Spire Missouri 10-Q 7 Aug 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Jun. 30, 2014	Aug. 04, 2014
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	'	43,167,152
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'
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	'2014	'
Document Fiscal Period Focus	'Q3	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	30-Jun-14	'

STATEMENTS_OF_CONSOLIDATED_INC

STATEMENTS OF CONSOLIDATED INCOME (UNAUDITED) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Operating Revenues:	'	'	'	'
Gas utility	$214	$131.50	$1,283.60	$735.70
Gas marketing and other	27.8	33.8	121.3	134.2
Total Operating Revenues	241.8	165.3	1,404.90	869.9
Gas utility	'	'	'	'
Natural and propane gas	49.3	43.2	696.4	410.2
Other operation and maintenance expenses	73	42.5	207.3	123.3
Depreciation and amortization	18.4	11.5	58.5	33.7
Taxes, other than income taxes	22.2	12.9	92.6	49.5
Total Gas Utility Operating Expenses	162.9	110.1	1,054.80	616.7
Gas marketing and other	54.2	42.9	175.3	147
Other	4.2	2.3	8.5	13
Total Operating Expenses	217.1	153	1,230.10	763.7
Operating Income	24.7	12.3	174.8	106.2
Other Income and (Income Deductions) – Net	-2.4	-0.4	-1	2
Interest Charges:	'	'	'	'
Interest on long-term debt	8.6	6.3	26.9	17.4
Other interest charges	2.8	0.6	4.3	2.2
Total Interest Charges	11.4	6.9	31.2	19.6
Income Before Income Taxes	10.9	5	142.6	88.6
Income Tax (Benefit) Expense	-0.8	-1.6	43.1	26.2
Net Income	11.7	6.6	99.5	62.4
Weighted Average Number of Common Stock Outstanding:	'	'	'	'
Basic	34.9	26.1	33.3	23.6
Diluted	35	26.2	33.4	23.7
Basic Earnings Per Share of Common Stock:	'	'	'	'
Basic Earnings Per Share of Common Stock	$0.34	$0.25	$2.97	$2.62
Diluted Earnings Per Share of Common Stock:	'	'	'	'
Diluted Earnings Per Share of Common Stock	$0.33	$0.25	$2.97	$2.62
Dividends Declared Per Share of Common Stock	$0.44	$0.43	$1.32	$1.27
Laclede Gas Company	'	'	'	'
Operating Revenues:	'	'	'	'
Gas utility	214.2	131.5	1,288.10	746.2
Other	0	0.2	0.1	1.6
Total Operating Revenues	214.2	131.7	1,288.20	747.8
Gas utility	'	'	'	'
Natural and propane gas	77.6	52.8	769.7	435.3
Other operation and maintenance expenses	73.3	42.2	208	123
Depreciation and amortization	18.4	11.5	58.5	33.7
Taxes, other than income taxes	22.2	12.9	92.6	49.5
Total Gas Utility Operating Expenses	191.5	119.4	1,128.80	641.5
Other	0.2	5.1	0.1	6.4
Total Operating Expenses	191.7	124.5	1,128.90	647.9
Operating Income	22.5	7.2	159.3	99.9
Other Income and (Income Deductions) – Net	-2.2	-0.5	-1.2	1.6
Interest Charges:	'	'	'	'
Interest on long-term debt	8.2	6	26.1	16.9
Other interest charges	0.8	-0.1	2.3	0.9
Total Interest Charges	9	5.9	28.4	17.8
Income Before Income Taxes	11.3	0.8	129.7	83.7
Income Tax (Benefit) Expense	-0.7	-3	38.2	24.4
Net Income	$12	$3.80	$91.50	$59.30

