per Share of Common Stock (in dollars per share)	$ 2.18	$ 1.59	$ 3.26	$ 2.68
Dividends Declared, Common stock (in dollars per share)	$ 0.46	$ 0.44	$ 0.92	$ 0.88
Laclede Gas
Operating Revenues:
Gas utility	615.7	638.7	1,078.1	1,073.9
Other	0	0.1	0	0.1
Total Operating Revenues	615.7	638.8	1,078.1	1,074.0
Gas utility
Natural and propane gas	402.7	430.5	686.1	692.1
Other operation and maintenance expenses	69.6	72.2	134.4	134.7
Depreciation and amortization	20.5	20.1	40.7	40.1
Taxes, other than income taxes	42.3	41.8	71.5	70.4
Total Gas Utility Operating Expenses	535.1	564.6	932.7	937.3
Gas marketing and other	0	(0.3)	0	(0.1)
Total Operating Expenses	535.1	564.3	932.7	937.2
Operating Income	80.6	74.5	145.4	136.8
Other Income – Net	0.4	(0.7)	1.3	1.0
Interest Charges:
Interest on long-term debt	8.3	8.4	16.6	17.9
Other interest charges	1.2	0.7	2.2	1.5
Total Interest Charges	9.5	9.1	18.8	19.4
Income Before Income Taxes	71.5	64.7	127.9	118.4
Income Tax Expense	21.6	20.5	39.0	38.9
Net Income	49.9	44.2	88.9	79.5
Alagasco
Operating Revenues:
Gas utility	233.3	263.9	353.3	406.7
Total Operating Revenues	233.3	263.9	353.3	406.7
Gas utility
Natural and propane gas	96.4	128.1	142.8	180.1
Other operation and maintenance expenses	34.4	36.2	67.0	71.7
Depreciation and amortization	11.7	11.4	23.5	22.6
Taxes, other than income taxes	13.4	15.8	22.2	25.1
Total Operating Expenses	155.9	191.5	255.5	299.5
Operating Income	77.4	72.4	97.8	107.2
Other Income – Net	0.6	1.2	1.0	1.9
Interest Charges:
Interest on long-term debt	2.8	3.4	6.0	6.8
Other interest charges	0.7	0.6	1.3	1.1
Total Interest Charges	3.5	4.0	7.3	7.9
Income Before Income Taxes	74.5	69.6	91.5	101.2
Income Tax Expense	28.2	26.5	34.6	38.3
Net Income	$ 46.3	$ 43.1	$ 56.9	$ 62.9

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CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY (UNAUDITED) (USD $) In Millions, except Share data, unless otherwise specified	Total	Common Stock Issued	Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Loss	Laclede Gas	Laclede Gas Common Stock Issued	Laclede Gas Paid-in Capital	Laclede Gas Retained Earnings	Laclede Gas Accumulated Other Comprehensive Loss	Alagasco	Alagasco Common Stock Issued	Alagasco Paid-in Capital	Alagasco Retained Earnings
BALANCE at Sep. 30, 2013	$ 1,046.3	$ 32.7	$ 594.3	$ 420.1	$ (0.8)	$ 973.9	$ 0.1	$ 738.1	$ 237.8	$ (2.1)	$ 364.7	$ 0	$ 34.5	$ 330.2
BALANCE (in shares) at Sep. 30, 2013		32,696,836					24,549					1,972,052
Stockholders' Equity Rollforward
Net Income	87.8			87.8		79.5			79.5		62.9			62.9
Dividend reinvestment plan (in shares)		15,994
Dividend reinvestment plan	0.7		0.7
Stock-based compensation costs	2.4		2.4			1.8		1.8
Equity Incentive Plan (in shares)		63,765
Equity Incentive Plan	0.7	0.1	0.6
Employees’ taxes paid associated with restricted shares withheld upon vesting	(1.1)		(1.1)
Tax benefit - stock compensation	0.5		0.5			0.4		0.4
Dividends declared	(28.9)			(28.9)		(28.8)			(28.8)		(10.8)			(10.8)
Issuance of common stock to Laclede Group (in shares)							18
Issuance of common stock to Laclede Group						0.7		0.7
Other comprehensive loss, net of tax	(1.8)				(1.8)	0.1				0.1
BALANCE at Mar. 31, 2014	1,106.6	32.8	597.4	479.0	(2.6)	1,027.6	0.1	741.0	288.5	(2.0)	416.8	0	34.5	382.3
BALANCE (in shares) at Mar. 31, 2014		32,776,595					24,567					1,972,052
BALANCE at Dec. 31, 2013
Stockholders' Equity Rollforward
Net Income	52.2					44.2					43.1
Other comprehensive loss, net of tax	(0.1)					0.1
BALANCE at Mar. 31, 2014	1,106.6					1,027.6					416.8	0	34.5
BALANCE (in shares) at Mar. 31, 2014												1,972,052
BALANCE at Sep. 30, 2014	1,508.4	43.2	1,029.4	437.5	(1.7)	1,007.8	0.1	744.0	265.6	(1.9)	849.6	0	503.9	345.7
BALANCE (in shares) at Sep. 30, 2014		43,178,405					24,577					1,972,052
Stockholders' Equity Rollforward
Net Income	141.5			141.5		88.9			88.9		56.9			56.9
Dividend reinvestment plan (in shares)		9,494
Dividend reinvestment plan	0.9		0.9
Stock-based compensation costs	(0.4)		(0.4)			1.7		1.7
Equity Incentive Plan (in shares)		125,949
Equity Incentive Plan	2.9	0.1	2.8
Tax benefit - stock compensation	0.6		0.6			0.5		0.5
Dividends declared	(39.8)			(39.8)		(39.8)			(39.8)
Purchase accounting adjustments											2.4		2.4
Other comprehensive loss, net of tax	(2.5)				(2.5)	(0.5)				(0.5)
BALANCE at Mar. 31, 2015	1,611.6	43.3	1,033.3	539.2	(4.2)	1,058.6	0.1	746.2	314.7	(2.4)	908.9	0	506.3	402.6
BALANCE (in shares) at Mar. 31, 2015		43,313,848					24,577					1,972,052
BALANCE at Dec. 31, 2014
Stockholders' Equity Rollforward
Net Income	94.4					49.9					46.3
Other comprehensive loss, net of tax	1.2					0.3
BALANCE at Mar. 31, 2015	$ 1,611.6					$ 1,058.6	$ 0.1				$ 908.9	$ 0
BALANCE (in shares) at Mar. 31, 2015							24,577					1,972,052

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2015	Sep. 30, 2014	Mar. 31, 2014	Sep. 30, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 46.9	$ 16.1	$ 10.9	$ 53.0
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	46.9	16.1
Short-term debt	247.6	287.1
Long-term debt, including current portion	1,816.3	1,851.0
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	46.9	16.1
Short-term debt	247.6	287.1
Long-term debt, including current portion	1,971.0	1,937.3
Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	9.3	3.7	5.0	23.9
Laclede Gas | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	9.3	3.7
Short-term debt	153.0	238.6
Long-term debt, including current portion	808.0	807.9
Laclede Gas | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	9.3	3.7
Short-term debt	0	238.6
Long-term debt, including current portion	909.5	876.2
Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	35.4	5.6	34.1	8.5
Alagasco | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	35.4	5.6
Short-term debt	25.0	16.0
Long-term debt, including current portion	215.0	249.8
Alagasco | Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	35.4	5.6
Short-term debt	25.0	16.0
Long-term debt, including current portion	235.1	266.4
Quoted Prices in Active Markets (Level 1)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	46.9	16.1
Short-term debt	0	0
Long-term debt, including current portion	0	0
Quoted Prices in Active Markets (Level 1) | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	9.3	3.7
Short-term debt	0	0
Long-term debt, including current portion	0	0
Quoted Prices in Active Markets (Level 1) | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	35.4	5.6
Short-term debt	0	0
Long-term debt, including current portion	0	0
Significant Observable Inputs (Level 2)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0
Short-term debt	247.6	287.1
Long-term debt, including current portion	1,971.0	1,937.3
Significant Observable Inputs (Level 2) | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0
Short-term debt	153.0	238.6
Long-term debt, including current portion	909.5	876.2
Significant Observable Inputs (Level 2) | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0
Short-term debt	25.0	16.0
Long-term debt, including current portion	235.1	266.4
Significant Unobservable Inputs (Level 3)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0
Short-term debt	0	0
Long-term debt, including current portion	0	0
Significant Unobservable Inputs (Level 3) | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0
Short-term debt	0	0
Long-term debt, including current portion	0	0
Significant Unobservable Inputs (Level 3) | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0
Short-term debt	0	0
Long-term debt, including current portion	$ 0	$ 0

XML

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Mar. 31, 2015

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	46.9	$	46.9	$	46.9	$	—	$	—
Short-term debt	247.6		247.6		—		247.6		—
Long-term debt, including current portion	1,816.3		1,971.0		—		1,971.0		—
As of September 30, 2014
Cash and cash equivalents	$	16.1	$	16.1	$	16.1	$	—	$	—
Short-term debt	287.1		287.1		—		287.1		—
Long-term debt	1,851.0		1,937.3		—		1,937.3		—

Laclede Gas

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	9.3	$	9.3	$	9.3	$	—	$	—
Short-term debt	153.0		—		—		153.0		—
Long-term debt	808.0		909.5		—		909.5		—
As of September 30, 2014
Cash and cash equivalents	$	3.7	$	3.7	$	3.7	$	—	$	—
Short-term debt	238.6		238.6		—		238.6		—
Long-term debt	807.9		876.2		—		876.2		—

Alagasco

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair value of financial instruments

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	35.4	$	35.4	$	35.4	$	—	$	—
Short-term debt	25.0		25.0		—		25.0		—
Long-term debt, including current portion	215.0		235.1		—		235.1		—
As of September 30, 2014
Cash and cash equivalents	$	5.6	$	5.6	$	5.6	$	—	$	—
Short-term debt	16.0		16.0		—		16.0		—
Long-term debt	249.8		266.4		—		266.4		—

XML

FAIR VALUE MEASUREMENTS (Details) (Fair Value, Measurements, Recurring, USD $) In Millions, unless otherwise specified	Mar. 31, 2015	Sep. 30, 2014
ASSETS
Total	$ 23.8	$ 22.7
LIABILITIES
Total	17.7	4.5
Quoted Prices in Active Markets (Level 1)
ASSETS
Total	20.4	19.1
LIABILITIES
Total	17.0	6.5
Significant Observable Inputs (Level 2)
ASSETS
Total	8.3	7.9
LIABILITIES
Total	21.7	5.5
Significant Unobservable Inputs (Level 3)
ASSETS
Total	0.5	0.2
LIABILITIES
Total	0	0
Effects of Netting and Cash Margin Receivables /Payables
ASSETS
Total	(5.4)	(4.5)
LIABILITIES
Total	(21.0)	(7.5)
Gas Utility
ASSETS
U. S. Stock/Bond Mutual Funds	20.3	19.6
NYMEX natural gas contracts	0	0
OTCBB natural gas contracts		0
Total	20.3	19.6
LIABILITIES
NYMEX/ICE natural gas contracts	0	0
OTCBB natural gas contracts	14.5	4.0
NYMEX gasoline and heating oil contracts	0	0
Interest rate swaps	2.9
Total	17.4	4.0
Gas Utility | Quoted Prices in Active Markets (Level 1)
ASSETS
U. S. Stock/Bond Mutual Funds	16.4	15.7
NYMEX natural gas contracts	0.6	2.4
OTCBB natural gas contracts		0
Total	17.0	18.1
LIABILITIES
NYMEX/ICE natural gas contracts	14.1	5.2
OTCBB natural gas contracts	0	0
NYMEX gasoline and heating oil contracts	1.0	0.2
Interest rate swaps	0
Total	15.1	5.4
Gas Utility | Significant Observable Inputs (Level 2)
ASSETS
U. S. Stock/Bond Mutual Funds	3.9	3.9
NYMEX natural gas contracts	0	0
OTCBB natural gas contracts		0.1
Total	3.9	4.0
LIABILITIES
NYMEX/ICE natural gas contracts	0	0
OTCBB natural gas contracts	14.5	4.1
NYMEX gasoline and heating oil contracts	0	0
Interest rate swaps	2.9
Total	17.4	4.1
Gas Utility | Significant Unobservable Inputs (Level 3)
ASSETS
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts	0	0
Total	0	0
LIABILITIES
NYMEX/ICE natural gas contracts	0	0
OTCBB natural gas contracts	0	0
NYMEX gasoline and heating oil contracts	0	0
Interest rate swaps	0
Total	0	0
Gas Utility | Effects of Netting and Cash Margin Receivables /Payables
ASSETS
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts	(0.6)	(2.4)
OTCBB natural gas contracts		(0.1)
Total	(0.6)	(2.5)
LIABILITIES
NYMEX/ICE natural gas contracts	(14.1)	(5.2)
OTCBB natural gas contracts	0	(0.1)
NYMEX gasoline and heating oil contracts	(1.0)	(0.2)
Interest rate swaps	0
Total	(15.1)	(5.5)
Gas Marketing
ASSETS
NYMEX natural gas contracts	0.8	0.4
Natural gas commodity contracts	2.7	2.7
LIABILITIES
NYMEX natural gas contracts	0	0
Natural gas commodity contracts	0.3	0.5
Gas Marketing | Quoted Prices in Active Markets (Level 1)
ASSETS
NYMEX natural gas contracts	3.4	1.0
Natural gas commodity contracts	0	0
LIABILITIES
NYMEX natural gas contracts	1.9	1.1
Natural gas commodity contracts	0	0
Gas Marketing | Significant Observable Inputs (Level 2)
ASSETS
NYMEX natural gas contracts	1.7	1.2
Natural gas commodity contracts	2.7	2.7
LIABILITIES
NYMEX natural gas contracts	3.5	0.7
Natural gas commodity contracts	0.8	0.7
Gas Marketing | Significant Unobservable Inputs (Level 3)
ASSETS
NYMEX natural gas contracts	0	0
Natural gas commodity contracts	0.5	0.2
LIABILITIES
NYMEX natural gas contracts	0	0
Natural gas commodity contracts	0	0
Gas Marketing | Effects of Netting and Cash Margin Receivables /Payables
ASSETS
NYMEX natural gas contracts	(4.3)	(1.8)
Natural gas commodity contracts	(0.5)	(0.2)
LIABILITIES
NYMEX natural gas contracts	(5.4)	(1.8)
Natural gas commodity contracts	(0.5)	(0.2)
Laclede Gas
ASSETS
U. S. Stock/Bond Mutual Funds	20.3	19.6
NYMEX natural gas contracts	0	0
OTCBB natural gas contracts		0
Total	20.3	19.6
LIABILITIES
NYMEX/ICE natural gas contracts		0
OTCBB natural gas contracts	14.5	4.0
NYMEX gasoline and heating oil contracts	0	0
NYMEX natural gas contracts	0
Total	14.5	4.0
Laclede Gas | Quoted Prices in Active Markets (Level 1)
ASSETS
U. S. Stock/Bond Mutual Funds	16.4	15.7
NYMEX natural gas contracts	0.6	2.4
OTCBB natural gas contracts		0
Total	17.0	18.1
LIABILITIES
NYMEX/ICE natural gas contracts		5.2
OTCBB natural gas contracts	0	0
NYMEX gasoline and heating oil contracts	1.0	0.2
NYMEX natural gas contracts	14.1
Total	15.1	5.4
Laclede Gas | Significant Observable Inputs (Level 2)
ASSETS
U. S. Stock/Bond Mutual Funds	3.9	3.9
NYMEX natural gas contracts	0	0
OTCBB natural gas contracts		0.1
Total	3.9	4.0
LIABILITIES
NYMEX/ICE natural gas contracts		0
OTCBB natural gas contracts	14.5	4.1
NYMEX gasoline and heating oil contracts	0	0
NYMEX natural gas contracts	0
Total	14.5	4.1
Laclede Gas | Significant Unobservable Inputs (Level 3)
ASSETS
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts	0	0
Total	0	0
LIABILITIES
NYMEX/ICE natural gas contracts		0
OTCBB natural gas contracts	0	0
NYMEX gasoline and heating oil contracts	0	0
NYMEX natural gas contracts	0
Total	0	0
Laclede Gas | Effects of Netting and Cash Margin Receivables /Payables
ASSETS
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts	(0.6)	(2.4)
OTCBB natural gas contracts		(0.1)
Total	(0.6)	(2.5)
LIABILITIES
NYMEX/ICE natural gas contracts		(5.2)
OTCBB natural gas contracts	0	(0.1)
NYMEX gasoline and heating oil contracts	(1.0)	(0.2)
NYMEX natural gas contracts	(14.1)
Total	(15.1)	(5.5)
Alagasco
LIABILITIES
Interest rate swaps	2.9	0
Total	2.9	0
Alagasco | Quoted Prices in Active Markets (Level 1)
LIABILITIES
Interest rate swaps	0	0
Total	0	0
Alagasco | Significant Observable Inputs (Level 2)
LIABILITIES
Interest rate swaps	2.9	0
Total	2.9	0
Alagasco | Significant Unobservable Inputs (Level 3)
LIABILITIES
Interest rate swaps	0	0
Total	0	0
Alagasco | Effects of Netting and Cash Margin Receivables /Payables
LIABILITIES
Interest rate swaps	0	0
Total	$ 0	$ 0

XML

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS (Tables)

6 Months Ended

Mar. 31, 2015

Pension Plans

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Cost

The net periodic pension cost included the following components:

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Laclede Group
Service cost – benefits earned during the period	$	4.3		$	2.5		$	8.6		$	4.9
Interest cost on projected benefit obligation	7.4			6.0			14.9			12.0
Expected return on plan assets	(9.3		)	(6.7		)	(18.7		)	(13.3		)
Amortization of prior service cost	0.1			0.1			0.2			0.2
Amortization of actuarial loss	2.0			1.7			3.9			3.5
Loss on lump-sum settlements	—			1.3			—			1.3
Sub-total	4.5			4.9			8.9			8.6
Regulatory adjustment	4.8			1.6			9.7			4.5
Net pension cost	$	9.3		$	6.5		$	18.6		$	13.1

Postretirement Plans

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Cost

Net periodic postretirement benefit cost for the Company consisted of the following components:

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Laclede Group
Service cost – benefits earned during the period	$	3.2		$	2.8		$	6.4		$	5.6
Interest cost on accumulated postretirement benefit obligation	2.8			2.2			5.6			4.4
Expected return on plan assets	(3.3		)	(1.7		)	(6.6		)	(3.4		)
Amortization of prior service credit	0.2			—			0.4			—
Amortization of actuarial loss	1.2			1.5			2.5			3.0
Sub-total	4.1			4.8			8.3			9.6
Regulatory adjustment	(2.7		)	(2.4		)	(5.4		)	(4.8		)
Net postretirement benefit cost	$	1.4		$	2.4		$	2.9		$	4.8

Laclede Gas | Pension Plans

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Cost

Laclede Gas
Service cost – benefits earned during the period	$	2.9		$	2.5		$	5.7		$	4.9
Interest cost on projected benefit obligation	5.9			6.0			11.8			12.0
Expected return on plan assets	(7.3		)	(6.7		)	(14.6		)	(13.3		)
Amortization of prior service cost	0.1			0.1			0.2			0.2
Amortization of actuarial loss	2.0			1.7			3.9			3.5
Loss on lump-sum settlements	—			1.3			—			1.3
Sub-total	3.6			4.9			7.0			8.6
Regulatory adjustment	3.4			1.6			6.8			4.5
Net pension cost	$	7.0		$	6.5		$	13.8		$	13.1

Laclede Gas | Postretirement Plans

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Cost

Laclede Gas
Service cost – benefits earned during the period	$	3.1		$	2.8		$	6.2		$	5.6
Interest cost on accumulated postretirement benefit obligation	2.2			2.2			4.3			4.4
Expected return on plan assets	(2.1		)	(1.7		)	(4.1		)	(3.4		)
Amortization of prior service cost	0.2			—			0.4			—
Amortization of actuarial loss	1.2			1.5			2.5			3.0
Sub-total	4.6			4.8			9.3			9.6
Regulatory adjustment	(2.3		)	(2.4		)	(4.6		)	(4.8		)
Net postretirement benefit cost	$	2.3		$	2.4		$	4.7		$	4.8

Alagasco | Pension Plans

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Cost

Alagasco
Service cost – benefits earned during the period	$	1.4		$	1.5		$	2.9		$	3.6
Interest cost on projected benefit obligation	1.5			1.2			3.1			2.9
Expected return on plan assets	(2.0		)	(1.5		)	(4.1		)	(3.7		)
Amortization of prior service cost	—			0.1			—			0.1
Amortization of actuarial loss	—			0.7			—			2.0
Loss on lump-sum settlements	—			10.1			—			10.9
Sub-total	0.9			12.1			1.9			15.8
Regulatory adjustment	1.4			(9.8		)	2.9			(10.6		)
Net pension cost	$	2.3		$	2.3		$	4.8		$	5.2

Alagasco | Postretirement Plans

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Cost

Alagasco
Service cost – benefits earned during the period	$	0.1		$	0.1		$	0.2		$	0.4
Interest cost on accumulated postretirement benefit obligation	0.6			0.5			1.3			1.2
Expected return on plan assets	(1.2		)	(1.1		)	(2.5		)	(2.1		)
Amortization of actuarial loss and other	—			(0.4		)	—			(0.5		)
Amortization of transition obligation	—			0.1			—			0.3
Sub-total	(0.5		)	(0.8		)	(1.0		)	(0.7		)
Regulatory adjustment	(0.4		)	—			(0.8		)	—
Net postretirement benefit cost	$	(0.9	)	$	(0.8	)	$	(1.8	)	$	(0.7	)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Operating Activities:
Net Income	$ 141.5	$ 87.8
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	64.7	40.5
Changes in assets and liabilities:
Accounts receivable	(139.4)	(211.7)
Unamortized purchased gas adjustments	108.2	15.9
Deferred purchased gas costs	(14.3)	27.8
Accounts payable	(12.1)	79.4
Delayed/advance customer billings – net	(74.7)	(53.4)
Taxes accrued	21.5	38.1
Inventories	153.1	114.2
Other assets and liabilities	(2.1)	(1.3)
Other	33.5	5.5
Net cash provided by operating activities	279.9	142.8
Investing Activities:
Capital expenditures	(129.5)	(68.2)
Proceeds from sale of right to acquire New England Gas Company	0	11.0
(Payments for) proceeds from final reconciliation of acquisitions	(8.6)	23.9
Other	(0.4)	(5.1)
Net cash used in investing activities	(138.5)	(38.4)
Financing Activities:
Redemption and maturity of long-term debt	(34.7)	(80.0)
Repayment of short-term debt – net	(39.6)	(38.0)
Issuance of common stock	2.8	1.4
Dividends paid	(39.2)	(28.5)
Employees’ taxes paid associated with restricted shares withheld upon vesting	(1.6)	(1.1)
Other	1.7	(0.3)
Net cash used in financing activities	(110.6)	(146.5)
Net Increase (Decrease) in Cash and Cash Equivalents	30.8	(42.1)
Cash and Cash Equivalents at Beginning of Year	16.1	53.0
Cash and Cash Equivalents at End of Year	46.9	10.9
Supplemental disclosure of cash flow information:
Interest paid	(36.1)	(19.7)
Income taxes (paid) refunded	0.3	2.6
Laclede Gas
Operating Activities:
Net Income	88.9	79.5
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	40.7	40.1
Changes in assets and liabilities:
Accounts receivable	(100.9)	(170.7)
Unamortized purchased gas adjustments	93.0	15.9
Deferred purchased gas costs	(14.3)	27.8
Accounts payable	11.4	55.3
Delayed/advance customer billings – net	(66.4)	(53.4)
Taxes accrued	35.4	36.8
Inventories	128.7	105.1
Other assets and liabilities	12.8	2.7
Other	(6.1)	5.4
Net cash provided by operating activities	223.2	144.5
Investing Activities:
Capital expenditures	(93.4)	(67.1)
Proceeds from final reconciliation of acquisition of Missouri Gas Energy	0	23.9
Other	0	(4.8)
Net cash used in investing activities	(93.4)	(48.0)
Financing Activities:
Redemption and maturity of first mortgage bonds	0	(80.0)
Repayment of short-term debt – net	(96.1)	(38.0)
Borrowings from Laclede Group	16.8	121.8
Repayment of borrowings from Laclede Group	(6.4)	(91.2)
Issuance of common stock	0	0.7
Dividends paid	(38.9)	(28.3)
Other	0.4	(0.4)
Net cash used in financing activities	(124.2)	(115.4)
Net Increase (Decrease) in Cash and Cash Equivalents	5.6	(18.9)
Cash and Cash Equivalents at Beginning of Year	3.7	23.9
Cash and Cash Equivalents at End of Year	9.3	5.0
Supplemental disclosure of cash flow information:
Interest paid	(18.4)	(19.5)
Income taxes (paid) refunded	0.6	1.2
Alagasco
Operating Activities:
Net Income	56.9	62.9
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	23.5	22.6
Changes in assets and liabilities:
Accounts receivable	(44.0)	(64.5)
Unamortized purchased gas adjustments	15.2	23.8
Accounts payable	4.2	19.9
Advance customer billings	(8.3)	(13.6)
Taxes accrued	(7.0)	18.5
Inventories	20.5	21.9
Other assets and liabilities	(7.0)	29.0
Other	35.2	(3.7)
Net cash provided by operating activities	89.2	116.8
Investing Activities:
Capital expenditures	(34.2)	(34.4)
Proceeds from sale of assets	0	0
Other	(0.2)	3.1
Net cash used in investing activities	(34.4)	(31.3)
Financing Activities:
Redemption and maturity of long-term debt	(34.7)	0
Issuance (repayment) of short-term debt – net	9.0	(49.0)
Borrowings from Laclede Group	0.8	0
Dividends paid	0	(10.8)
Other	(0.1)	(0.1)
Net cash used in financing activities	(25.0)	(59.9)
Net Increase (Decrease) in Cash and Cash Equivalents	29.8	25.6
Cash and Cash Equivalents at Beginning of Year	5.6	8.5
Cash and Cash Equivalents at End of Year	35.4	34.1
Supplemental disclosure of cash flow information:
Interest paid	(6.7)	(6.8)
Income taxes (paid) refunded	$ 0	$ (5.3)

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Net Income	$ 94.4	$ 52.2	$ 141.5	$ 87.8
Net gains (losses) on cash flow hedging derivative instruments:
Net hedging gains (losses) arising during the period	(0.6)	(3.5)	(6.5)	(5.1)
Reclassification adjustment for losses (gains) included in net income	2.3	3.2	2.2	2.0
Net unrealized gains (losses) on cash flow hedging derivative instruments	1.7	(0.3)	(4.3)	(3.1)
Defined benefit pension and other postretirement plans:
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	0.1	0.1	0.2	0.2
Other Comprehensive Income (Loss), Before Tax	1.8	(0.2)	(4.1)	(2.9)
Income Tax Expense (Benefit) Related to Items of Other Comprehensive Income	0.6	(0.1)	(1.6)	(1.1)
Other Comprehensive Income (Loss), Net of Tax	1.2	(0.1)	(2.5)	(1.8)
Comprehensive Income	95.6	52.1	139.0	86.0
Laclede Gas
Net Income	49.9	44.2	88.9	79.5
Net gains (losses) on cash flow hedging derivative instruments:
Net hedging gains (losses) arising during the period	0.1	0.1	(1.3)	0.1
Reclassification adjustment for losses (gains) included in net income	0.3	0	0.4	(0.1)
Net unrealized gains (losses) on cash flow hedging derivative instruments	0.4	0.1	(0.9)	0
Defined benefit pension and other postretirement plans:
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	0	0.1	0.1	0.2
Other Comprehensive Income (Loss), Before Tax	0.4	0.2	(0.8)	0.2
Income Tax Expense (Benefit) Related to Items of Other Comprehensive Income	0.1	0.1	(0.3)	0.1
Other Comprehensive Income (Loss), Net of Tax	0.3	0.1	(0.5)	0.1
Comprehensive Income	$ 50.2	$ 44.3	$ 88.4	$ 79.6

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Mar. 31, 2015

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

Commitments

The Company and the Utilities have entered into contracts with various counterparties, expiring on dates through 2019, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at March 31, 2015 are estimated at approximately $1,595.0, $750.4, and $521.5 for the Company, Laclede Gas, and Alagasco, respectively. Additional contracts are generally entered into prior to or during the heating season of November through April. The Missouri Utilities recover their costs from customers in accordance with their PGA clause and Alagasco recovers its cost through its GSA rider.

Contingencies

Laclede Gas

Similar to other natural gas utility companies, 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, the Company or Laclede Gas may incur additional environmental liabilities that may result in additional costs.

In the natural gas industry, many gas distribution companies like Laclede Gas and MGE have incurred environmental liabilities associated with sites they or their predecessor companies formerly owned or operated where 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. Laclede Gas has enrolled the two sites in the City of St. Louis in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP). MGE has enrolled all of its owned former manufactured gas plant sites in the BVCP.

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.

In conjunction with redevelopment of one of the sites located in the City of St. Louis, 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 coverage, 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, Laclede Gas 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. Accordingly, Laclede Gas was able to enter into a cost sharing agreement for remedial investigation with other potentially responsible parties. Pending Missouri Department of Natural Resources approval, the remedial investigation of the site will begin. 

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.

On March 10, 2015, Laclede Gas received a Section 104(e) information request from Region 7 of the United States Environmental Protection Agency (EPA) in respect to the former Thompson Chemical/Superior Solvents site located at 60 Chouteau Avenue in St. Louis, Missouri. Laclede Gas is currently reviewing its records, and responses are due to the EPA on May 26, 2015. In turn, Laclede Gas has issued a Freedom of Information Act request to the EPA dated April 3, 2015, in an effort to identify the basis of the EPA’s inquiry.

MGE has seven owned MGP sites enrolled in the BVCP, including Joplin MGP #1, St. Joseph MGP #1, Kansas City Coal Gas Station B, Kansas City Station A Railroad, Kansas City Coal Gas Station A North, Kansas City Coal Gas Station A South, and Independence MGP #2. Source removal has been conducted at all of the owned sites since 2003 with the exception of Joplin, which is in the early stages of site analysis and characterization. Remediation efforts at these sites are at various stages of completion, ranging from groundwater monitoring and sampling following source removal activities to early site characterization in Joplin. As part of its participation in the BVCP, MGE communicates regularly with the MDNR with respect to its remediation efforts and monitoring activities at these sites.

To date, costs incurred for all Missouri Utilities' MGP sites for investigation, remediation and monitoring 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. The actual future costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remediation actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and government regulations, the ultimate ability of other potential responsible parties to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries.

In 2013, Laclede Gas retained an outside consultant to conduct probabilistic cost modeling of 19 former MGP sites owned or operated by Laclede Gas or MGE. The purpose of this analysis was to develop an estimated range of probabilistic future liability for each site. That analysis, completed in August 2014, provided a range of demonstrated possible future expenditures to investigate, monitor and remediate all 19 MGP sites from $8.1 to $39.3 based upon current available facts, technology and laws and regulations.

Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable. To the extent such costs (less any amounts received from insurance proceeds or as contributions from other potential responsible parties), are incurred prior to a rate case, Laclede Gas would request from the MoPSC authority to defer such costs and collect them in the next rate case. The Company does not expect potential liabilities that may arise from remediating these sites to have a material impact on the future financial position or results of operations of Laclede Gas or the Company.

Alagasco

Alagasco 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 Alagasco's financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Alagasco may be required to incur additional costs.

Alagasco is in the chain of title of nine former MGP sites, four of which it still owns, and five former manufactured gas distribution sites, one of which it still owns. Management expects that, should future remediation of the sites be required, Alagasco’s share of the remediation costs will not materially affect the financial position of Alagasco. During 2011, a removal action was completed at the Huntsville, Alabama MGP site pursuant to an Administrative Settlement Agreement and Order on Consent among the EPA, Alagasco and the current site owner.

In 2012, Alagasco responded to an EPA Request for Information Pursuant to Section 104 of Comprehensive Environment Response, Compensation, and Liability Act (CERCLA) relating to the 35th Avenue Superfund Site located in North Birmingham, Jefferson County, Alabama. The Request related to a former site of a manufactured gas distribution facility owned by Alagasco and located in the vicinity of the 35th Avenue Superfund Site. In September 2013, Alagasco received from the EPA a General Notice Letter and Invitation to Conduct a Removal Action at the 35th Avenue Superfund Site. The letter identifies Alagasco as a potentially responsible party (PRP) under CERCLA for the cleanup of the Site or costs the EPA incurs in cleaning up the site. The EPA also offered the PRP group the opportunity to conduct Phase I of the proposed removal action which involved removal activities at approximately 50 residences that purportedly exceed certain risk levels for contamination. All Phase I work was conducted by EPA without PRP participation, and is completed or close to completion. In August of 2014, EPA offered the PRP group the opportunity to conduct Phase II of the proposed removal action which involved removal activities at approximately 30 additional residences that purportedly exceed certain risk levels for contamination. Alagasco has not agreed to undertake any of the proposed removal activities.

Alagasco has discussed its designation as a PRP with the EPA (including an in-person meeting in Atlanta), and Alagasco has requested additional information from the EPA regarding the testing and removal activities and its designation as a PRP. To this point, Alagasco has not been provided information that would allow it to determine the extent, if any, of its potential liability with respect to the 35th Avenue Superfund Site.

Alagasco has also been approached by a law firm regarding entry into an agreement to toll the statute of limitations with potential plaintiffs related to purported damages allegedly incurred by such potential plaintiffs in connection with the 35th Avenue Superfund Site, and is considering whether to enter into such a tolling arrangement.

The EPA published a proposal to add the 35th Avenue Superfund Site to its National Priorities List (NPL). CERCLA requires that the National Oil and Hazardous Substances Pollution Contingency Plan (NCP) include a list of national priorities among the known releases or threatened releases of hazardous substances, pollutants or contaminants throughout the United States. The NPL constitutes this list. Alagasco submitted comments in opposition to the proposed listing on January 20, 2015.

Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable. To the extent such costs (less any amounts received from insurance proceeds or as contributions from other potential responsible parties) are incurred, Alagasco would defer such costs and recover them over a period of time in accordance with Alagasco's Enhanced Stability Reserve (ESR). Alagasco does not expect potential liabilities that may arise from remediating these sites to have a material impact on the future financial position or results of operations of Alagasco or the Company.

On December 17, 2013, an incident occurred at a Housing Authority apartment complex in Birmingham, Alabama which resulted in one fatality, personal injuries and property damage. Alagasco is cooperating with the National Transportation Safety Board which is investigating the incident. Alagasco has been named as a defendant in several lawsuits arising from the incident, and additional lawsuits and claims may be filed against Alagasco.

Alagasco is, from time to time, a party to various pending or threatened legal proceedings and has accrued a provision for its estimated liability. Certain of these lawsuits include claims for punitive damages in addition to other specified relief. Alagasco recognizes its liability for contingencies when information available indicates both a loss is probable and the amount of the loss can be reasonably estimated. Based upon information presently available, and in light of available legal and other defenses, contingent liabilities arising from threatened and pending litigation are not considered material in relation to the financial position of Alagasco. It should be noted, however, that there is uncertainty in the valuation of pending claims and prediction of litigation results.

Laclede Group

The Company, Laclede Gas and Alagasco are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcomes of such matters will not have a material effect on the statements of income, balance sheets, and statements of cash flows of the Company, Laclede Gas, or Alagasco.

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Document and Entity Information	6 Months Ended
	Mar. 31, 2015	Apr. 30, 2015
Entity Information [Line Items]
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 Common Stock, Shares Outstanding		43,318,933
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2015
Laclede Gas
Entity Information [Line Items]
Entity Registrant Name	LACLEDE GAS CO
Entity Central Index Key	0000057183
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		24,577
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2015
Alagasco
Entity Information [Line Items]
Entity Registrant Name	ALABAMA GAS CORP
Entity Central Index Key	0000003146
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		1,972,052
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2015

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

BASIS OF PRESENTATION

BASIS OF PRESENTATION - These notes are an integral part of the accompanying unaudited financial statements of The Laclede Group, Inc. (Laclede Group or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco or the Alabama Utility). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Collectively, Laclede Gas and Alagasco are referred to as the Utilities. The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial information with the instructions to Form 10-Q and Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the disclosures required for complete financial statements. In the opinion of management, the accompanying unaudited financial statements include 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 the Financial Statements contained in Laclede Group's, Laclede Gas' and Alagasco's Annual Reports on Form 10-K or 10-KT for the fiscal year or transition period, as applicable, ended September 30, 2014.

The consolidated financial position, results of operations, and cash flows of Laclede Group are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between the Utilities and their affiliates, as well as intercompany balances on the Utilities' Balance Sheets, have not been eliminated from the Utilities' financial statements. As a result of the Company's August 31, 2014 acquisition of Alagasco, the Company's results of operations for the three and six months ended March 31, 2015 include Alagasco, which impacts the comparability of the current year financial statements to prior years. For a further discussion of the acquisition, see Note 2, Alagasco Acquisition.

The Utilities are regulated natural gas distribution utilities. Due to the seasonal nature of the Utilities, Laclede Group’s earnings are typically concentrated during the heating season of November through April each fiscal year. As a result, the interim statements of income for Laclede Group are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year.

REVENUE RECOGNITION

REVENUE RECOGNITION - The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their 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 for Laclede Gas at March 31, 2015 and September 30, 2014 were $63.5 and $29.4, respectively.

Alagasco records natural gas distribution revenues in accordance with the tariff established by the Alabama Public Service Commission (APSC). The amount of accrued unbilled revenues, which is not recorded as revenue until billed, for Alagasco at March 31, 2015 and September 30, 2014 were $15.0 and $5.2, respectively.

Laclede Group's other subsidiaries, including LER, record revenues when earned, either when the product is delivered or when services are performed.

In the course of its business, LER 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 Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 815, “Derivatives and Hedging.” Those contracts are accounted for as executory contracts and recorded on an accrual basis. Revenues and expenses from such contracts are recorded using a gross presentation. Contracts not designated as normal purchases or normal sales are recorded as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. Certain of LER’s wholesale purchase and sale transactions entered on or after January 1, 2012 are classified as trading activities for financial reporting purposes. Under GAAP, revenues and expenses associated with trading activities are presented on a net basis in Gas Marketing Operating Revenues in the Condensed Consolidated Statements of Income. This net presentation has no effect on operating income or net income.

GROSS RECEIPTS TAXES

GROSS RECEIPTS TAXES - Gross receipts taxes associated with the Utilities' services are imposed on the Utilities and billed to customers. These amounts are recorded gross in the Operating Revenues line in the Company's Condensed Consolidated Statements of Income and the Utilities' Condensed Statements of Income. Gross receipts taxes are expensed by the Utilities and are included in the "Taxes, other than income taxes" line in the Company's Condensed Consolidated Statements of Income and the Utilities' Condensed Statements of Income.

REGULATED OPERATIONS

REGULATED OPERATIONS - The Utilities account for their regulated operations in accordance with FASB ASC Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. In addition, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process.

GOODWILL

GOODWILL - Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities.

NEW ACCOUNTING PRONOUNCEMENTS

NEW ACCOUNTING PRONOUNCEMENTS - In May 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers. This standard is intended to improve the financial reporting requirements for revenue from contracts with customers by providing a principles-based approach to the recognition of revenue. The core principle of the standard is when an entity transfers goods or services to customers it will recognize revenue in an amount that reflects the consideration the entity expects to be entitled to for those goods or services. The standard outlines a five-step model and related application guidance, which replaces most existing revenue recognition guidance. ASU 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The guidance is currently effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early adoption not permitted. In April 2015, the FASB proposed (for public comment) a one-year deferral of the effective date (which also would permit early application as of the standard's original effective date). The Company, Laclede Gas and Alagasco are currently assessing the available transition methods and the potential impacts of the standard, which must be adopted by the first quarter of fiscal 2018 (or fiscal 2019, if the effective date is delayed as proposed).

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CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $) In Millions, unless otherwise specified	Mar. 31, 2015	Sep. 30, 2014
ASSETS
Utility Plant	$ 4,037.8	$ 3,928.3
Less: Accumulated depreciation and amortization	1,213.1	1,168.6
Net Utility Plant	2,824.7	2,759.7
Non-utility Property (net of accumulated depreciation and amortization, $7.2 and $6.7 at March 31, 2015 and September 30, 2014, respectively)	10.5	9.2
Goodwill	946.0	937.8
Other Property and Investments	60.8	60.0
Total Other Property and Investments	1,017.3	1,007.0
Current Assets:
Cash and cash equivalents	46.9	16.1
Accounts receivable:
Utility	303.8	148.2
Other	70.1	86.5
Allowance for doubtful accounts	(18.6)	(15.9)
Delayed customer billings	61.7	10.8
Inventories:
Natural gas	90.8	245.5
Propane gas	11.9	11.7
Materials and supplies	14.3	13.0
Natural gas receivable	5.9	7.3
Derivative instrument assets	3.0	2.4
Unamortized purchased gas adjustments	0	54.0
Regulatory assets	27.4	26.8
Prepayments and other	20.0	21.6
Total Current Assets	637.2	628.0
Deferred Charges:
Regulatory assets	632.9	614.3
Other	68.6	65.0
Total Deferred Charges	701.5	679.3
Total Assets	5,180.7	5,074.0
Capitalization:
Common stock	43.3	43.2
Paid-in capital	1,033.3	1,029.4
Retained earnings	539.2	437.5
Accumulated other comprehensive loss	(4.2)	(1.7)
Total Common Stock Equity	1,611.6	1,508.4
Long-term debt (less current portion)	1,736.3	1,851.0
Total Capitalization	3,347.9	3,359.4
Current Liabilities:
Current portion of long-term debt	80.0	0
Notes payable	247.6	287.1
Accounts payable	160.1	176.7
Advance customer billings	8.4	32.2
Wages and compensation accrued	30.9	36.0
Dividends payable	20.5	19.9
Customer deposits	36.2	34.0
Interest accrued	14.9	15.1
Unamortized purchased gas adjustments	76.7	22.4
Taxes accrued	85.2	63.4
Deferred income taxes	0	9.9
Regulatory liabilities	38.5	41.3
Other	54.7	47.8
Total Current Liabilities	853.7	785.8
Deferred Credits and Other Liabilities:
Deferred income taxes	438.7	383.8
Pension and postretirement benefit costs	243.9	244.9
Asset retirement obligations	101.5	99.2
Regulatory liabilities	114.3	125.8
Other	80.7	75.1
Total Deferred Credits and Other Liabilities	979.1	928.8
Commitments and Contingencies
Total Capitalization and Liabilities	5,180.7	5,074.0
Laclede Gas
ASSETS
Utility Plant	2,479.8	2,403.3
Less: Accumulated depreciation and amortization	566.2	542.3
Net Utility Plant	1,913.6	1,861.0
Goodwill	210.2	210.2
Other Property and Investments	56.5	55.7
Total Other Property and Investments	266.7	265.9
Current Assets:
Cash and cash equivalents	9.3	3.7
Accounts receivable:
Utility	224.1	111.1
Other	19.4	19.2
Allowance for doubtful accounts	(14.0)	(10.7)
Delayed customer billings	61.7	10.8
Receivables from associated companies	2.3	11.4
Inventories:
Natural gas	60.8	191.1
Propane gas	12.0	11.7
Materials and supplies	9.2	7.8
Unamortized purchased gas adjustments	0	54.0
Regulatory assets	17.4	18.0
Prepayments and other	16.2	15.5
Total Current Assets	418.4	443.6
Deferred Charges:
Regulatory assets	545.3	523.7
Other	11.9	10.8
Total Deferred Charges	557.2	534.5
Total Assets	3,155.9	3,105.0
Capitalization:
Common stock and Paid-in capital	746.3	744.1
Retained earnings	314.7	265.6
Accumulated other comprehensive loss	(2.4)	(1.9)
Total Common Stock Equity	1,058.6	1,007.8
Long-term debt (less current portion)	808.0	807.9
Total Capitalization	1,866.6	1,815.7
Current Liabilities:
Notes payable	142.6	238.6
Notes payable – associated companies	10.4	0
Accounts payable	77.3	70.1
Accounts payable – associated companies	5.7	6.0
Advance customer billings	0	15.5
Wages and compensation accrued	26.9	30.3
Dividends payable	19.9	19.0
Customer deposits	15.2	14.8
Interest accrued	8.1	8.1
Unamortized purchased gas adjustments	39.1	0
Taxes accrued	79.2	43.9
Other	36.3	41.9
Total Current Liabilities	460.7	488.2
Deferred Credits and Other Liabilities:
Deferred income taxes	424.3	399.8
Pension and postretirement benefit costs	212.4	215.3
Asset retirement obligations	72.9	71.2
Regulatory liabilities	71.7	72.1
Other	47.3	42.7
Total Deferred Credits and Other Liabilities	828.6	801.1
Commitments and Contingencies
Total Capitalization and Liabilities	3,155.9	3,105.0
Alagasco
ASSETS
Utility Plant	1,558.0	1,525.1
Less: Accumulated depreciation and amortization	646.9	626.4
Net Utility Plant	911.1	898.7
Current Assets:
Cash and cash equivalents	35.4	5.6
Accounts receivable:
Utility	79.6	39.0
Other	5.2	5.1
Allowance for doubtful accounts	(4.6)	(5.1)
Inventories:
Natural gas	27.6	48.0
Materials and supplies	4.9	5.1
Regulatory assets	10.0	8.8
Deferred income taxes	0	2.3
Prepayments and other	3.3	1.6
Total Current Assets	161.4	110.4
Deferred Charges:
Regulatory assets	87.6	90.6
Deferred income taxes	249.1	277.8
Other	50.4	47.1
Total Deferred Charges	387.1	415.5
Total Assets	1,459.6	1,424.6
Capitalization:
Common stock	0	0
Paid-in capital	506.3	503.9
Retained earnings	402.6	345.7
Total Common Stock Equity	908.9	849.6
Long-term debt (less current portion)	135.0	249.8
Total Capitalization	1,043.9	1,099.4
Current Liabilities:
Current portion of long-term debt	80.0	0
Notes payable	25.0	16.0
Accounts payable	37.9	34.2
Accounts payable – associated companies	1.2	0.4
Advance customer billings	8.4	16.7
Wages and compensation accrued	4.0	5.7
Customer deposits	21.0	19.1
Interest accrued	3.6	3.9
Unamortized purchased gas adjustments	37.6	22.4
Taxes accrued	23.0	30.0
Regulatory liabilities	37.9	40.7
Other	11.1	6.8
Total Current Liabilities	290.7	195.9
Deferred Credits and Other Liabilities:
Pension and postretirement benefit costs	31.5	29.6
Asset retirement obligations	28.4	27.7
Regulatory liabilities	42.8	53.7
Other	22.3	18.3
Total Deferred Credits and Other Liabilities	125.0	129.3
Total Capitalization and Liabilities	$ 1,459.6	$ 1,424.6

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FAIR VALUE OF FINANCIAL INSTRUMENTS

6 Months Ended

Mar. 31, 2015

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts of 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.

Laclede Group

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	46.9	$	46.9	$	46.9	$	—	$	—
Short-term debt	247.6		247.6		—		247.6		—
Long-term debt, including current portion	1,816.3		1,971.0		—		1,971.0		—
As of September 30, 2014
Cash and cash equivalents	$	16.1	$	16.1	$	16.1	$	—	$	—
Short-term debt	287.1		287.1		—		287.1		—
Long-term debt	1,851.0		1,937.3		—		1,937.3		—

Laclede Gas

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	9.3	$	9.3	$	9.3	$	—	$	—
Short-term debt	153.0		—		—		153.0		—
Long-term debt	808.0		909.5		—		909.5		—
As of September 30, 2014
Cash and cash equivalents	$	3.7	$	3.7	$	3.7	$	—	$	—
Short-term debt	238.6		238.6		—		238.6		—
Long-term debt	807.9		876.2		—		876.2		—

Alagasco

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

					Classification of Estimated Fair Value
($ Millions)	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, 2015
Cash and cash equivalents	$	35.4	$	35.4	$	35.4	$	—	$	—
Short-term debt	25.0		25.0		—		25.0		—
Long-term debt, including current portion	215.0		235.1		—		235.1		—
As of September 30, 2014
Cash and cash equivalents	$	5.6	$	5.6	$	5.6	$	—	$	—
Short-term debt	16.0		16.0		—		16.0		—
Long-term debt	249.8		266.4		—		266.4		—

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REGULATORY MATTERS

6 Months Ended

Mar. 31, 2015

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY MATTERS

As explained in Note 1, Summary of Significant Accounting Policies, Laclede Gas and Alagasco account for regulated operations in accordance with FASB ASC Topic 980, "Regulated Operations." The following regulatory assets and regulatory liabilities, including purchase gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of March 31, 2015 and September 30, 2014.

	Laclede Group				Laclede Gas				Alagasco
	March 31,		September 30,		March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014		2015		2014
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	21.4	$	21.4	$	15.0	$	15.0	$	6.4	$	6.4
Unamortized purchased gas adjustments	—		54.0		—		54.0		—		—
Other	6.0		5.4		2.4		3.0		3.6		2.4
Total Regulatory Assets (current)	27.4		80.8		17.4		72.0		10.0		8.8
Non-current:
Future income taxes due from customers	125.6		117.0		125.6		117.0		—		—
Pension and postretirement benefit costs	420.8		431.5		357.9		365.4		62.9		66.1
Accretion and depreciation of asset retirement obligations	19.1		18.4		—		—		19.1		18.4
Purchased gas costs	18.6		4.3		18.6		4.3		—		—
Energy efficiency	20.4		18.9		20.4		18.9		—		—
Other	28.4		24.2		22.8		18.1		5.6		6.1
Total Regulatory Assets (non-current)	632.9		614.3		545.3		523.7		87.6		90.6
Total Regulatory Assets	$	660.3	$	695.1	$	562.7	$	595.7	$	97.6	$	99.4
Regulatory Liabilities:
Current:
RSE adjustment	$	9.9	$	19.8	$	—	$	—	$	9.9	$	19.8
Unbilled service margin	15.0		5.2		—		—		15.0		5.2
Refundable negative salvage	10.8		13.4		—		—		10.8		13.4
Unamortized purchased gas adjustments	76.7		22.4		39.1		—		37.6		22.4
Other	2.8		2.9		0.6		0.6		2.2		2.3
Total Regulatory Liabilities (current)	115.2		63.7		39.7		0.6		75.5		63.1
Non-current:
Postretirement liabilities	25.1		26.2		—		—		25.1		26.2
Refundable negative salvage	17.0		26.8		—		—		17.0		26.8
Accrued cost of removal	59.9		60.5		59.9		60.5		—		—
Other	12.3		12.3		11.8		11.6		0.7		0.7
Total Regulatory Liabilities (non-current)	114.3		125.8		71.7		72.1		42.8		53.7
Total Regulatory Liabilities	$	229.5	$	189.5	$	111.4	$	72.7	$	118.3	$	116.8

A portion of the Company's and Laclede Gas' regulatory assets are not earning a return, as shown in the schedule below:

	Laclede Group				Laclede Gas
	March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014
Regulatory Assets Not Earning a Return:
Future income taxes due from customers	$	125.6	$	117.0	$	125.6	$	117.0
Pension and postretirement benefit costs	232.3		240.9		232.3		240.9
Other	15.2		16.0		15.2		16.0
Total Regulatory Assets Not Earning a Return	$	373.1	$	373.9	$	373.1	$	373.9

Like all the Company's regulatory assets, these regulatory assets are expected to be recovered from customers in future rates. The Company and Laclede Gas expect these items to be recovered over a period not to exceed 15 years consistent with precedent set by the Missouri Public Service Commission (MoPSC). The portion of regulatory assets related to pensions and other postemployment benefits that pertains to unfunded differences between the projected benefit obligation and plan assets also does not earn a rate of return. Alagasco does not have any regulatory assets that are not earning a return.

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Mar. 31, 2015

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value Measurements, Measured on Recurring Basis

The following tables for Laclede Group, Laclede Gas, and Alagasco categorize the assets and liabilities in the balance sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.

The mutual funds included in Level 1 are valued based on exchange-quoted market prices of individual securities. The mutual funds included in Level 2 are valued based on the closing net asset value per unit.

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 Over-the-Counter Bulletin Board (OTCBB), 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. The Alagasco interest rate swaps fall into this latter Level 2 classification. 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 Level 3 balances as of March 31, 2015 and September 30, 2014 consisted of gas commodity contracts. The Company’s and the Utilities' 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 mutual funds are included in the "Other investments" line of the balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exists between the Company or Laclede Gas and the counterparty to a derivative contract.

Laclede Group

($ Millions)	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, 2015
ASSETS
Gas Utility
U. S. stock/bond mutual funds	$	16.4	$	3.9	$	—	$	—		$	20.3
NYMEX natural gas contracts	0.6		—		—		(0.6		)	—
Subtotal	17.0		3.9		—		(0.6		)	20.3
Gas Marketing
NYMEX natural gas contracts	3.4		1.7		—		(4.3		)	0.8
Natural gas commodity contracts	—		2.7		0.5		(0.5		)	2.7
Total	$	20.4	$	8.3	$	0.5	$	(5.4	)	$	23.8
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	14.1	$	—	$	—	$	(14.1	)	$	—
OTCBB natural gas contracts	—		14.5		—		—			14.5
NYMEX gasoline and heating oil contracts	1.0		—		—		(1.0		)	—
Interest rate swaps	—		2.9		—		—			2.9
Subtotal	15.1		17.4		—		(15.1		)	17.4
Gas Marketing
NYMEX natural gas contracts	1.9		3.5		—		(5.4		)	—
Natural gas commodity contracts	—		0.8		—		(0.5		)	0.3
Total	$	17.0	$	21.7	$	—	$	(21.0	)	$	17.7
As of September 30, 2014
ASSETS
Gas Utility
U. S. stock/bond mutual funds	$	15.7	$	3.9	$	—	$	—		$	19.6
NYMEX natural gas contracts	2.4		—		—		(2.4		)	—
OTCBB natural gas contracts	—		0.1		—		(0.1		)	—
Subtotal	18.1		4.0		—		(2.5		)	19.6
Gas Marketing
NYMEX natural gas contracts	1.0		1.2		—		(1.8		)	0.4
Natural gas commodity contracts	—		2.7		0.2		(0.2		)	2.7
Total	$	19.1	$	7.9	$	0.2	$	(4.5	)	$	22.7
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	5.2	$	—	$	—	$	(5.2	)	$	—
OTCBB natural gas contracts	—		4.1		—		(0.1		)	4.0
Gasoline and heating oil contracts	0.2		—		—		(0.2		)	—
Subtotal	5.4		4.1		—		(5.5		)	4.0
Gas Marketing
NYMEX natural gas contracts	1.1		0.7		—		(1.8		)	—
Natural gas commodity contracts	—		0.7		—		(0.2		)	0.5
Total	$	6.5	$	5.5	$	—	$	(7.5	)	$	4.5

Laclede Gas

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value Measurements, Measured on Recurring Basis

($ Millions)	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, 2015
ASSETS
U. S. stock/bond mutual funds	$	16.4	$	3.9	$	—	$	—		$	20.3
NYMEX natural gas contracts	0.6		—		—		(0.6		)	—
Total	17.0		3.9		—		(0.6		)	20.3
LIABILITIES
NYMEX natural gas contracts	14.1		—		—		(14.1		)	—
OTCBB natural gas contracts	—		14.5		—		—			14.5
Gasoline and heating oil contracts	1.0		—		—		(1.0		)	—
Total	$	15.1	$	14.5	$	—	$	(15.1	)	$	14.5
As of September 30, 2014
ASSETS
U. S. stock/bond mutual funds	$	15.7	$	3.9	$	—	$	—		$	19.6
NYMEX natural gas contracts	2.4		—		—		(2.4		)	—
OTCBB natural gas contracts	—		0.1		—		(0.1		)	—
Total	18.1		4.0		—		(2.5		)	19.6
LIABILITIES
NYMEX/ICE natural gas contracts	5.2		—		—		(5.2		)	—
OTCBB natural gas contracts	—		4.1		—		(0.1		)	4.0
NYMEX gasoline and heating oil contracts	0.2		—		—		(0.2		)	—
Total	$	5.4	$	4.1	$	—	$	(5.5	)	$	4.0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

6 Months Ended

Mar. 31, 2015

Accounting Policies [Abstract]

Schedule of gross receipts taxes

The following table presents gross receipts taxes recorded:

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Laclede Group	$	44.7	$	34.3	$	72.4	$	54.3
Laclede Gas	33.9		34.3		55.8		54.3
Alagasco	10.8		13.0		16.6		19.4

Schedule of inter-company transactions

Laclede Gas had the following transactions with affiliates:

	Three Months Ended   March 31,				Six Months Ended   March 31,
($ Millions)	2015		2014		2015		2014
Sales of natural gas from Laclede Gas to LER	$	1.9	$	4.2	$	2.9	$	4.3
Sales of natural gas from LER to Laclede Gas	16.0		25.0		41.3		44.5
Transportation services provided by Laclede Pipeline Company to Laclede Gas	0.2		0.2		0.5		0.5

Schedule of goodwill

The following table represents total goodwill of Laclede Group and Laclede Gas, by acquisition, all included in the Gas Utility segment:

	Laclede Group				Laclede Gas
($ Millions)	March 31, 2015		September 30, 2014		March 31, 2015		September 30, 2014
Acquisition of MGE	$	210.2	$	210.2	$	210.2	$	210.2
Acquisition of Alagasco	735.8		727.6		—		—
Total	$	946.0	$	937.8	$	210.2	$	210.2

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

6 Months Ended

Mar. 31, 2015

Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

This footnote includes all pension plans of the Company whether historical plans or those acquired as part of the purchase of certain assets and liabilities of MGE on September 1, 2013 or those acquired in the Alagasco Transaction effective August 31, 2014. The net pension and postretirement obligations were re-measured at the applicable acquisition dates as well as at the fiscal year end.

Pension Plans

The pension plans of Laclede Group consist of plans for employees at the Missouri Utilities and plans covering employees of Alagasco.

The Missouri Utilities have non-contributory, defined benefit, trusteed forms of pension plans covering the majority of their employees. Plan assets consist primarily of corporate and US government obligations and a growth segment consisting of exposure to equity markets, commodities, real estate and inflation-indexed securities, achieved through derivative instruments and investments in diversified mutual funds.

Alagasco has non-contributory, defined benefit, trusteed forms of pension plans covering the majority of its employees. Qualified plan assets are comprised of United States equities consisting of mutual and commingled funds with varying strategies, global equities consisting of mutual funds, alternative investments of limited partnerships and commingled and mutual funds, and fixed income investments.

The net periodic pension cost included the following components:

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Laclede Group
Service cost – benefits earned during the period	$	4.3		$	2.5		$	8.6		$	4.9
Interest cost on projected benefit obligation	7.4			6.0			14.9			12.0
Expected return on plan assets	(9.3		)	(6.7		)	(18.7		)	(13.3		)
Amortization of prior service cost	0.1			0.1			0.2			0.2
Amortization of actuarial loss	2.0			1.7			3.9			3.5
Loss on lump-sum settlements	—			1.3			—			1.3
Sub-total	4.5			4.9			8.9			8.6
Regulatory adjustment	4.8			1.6			9.7			4.5
Net pension cost	$	9.3		$	6.5		$	18.6		$	13.1

Laclede Gas
Service cost – benefits earned during the period	$	2.9		$	2.5		$	5.7		$	4.9
Interest cost on projected benefit obligation	5.9			6.0			11.8			12.0
Expected return on plan assets	(7.3		)	(6.7		)	(14.6		)	(13.3		)
Amortization of prior service cost	0.1			0.1			0.2			0.2
Amortization of actuarial loss	2.0			1.7			3.9			3.5
Loss on lump-sum settlements	—			1.3			—			1.3
Sub-total	3.6			4.9			7.0			8.6
Regulatory adjustment	3.4			1.6			6.8			4.5
Net pension cost	$	7.0		$	6.5		$	13.8		$	13.1

Alagasco
Service cost – benefits earned during the period	$	1.4		$	1.5		$	2.9		$	3.6
Interest cost on projected benefit obligation	1.5			1.2			3.1			2.9
Expected return on plan assets	(2.0		)	(1.5		)	(4.1		)	(3.7		)
Amortization of prior service cost	—			0.1			—			0.1
Amortization of actuarial loss	—			0.7			—			2.0
Loss on lump-sum settlements	—			10.1			—			10.9
Sub-total	0.9			12.1			1.9			15.8
Regulatory adjustment	1.4			(9.8		)	2.9			(10.6		)
Net pension cost	$	2.3		$	2.3		$	4.8		$	5.2

Pursuant to the provisions of the Missouri Utilities' and Alagasco's pension plans, pension obligations may be satisfied by lump-sum cash payments. Pursuant to a MoPSC 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 in a specific year. Lump-sum payments during the six months ended March 31, 2015 were $12.7 for the Missouri Utilities and $2.6 for Alagasco.

The funding policy of the Utilities 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 2015 contributions to Laclede Gas' pension plans through March 31, 2015 were $9.1 to the qualified trusts and $0.2 to the non-qualified plans. There were no fiscal 2015 contributions to the Alagasco pension plans through March 31, 2015.

Contributions to the Missouri Utilities' pension plans for the remaining six months of fiscal 2015 are anticipated to be approximately $17.3 to the qualified trusts and $0.3 to the non-qualified plans. There are no expected contributions to Alagasco's pension plans for the remaining six months of fiscal 2015.

Postretirement Benefits

The Utilities provide certain life insurance benefits at retirement. Laclede Gas plans provide for medical insurance after early retirement until age 65. For retirements prior to January 1, 2015, the MGE plans provided medical insurance after retirement until death. For retirements after January 1, 2015, the MGE plans provide medical insurance after early retirement until age 65. The transition obligation not yet included in postretirement benefit cost is being amortized over 20 years. Under the Alagasco plans, medical insurance is currently available upon retirement until death for certain retirees depending on the type of employee and the date the employee was originally hired.

Net periodic postretirement benefit cost for the Company consisted of the following components:

	Three Months Ended   March 31,						Six Months Ended   March 31,
($ Millions)	2015			2014			2015			2014
Laclede Group
Service cost – benefits earned during the period	$	3.2		$	2.8		$	6.4		$	5.6
Interest cost on accumulated postretirement benefit obligation	2.8			2.2			5.6			4.4
Expected return on plan assets	(3.3		)	(1.7		)	(6.6		)	(3.4		)
Amortization of prior service credit	0.2			—			0.4			—
Amortization of actuarial loss	1.2			1.5			2.5			3.0
Sub-total	4.1			4.8			8.3			9.6
Regulatory adjustment	(2.7		)	(2.4		)	(5.4		)	(4.8		)
Net postretirement benefit cost	$	1.4		$	2.4		$	2.9		$	4.8

Laclede Gas
Service cost – benefits earned during the period	$	3.1		$	2.8		$	6.2		$	5.6
Interest cost on accumulated postretirement benefit obligation	2.2			2.2			4.3			4.4
Expected return on plan assets	(2.1		)	(1.7		)	(4.1		)	(3.4		)
Amortization of prior service cost	0.2			—			0.4			—
Amortization of actuarial loss	1.2			1.5			2.5			3.0
Sub-total	4.6			4.8			9.3			9.6
Regulatory adjustment	(2.3		)	(2.4		)	(4.6		)	(4.8		)
Net postretirement benefit cost	$	2.3		$	2.4		$	4.7		$	4.8

Alagasco
Service cost – benefits earned during the period	$	0.1		$	0.1		$	0.2		$	0.4
Interest cost on accumulated postretirement benefit obligation	0.6			0.5			1.3			1.2
Expected return on plan assets	(1.2		)	(1.1		)	(2.5		)	(2.1		)
Amortization of actuarial loss and other	—			(0.4		)	—			(0.5		)
Amortization of transition obligation	—			0.1			—			0.3
Sub-total	(0.5		)	(0.8		)	(1.0		)	(0.7		)
Regulatory adjustment	(0.4		)	—			(0.8		)	—
Net postretirement benefit cost	$	(0.9	)	$	(0.8	)	$	(1.8	)	$	(0.7	)

Missouri and Alabama 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. The Missouri Utilities established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi Trusts as its external funding mechanisms. The assets of the VEBA and Rabbi Trusts consist primarily of money market securities and mutual funds invested in stocks and bonds.

The Utilities' 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 2015 contributions to the postretirement plans through March 31, 2015 were $4.4 for the Missouri Utilities. Contributions to the postretirement plans for the remaining six months of fiscal year 2015 are anticipated to be $13.6 to the qualified trusts and $0.3 paid directly to participants from the Missouri Utilities' funds. For Alagasco, there were no contributions to the postretirement plans during the first six months of fiscal year 2015, and there are none expected for the remaining six months.

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FAIR VALUE MEASUREMENTS

6 Months Ended

Mar. 31, 2015

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

The following tables for Laclede Group, Laclede Gas, and Alagasco categorize the assets and liabilities in the balance sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.

The mutual funds included in Level 1 are valued based on exchange-quoted market prices of individual securities. The mutual funds included in Level 2 are valued based on the closing net asset value per unit.

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 Over-the-Counter Bulletin Board (OTCBB), 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. The Alagasco interest rate swaps fall into this latter Level 2 classification. 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 Level 3 balances as of March 31, 2015 and September 30, 2014 consisted of gas commodity contracts. The Company’s and the Utilities' 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 mutual funds are included in the "Other investments" line of the balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exists between the Company or Laclede Gas and the counterparty to a derivative contract.

Laclede Group

($ Millions)	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, 2015
ASSETS
Gas Utility
U. S. stock/bond mutual funds	$	16.4	$	3.9	$	—	$	—		$	20.3
NYMEX natural gas contracts	0.6		—		—		(0.6		)	—
Subtotal	17.0		3.9		—		(0.6		)	20.3
Gas Marketing
NYMEX natural gas contracts	3.4		1.7		—		(4.3		)	0.8
Natural gas commodity contracts	—		2.7		0.5		(0.5		)	2.7
Total	$	20.4	$	8.3	$	0.5	$	(5.4	)	$	23.8
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	14.1	$	—	$	—	$	(14.1	)	$	—
OTCBB natural gas contracts	—		14.5		—		—			14.5
NYMEX gasoline and heating oil contracts	1.0		—		—		(1.0		)	—
Interest rate swaps	—		2.9		—		—			2.9
Subtotal	15.1		17.4		—		(15.1		)	17.4
Gas Marketing
NYMEX natural gas contracts	1.9		3.5		—		(5.4		)	—
Natural gas commodity contracts	—		0.8		—		(0.5		)	0.3
Total	$	17.0	$	21.7	$	—	$	(21.0	)	$	17.7
As of September 30, 2014
ASSETS
Gas Utility
U. S. stock/bond mutual funds	$	15.7	$	3.9	$	—	$	—		$	19.6
NYMEX natural gas contracts	2.4		—		—		(2.4		)	—
OTCBB natural gas contracts	—		0.1		—		(0.1		)	—
Subtotal	18.1		4.0		—		(2.5		)	19.6
Gas Marketing
NYMEX natural gas contracts	1.0		1.2		—		(1.8		)	0.4
Natural gas commodity contracts	—		2.7		0.2		(0.2		)	2.7
Total	$	19.1	$	7.9	$	0.2	$	(4.5	)	$	22.7
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	5.2	$	—	$	—	$	(5.2	)	$	—
OTCBB natural gas contracts	—		4.1		—		(0.1		)	4.0
Gasoline and heating oil contracts	0.2		—		—		(0.2		)	—
Subtotal	5.4		4.1		—		(5.5		)	4.0
Gas Marketing
NYMEX natural gas contracts	1.1		0.7		—		(1.8		)	—
Natural gas commodity contracts	—		0.7		—		(0.2		)	0.5
Total	$	6.5	$	5.5	$	—	$	(7.5	)	$	4.5

Laclede Gas

($ Millions)	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, 2015
ASSETS
U. S. stock/bond mutual funds	$	16.4	$	3.9	$	—	$	—		$	20.3
NYMEX natural gas contracts	0.6		—		—		(0.6		)	—
Total	17.0		3.9		—		(0.6		)	20.3
LIABILITIES
NYMEX natural gas contracts	14.1		—		—		(14.1		)	—
OTCBB natural gas contracts	—		14.5		—		—			14.5
Gasoline and heating oil contracts	1.0		—		—		(1.0		)	—
Total	$	15.1	$	14.5	$	—	$	(15.1	)	$	14.5
As of September 30, 2014
ASSETS
U. S. stock/bond mutual funds	$	15.7	$	3.9	$	—	$	—		$	19.6
NYMEX natural gas contracts	2.4		—		—		(2.4		)	—
OTCBB natural gas contracts	—		0.1		—		(0.1		)	—
Total	18.1		4.0		—		(2.5		)	19.6
LIABILITIES
NYMEX/ICE natural gas contracts	5.2		—		—		(5.2		)	—
OTCBB natural gas contracts	—		4.1		—		(0.1		)	4.0
NYMEX gasoline and heating oil contracts	0.2		—		—		(0.2		)	—
Total	$	5.4	$	4.1	$	—	$	(5.5	)	$	4.0

Alagasco

($ Millions)	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, 2015
LIABILITIES
Interest rate swaps	$	—	$	2.9	$	—	$	—	$	2.9
Total	$	—	$	2.9	$	—	$	—	$	2.9
As of September 30, 2014
LIABILITIES
Interest rate swaps	$	—	$	—	$	—	$	—	$	—
Total	$	—	$	—	$	—	$	—	$	—

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CONCENTRATIONS OF CREDIT RISK

6 Months Ended

Mar. 31, 2015

Risks and Uncertainties [Abstract]

CONCENTRATION OF CREDIT RISK

CONCENTRATIONS OF CREDIT RISK

Other than in LER (the Gas Marketing segment), Laclede Group has no significant concentrations of credit risk.

A significant portion of LER’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. The concentration of transactions with these counterparties has 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. LER records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in LER's accounts receivable attributable to energy producers and their marketing affiliates totaled $7.5 at March 31, 2015. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $5.7. LER's accounts receivable attributable to utility companies and their marketing affiliates comprised $15.6 of total accounts receivable at March 31, 2015, while net receivable amounts from these customers, reflecting netting arrangements, were $14.1.

LER also has concentrations of credit risk with certain individually significant counterparties and with pipeline companies associated with its natural gas receivable amounts. At March 31, 2015, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure) totaled $9.8. These five counterparties are either investment-grade rated or owned by investment-grade rated companies. Net receivable amounts from these five customers on the same date, reflecting netting arrangements, were $9.3.

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INFORMATION BY OPERATING SEGMENT

6 Months Ended

Mar. 31, 2015

Segment Reporting [Abstract]

INFORMATION BY OPERATING SEGMENT

INFORMATION BY OPERATING SEGMENT

The Company has two key operating segments: Gas Utility and Gas Marketing. The Gas Utility segment comprises the regulated operations of the Utilities, consisting of Laclede Gas and Alagasco. Laclede Gas and Alagasco are public utilities engaged in the retail distribution and sale of natural gas serving an area in eastern Missouri through its legacy Laclede Gas assets, an area in western Missouri through its MGE assets, and central and northern Alabama through its Alagasco assets. The Gas Marketing segment includes the results of LER, a subsidiary engaged in the non-regulated marketing of natural gas and related activities, and LER Storage Services, Inc., which utilizes natural gas storage contracts for providing natural gas sales. Other includes:

• unallocated corporate items, including certain debt and associated interest costs,

• Laclede Pipeline Company, a subsidiary of Laclede Group which operates a propane pipeline under Federal Energy Regulatory Commission (FERC) jurisdiction, and

• Laclede Group’s subsidiaries that are engaged in, among other activities, oil production, real estate development, compression of natural gas, and financial investments in other enterprises. All subsidiaries are wholly owned.

Accounting policies and intersegment transactions are described in Note 1, Summary of Significant Accounting Policies.

($ Millions)	Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Three Months Ended March 31, 2015
Operating Revenues:
Revenues from external customers	$	847.0	$	30.0	$	0.4		$	—		$	877.4
Intersegment revenues	2.0		14.1		0.5			(16.6		)	—
Total Operating Revenues	849.0		44.1		0.9			(16.6		)	877.4
Operating Expenses:
Gas Utility
Natural and propane gas	499.1		—		—			(16.3		)	482.8
Other operation and maintenance	104.0		—		—			(0.2		)	103.8
Depreciation and amortization	32.2		—		—			—			32.2
Taxes, other than income taxes	55.7		—		—			—			55.7
Total Gas Utility Operating Expenses	691.0		—		—			(16.5		)	674.5
Gas Marketing	—		43.5		—			—			43.5
Other	—		—		1.8			(0.1		)	1.7
Total Operating Expenses	691.0		43.5		1.8			(16.6		)	719.7
Operating Income (Loss)	$	158.0	$	0.6	$	(0.9	)	$	—		$	157.7
Net Economic Earnings (Loss)	$	96.5	$	2.1	$	(1.0	)	$	—		$	97.6
Three Months Ended March 31, 2014
Operating Revenues:
Revenues from external customers	$	634.4	$	59.9	$	0.2		$	—		$	694.5
Intersegment revenues	4.2		20.6		0.6			(25.4		)	—
Total Operating Revenues	638.6		80.5		0.8			(25.4		)	694.5
Operating Expenses:
Gas Utility
Natural and propane gas	430.5		—		—			(25.2		)	405.3
Other operation and maintenance	72.2		—		—			(0.2		)	72.0
Depreciation and amortization	20.1		—		—			—			20.1
Taxes, other than income taxes	41.8		—		—			—			41.8
Total Gas Utility Operating Expenses	564.6		—		—			(25.4		)	539.2
Gas Marketing	—		65.0		—			—			65.0
Other	—		—		3.1			—			3.1
Total Operating Expenses	564.6		65.0		3.1			(25.4		)	607.3
Operating Income (Loss)	$	74.0	$	15.5	$	(2.3	)	$	—		$	87.2
Net Economic Earnings (Loss)	$	44.7	$	7.1	$	(0.1	)	$	—		$	51.7

($ Millions)	Gas Utility		Gas Marketing		Other			Eliminations			Consolidated
Six Months Ended March 31, 2015
Operating Revenues:
Revenues from external customers	$	1,428.4	$	67.8	$	0.8		$	—		$	1,497.0
Intersegment revenues	3.0		38.5		1.0			(42.5		)	—
Total Operating Revenues	1,431.4		106.3		1.8			(42.5		)	1,497.0
Operating Expenses:
Gas Utility
Natural and propane gas	828.9		—		—			(41.8		)	787.1
Other operation and maintenance	201.4		—		—			(0.5		)	200.9
Depreciation and amortization	64.2		—		—			—			64.2
Taxes, other than income taxes	93.7		—		—			—			93.7
Total Gas Utility Operating Expenses	1,188.2		—		—			(42.3		)	1,145.9
Gas Marketing	—		102.1		—			—			102.1
Other	—		—		4.2			(0.2		)	4.0
Total Operating Expenses	1,188.2		102.1		4.2			(42.5		)	1,252.0
Operating Income (Loss)	$	243.2	$	4.2	$	(2.4	)	$	—		$	245.0
Net Economic Earnings (Loss)	$	146.3	$	2.5	$	(5.5	)	$	—		$	143.3
Six Months Ended March 31, 2014
Operating Revenues:
Revenues from external customers	$	1,069.6	$	93.1	$	0.4		$	—		$	1,163.1
Intersegment revenues	4.3		40.1		1.0			(45.4		)	—
Total Operating Revenues	1,073.9		133.2		1.4			(45.4		)	1,163.1
Operating Expenses:
Gas Utility
Natural and propane gas	692.1		—		—			(45.0		)	647.1
Other operation and maintenance	134.7		—		—			(0.4		)	134.3
Depreciation and amortization	40.1		—		—			—			40.1
Taxes, other than income taxes	70.4		—		—			—			70.4
Total Gas Utility Operating Expenses	937.3		—		—			(45.4		)	891.9
Gas Marketing	—		116.8		—			—			116.8
Other	—		—		4.3			—			4.3
Total Operating Expenses	937.3		116.8		4.3			(45.4		)	1,013.0
Operating Income (Loss)	$	136.6	$	16.4	$	(2.9	)	$	—		$	150.1
Net Economic Earnings (Loss)	$	80.5	$	7.9	$	(0.4	)	$	—		$	88.0

The Company's total assets by segment were as follows:

	March 31,			September 30,
($ Millions)	2015			2014
Total Assets:
Gas Utility	$	4,615.6		$	4,520.0
Gas Marketing	131.7			156.7
Other	1,590.8			1,575.7
Eliminations	(1,157.4		)	(1,178.4		)
Total Assets	$	5,180.7		$	5,074.0

The following table reconciles the Company's Net Income (GAAP) to Net Economic Earnings (Non-GAAP):

	Three Months Ended March 31,						Six Months Ended March 31,
($ Millions)	2015			2014			2015			2014
Net income (GAAP)	$	94.4		$	52.2		$	141.5		$	87.8
Unrealized loss (gain) on energy-related derivative contracts	2.6			(1.7		)	(0.4		)	(1.3		)
Lower of cost or market inventory adjustments	(1.0		)	(0.5		)	0.2			(0.6		)
Realized loss (gain) on economic hedges prior to sale of the physical commodity	0.1			(0.1		)	0.1			(0.1		)
Acquisition, divestiture and restructuring activities	1.5			1.8			1.9			2.2
Net Economic Earnings (Non-GAAP)	$	97.6		$	51.7		$	143.3		$	88.0

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REGULATORY MATTERS (Details)	6 Months Ended
	Mar. 31, 2015
Regulated Operations [Abstract]
Remaining recovery period for regulatory assets for which no return on investment during recovery period is provided	15 years

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REGULATORY MATTERS (Tables)

6 Months Ended

Mar. 31, 2015

Regulated Operations [Abstract]

Schedule of regulatory assets

The following regulatory assets and regulatory liabilities, including purchase gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of March 31, 2015 and September 30, 2014.

	Laclede Group				Laclede Gas				Alagasco
	March 31,		September 30,		March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014		2015		2014
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	21.4	$	21.4	$	15.0	$	15.0	$	6.4	$	6.4
Unamortized purchased gas adjustments	—		54.0		—		54.0		—		—
Other	6.0		5.4		2.4		3.0		3.6		2.4
Total Regulatory Assets (current)	27.4		80.8		17.4		72.0		10.0		8.8
Non-current:
Future income taxes due from customers	125.6		117.0		125.6		117.0		—		—
Pension and postretirement benefit costs	420.8		431.5		357.9		365.4		62.9		66.1
Accretion and depreciation of asset retirement obligations	19.1		18.4		—		—		19.1		18.4
Purchased gas costs	18.6		4.3		18.6		4.3		—		—
Energy efficiency	20.4		18.9		20.4		18.9		—		—
Other	28.4		24.2		22.8		18.1		5.6		6.1
Total Regulatory Assets (non-current)	632.9		614.3		545.3		523.7		87.6		90.6
Total Regulatory Assets	$	660.3	$	695.1	$	562.7	$	595.7	$	97.6	$	99.4
Regulatory Liabilities:
Current:
RSE adjustment	$	9.9	$	19.8	$	—	$	—	$	9.9	$	19.8
Unbilled service margin	15.0		5.2		—		—		15.0		5.2
Refundable negative salvage	10.8		13.4		—		—		10.8		13.4
Unamortized purchased gas adjustments	76.7		22.4		39.1		—		37.6		22.4
Other	2.8		2.9		0.6		0.6		2.2		2.3
Total Regulatory Liabilities (current)	115.2		63.7		39.7		0.6		75.5		63.1
Non-current:
Postretirement liabilities	25.1		26.2		—		—		25.1		26.2
Refundable negative salvage	17.0		26.8		—		—		17.0		26.8
Accrued cost of removal	59.9		60.5		59.9		60.5		—		—
Other	12.3		12.3		11.8		11.6		0.7		0.7
Total Regulatory Liabilities (non-current)	114.3		125.8		71.7		72.1		42.8		53.7
Total Regulatory Liabilities	$	229.5	$	189.5	$	111.4	$	72.7	$	118.3	$	116.8

A portion of the Company's and Laclede Gas' regulatory assets are not earning a return, as shown in the schedule below:

	Laclede Group				Laclede Gas
	March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014
Regulatory Assets Not Earning a Return:
Future income taxes due from customers	$	125.6	$	117.0	$	125.6	$	117.0
Pension and postretirement benefit costs	232.3		240.9		232.3		240.9
Other	15.2		16.0		15.2		16.0
Total Regulatory Assets Not Earning a Return	$	373.1	$	373.9	$	373.1	$	373.9

Schedule of regulatory liabilities

The following regulatory assets and regulatory liabilities, including purchase gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of March 31, 2015 and September 30, 2014.

	Laclede Group				Laclede Gas				Alagasco
	March 31,		September 30,		March 31,		September 30,		March 31,		September 30,
($ Millions)	2015		2014		2015		2014		2015		2014
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	21.4	$	21.4	$	15.0	$	15.0	$	6.4	$	6.4
Unamortized purchased gas adjustments	—		54.0		—		54.0		—		—
Other	6.0		5.4		2.4		3.0		3.6		2.4
Total Regulatory Assets (current)	27.4		80.8		17.4		72.0		10.0		8.8
Non-current:
Future income taxes due from customers	125.6		117.0		125.6		117.0		—		—
Pension and postretirement benefit costs	420.8		431.5		357.9		365.4		62.9		66.1
Accretion and depreciation of asset retirement obligations	19.1		18.4		—		—		19.1		18.4
Purchased gas costs	18.6		4.3		18.6		4.3		—		—
Energy efficiency	20.4		18.9		20.4		18.9		—		—
Other	28.4		24.2		22.8		18.1		5.6		6.1
Total Regulatory Assets (non-current)	632.9		614.3		545.3		523.7		87.6		90.6
Total Regulatory Assets	$	660.3	$	695.1	$	562.7	$	595.7	$	97.6	$	99.4
Regulatory Liabilities:
Current:
RSE adjustment	$	9.9	$	19.8	$	—	$	—	$	9.9	$	19.8
Unbilled service margin	15.0		5.2		—		—		15.0		5.2
Refundable negative salvage	10.8		13.4		—		—		10.8		13.4
Unamortized purchased gas adjustments	76.7		22.4		39.1		—		37.6		22.4
Other	2.8		2.9		0.6		0.6		2.2		2.3
Total Regulatory Liabilities (current)	115.2		63.7		39.7		0.6		75.5		63.1
Non-current:
Postretirement liabilities	25.1		26.2		—		—		25.1		26.2
Refundable negative salvage	17.0		26.8		—		—		17.0		26.8
Accrued cost of removal	59.9		60.5		59.9		60.5		—		—
Other	12.3		12.3		11.8		11.6		0.7		0.7
Total Regulatory Liabilities (non-current)	114.3		125.8		71.7		72.1		42.8		53.7
Total Regulatory Liabilities	$	229.5	$	189.5	$	111.4	$	72.7	$	118.3	$	116.8

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended	12 Months Ended	0 Months Ended	3 Months Ended
	Mar. 31, 2015 Operating_Segment	Sep. 30, 2014	Jan. 06, 2015	Mar. 31, 2015	Mar. 31, 2014	Sep. 30, 2013	Dec. 31, 2014
Related Party Transaction [Line Items]
Number of operating segments	2
Goodwill	$ 946.0	$ 937.8		$ 946.0
Stockholders' Equity	1,611.6	1,508.4		1,611.6	1,106.6	1,046.3
Laclede Gas
Related Party Transaction [Line Items]
Accrued unbilled revenues	63.5	29.4		63.5
Goodwill	210.2	210.2		210.2
Accruals for capital expenditures	4.2	3.0
Stockholders' Equity	1,058.6	1,007.8		1,058.6	1,027.6	973.9
Alagasco
Related Party Transaction [Line Items]
Accrued unbilled revenues	15.0	5.2		15.0
Accruals for capital expenditures	4.7	5.0
Stockholders' Equity	908.9	849.6		908.9	416.8	364.7
Missouri Gas Energy (MGE)
Related Party Transaction [Line Items]
Goodwill	210.2	210.2		210.2
Missouri Gas Energy (MGE) | Laclede Gas
Related Party Transaction [Line Items]
Goodwill	210.2	210.2		210.2
Alagasco
Related Party Transaction [Line Items]
Goodwill	735.8	727.6		735.8			727.6
Final reconciliation of net assets payments to acquire businesses			8.6	8.6
Alagasco | Laclede Gas
Related Party Transaction [Line Items]
Goodwill	0	0		0
Common Stock Issued
Related Party Transaction [Line Items]
Stockholders' Equity	43.3	43.2		43.3	32.8	32.7
Common Stock Issued | Laclede Gas
Related Party Transaction [Line Items]
Stockholders' Equity	0.1	0.1		0.1	0.1	0.1
Common Stock Issued | Alagasco
Related Party Transaction [Line Items]
Stockholders' Equity	0	0		0	0	0
Common Stock Issued | Restatement Adjustment | Alagasco
Related Party Transaction [Line Items]
Stockholders' Equity	31.7			31.7
Paid-in Capital
Related Party Transaction [Line Items]
Stockholders' Equity	1,033.3	1,029.4		1,033.3	597.4	594.3
Paid-in Capital | Laclede Gas
Related Party Transaction [Line Items]
Stockholders' Equity	746.2	744.0		746.2	741.0	738.1
Paid-in Capital | Alagasco
Related Party Transaction [Line Items]
Stockholders' Equity	506.3	503.9		506.3	34.5	34.5
Paid-in Capital | Restatement Adjustment | Alagasco
Related Party Transaction [Line Items]
Stockholders' Equity	$ 31.7			$ 31.7

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INFORMATION BY OPERATING SEGMENT - Reconciliation of Consolidated Net Income to Consolidated Net Economic Earnings (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Segment Reporting [Abstract]
Net Income	$ 94.4	$ 52.2	$ 141.5	$ 87.8
Unrealized loss (gain) on energy-related derivative contracts	2.6	(1.7)	(0.4)	(1.3)
Lower of cost or market inventory adjustments	(1.0)	(0.5)	0.2	(0.6)
Realized loss (gain) on economic hedges prior to sale of the physical commodity	0.1	(0.1)	0.1	(0.1)
Acquisition, divestiture and restructuring activities	1.5	1.8	1.9	2.2
Net Economic Earnings (Non-GAAP)	$ 97.6	$ 51.7	$ 143.3	$ 88.0

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Sep. 30, 2014
Assets
Non-utility property (net of accumulated depreciation and amortization)	$ 7.2	$ 6.7
Capitalization:
Common stock, par value (in dollars per share)	$ 1.00	$ 1.00
Common stock, authorized (in shares)	70,000,000	70,000,000
Common stock, issued (in shares)	43,300,000	43,200,000
Common stock, outstanding (in shares)	43,300,000	43,200,000
Laclede Gas
Capitalization:
Common stock, par value (in dollars per share)	$ 1.00	$ 1.00
Common stock, authorized (in shares)	50,000	50,000
Common stock, issued (in shares)	24,577	24,577
Common stock, outstanding (in shares)	24,577	24,577
Alagasco
Capitalization:
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, authorized (in shares)	3,000,000	3,000,000
Common stock, issued (in shares)	2,000,000	2,000,000
Common stock, outstanding (in shares)	2,000,000	2,000,000

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EARNINGS PER COMMON SHARE

6 Months Ended

Mar. 31, 2015

Earnings Per Share [Abstract]

EARNINGS PER COMMON SHARE

EARNINGS PER COMMON SHARE

	Three Months Ended March 31,				Six Months Ended March 31,
(Millions, except per share amounts)	2015		2014		2015		2014
Basic EPS:
Net Income	$	94.4	$	52.2	$	141.5	$	87.8
Less: Income allocated to participating securities	0.3		0.2		0.5		0.3
Net Income Available to Common Shareholders	$	94.1	$	52.0	$	141.0	$	87.5
Weighted Average Shares Outstanding	43.1		32.6		43.1		32.6
Basic Earnings Per Share of Common Stock	$	2.18	$	1.59	$	3.27	$	2.68
Diluted EPS:
Net Income	$	94.4	$	52.2	$	141.5	$	87.8
Less: Income allocated to participating securities	0.3		0.2		0.5		0.3
Net Income Available to Common Shareholders	$	94.1	$	52.0	$	141.0	$	87.5
Weighted Average Shares Outstanding	43.1		32.6		43.1		32.6
Dilutive Effect of Stock Options, Restricted Stock and Restricted Stock Units	0.1		—		0.1		0.1
Weighted Average Diluted Shares	43.2		32.6		43.2		32.7
Diluted Earnings Per Share of Common Stock	$	2.18	$	1.59	$	3.26	$	2.68

There were 0.4 and 0.3 shares of restricted stock and stock units subject to performance or market conditions for the three and six months ended March 31, 2015 and 2014, respectively, excluded from the calculation of diluted EPS. Also, Laclede Group's 2014 2.0% Series Equity Units issued in June 2014 are potentially dilutive securities but were anti-dilutive for the three and six months ended March 31, 2015; accordingly, they were excluded from the calculation of weighted average diluted shares for those periods.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Gross Receipts Taxes (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Schedule of Gross Receipts Taxes [Line Items]
Gross Receipts taxes recorded in regulated gas distribution operating revenues	$ 44.7	$ 34.3	$ 72.4	$ 54.3
Laclede Gas
Schedule of Gross Receipts Taxes [Line Items]
Gross Receipts taxes recorded in regulated gas distribution operating revenues	33.9	34.3	55.8	54.3
Alagasco
Schedule of Gross Receipts Taxes [Line Items]
Gross Receipts taxes recorded in regulated gas distribution operating revenues	$ 10.8	$ 13.0	$ 16.6	$ 19.4

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Narrative (Details) (USD $)	3 Months Ended		6 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2015	Mar. 31, 2014
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Extent of lump-sum payments recognized, percentage			100.00%
Medical insurance available until age is reached after early retirement			65 years
Amortization period for transition obligation excluded from postretirement benefit cost (in years)			20 years
Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Amortization of actuarial loss	$ 2,000,000	$ 1,700,000	$ 3,900,000	$ 3,500,000
Pension Plans | Laclede Gas
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions made by employer			9,100,000
Pension Plans | Missouri Gas Energy (MGE)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Lump-sum payments recognized as settlements			12,700,000
Anticipated contributions to pension plans for qualified trust			17,300,000
Pension Plans | Alagasco
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Lump-sum payments recognized as settlements			2,600,000
Contributions made by employer			0
Anticipated contributions to pension plans for qualified trust			0
Amortization of actuarial loss	0	700,000	0	2,000,000
Nonqualified Pension Plans | Laclede Gas
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions made by employer			200,000
Nonqualified Pension Plans | Missouri Gas Energy (MGE)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Anticipated contributions to pension plans for qualified trust			300,000
Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Anticipated contributions to pension plans for qualified trust			13,600,000
Amortization of actuarial loss	1,200,000	1,500,000	2,500,000	3,000,000
Anticipated payment directly to participants in postretirement plan			300,000
Postretirement Plans | Missouri Gas Energy (MGE)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions made by employer			4,400,000
Postretirement Plans | Alagasco
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Amortization of actuarial loss	$ 0	$ (400,000)	$ 0	$ (500,000)

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EARNINGS PER COMMON SHARE (Tables)

6 Months Ended

Mar. 31, 2015

Earnings Per Share [Abstract]

Earnings Per Common Share

	Three Months Ended March 31,				Six Months Ended March 31,
(Millions, except per share amounts)	2015		2014		2015		2014
Basic EPS:
Net Income	$	94.4	$	52.2	$	141.5	$	87.8
Less: Income allocated to participating securities	0.3		0.2		0.5		0.3
Net Income Available to Common Shareholders	$	94.1	$	52.0	$	141.0	$	87.5
Weighted Average Shares Outstanding	43.1		32.6		43.1		32.6
Basic Earnings Per Share of Common Stock	$	2.18	$	1.59	$	3.27	$	2.68
Diluted EPS:
Net Income	$	94.4	$	52.2	$	141.5	$	87.8
Less: Income allocated to participating securities	0.3		0.2		0.5		0.3
Net Income Available to Common Shareholders	$	94.1	$	52.0	$	141.0	$	87.5
Weighted Average Shares Outstanding	43.1		32.6		43.1		32.6
Dilutive Effect of Stock Options, Restricted Stock and Restricted Stock Units	0.1		—		0.1		0.1
Weighted Average Diluted Shares	43.2		32.6		43.2		32.7
Diluted Earnings Per Share of Common Stock	$	2.18	$	1.59	$	3.26	$	2.68