STATEMENTS_OF_CONSOLIDATED_COM

STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net Income	$11.70	$6.60	$99.50	$62.40
Net (losses) gains on cash flow hedging derivative instruments:	'	'	'	'
Net hedging (loss) gain arising during the period	-10.4	27.6	-15.5	21.4
Reclassification adjustment for losses included in net income	0.8	1.3	2.8	3.5
Net unrealized (losses) gains on cash flow hedging derivative instruments	-9.6	28.9	-12.7	24.9
Defined benefit pension and other postretirement plans:	'	'	'	'
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	0.1	0.1	0.3	0.3
Other Comprehensive (Loss) Income, Before Tax	-9.5	29	-12.4	25.2
Income Tax (Benefit) Expense Related to Items of Other Comprehensive Income	-3.6	10.8	-4.7	9.4
Other Comprehensive (Loss) Income, Net of Tax	-5.9	18.2	-7.7	15.8
Comprehensive Income	5.8	24.8	91.8	78.2
Laclede Gas Company	'	'	'	'
Net Income	12	3.8	91.5	59.3
Net (losses) gains on cash flow hedging derivative instruments:	'	'	'	'
Net hedging (loss) gain arising during the period	0	-0.1	0.1	0.1
Reclassification adjustment for losses included in net income	0	0	-0.1	-0.1
Net unrealized (losses) gains on cash flow hedging derivative instruments	0	-0.1	0	0
Defined benefit pension and other postretirement plans:	'	'	'	'
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	0	0	0.2	0.2
Other Comprehensive (Loss) Income, Before Tax	0	-0.1	0.2	0.2
Income Tax (Benefit) Expense Related to Items of Other Comprehensive Income	0	0	0.1	0.1
Other Comprehensive (Loss) Income, Net of Tax	0	-0.1	0.1	0.1
Comprehensive Income	$12	$3.70	$91.60	$59.40

CONSOLIDATED_BALANCE_SHEETS_UN

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $)	Jun. 30, 2014	Sep. 30, 2013
In Millions, unless otherwise specified
ASSETS	'	'
Utility Plant	$2,360.30	$2,271.20
Less: Accumulated depreciation and amortization	532.4	494.6
Net Utility Plant	1,827.90	1,776.60
Non-utility property	8.2	7.7
Goodwill	210	247.1
Other investments	60.4	58.3
Other Property and Investments	278.6	313.1
Current Assets:	'	'
Cash and cash equivalents	571.8	53
Accounts receivable:	'	'
Utility	127.8	101.1
Other	91.7	78.2
Allowance for doubtful accounts	-11.5	-8
Delayed customer billings	28.7	0
Inventories:	'	'
Natural gas stored underground	118.2	182
Propane gas	9.4	9
Materials and supplies at average cost	8	8.2
Prepayments and other	51.1	52.4
Total Current Assets	995.2	475.9
Deferred Charges:	'	'
Regulatory assets	540	545.9
Other	15	13.9
Total Deferred Charges	555	559.8
Total Assets	3,656.70	3,125.40
Capitalization:	'	'
Common stock (par value $1 per share; 70.0 shares authorized; 43.2 and 32.7 shares issued and outstanding, at June 30, 2014 and September 30, 2013, respectively)	43.2	32.7
Paid-in capital	1,027.50	594.3
Retained earnings	471.6	420.1
Accumulated other comprehensive loss	-8.5	-0.8
Total Common Stock Equity	1,533.80	1,046.30
Long-term debt (less current portion)	976.6	912.7
Total Capitalization	2,510.40	1,959
Current Liabilities:	'	'
Notes payable	0	74
Accounts payable	152	140.2
Advance customer billings	0	23.7
Wages and compensation accrued	25.3	20.8
Taxes accrued	56.1	32.9
Other	86.7	61.6
Total Current Liabilities	320.1	353.2
Deferred Credits and Other Liabilities:	'	'
Deferred income taxes	398.9	379.1
Pension and postretirement benefit costs	209.7	228.7
Asset retirement obligations	74.3	74.6
Regulatory liabilities	90.1	85.5
Other	53.2	45.3
Total Deferred Credits and Other Liabilities	826.2	813.2
Commitments and Contingencies (Note 12)	'	'
Total Capitalization and Liabilities	3,656.70	3,125.40
Laclede Gas Company	'	'
ASSETS	'	'
Utility Plant	2,360.30	2,271.20
Less: Accumulated depreciation and amortization	532.4	494.6
Net Utility Plant	1,827.90	1,776.60
Goodwill	210	247.1
Other investments	56	54
Other Property and Investments	266	301.1
Current Assets:	'	'
Cash and cash equivalents	6	23.9
Accounts receivable:	'	'
Utility	127.8	101.1
Associated companies	1	1.1
Other	12.4	15.1
Allowance for doubtful accounts	-11.4	-7.9
Delayed customer billings	28.7	0
Inventories:	'	'
Natural gas stored underground	114	164.7
Propane gas	9.4	9
Materials and supplies at average cost	7.9	8
Prepayments and other	34.2	28.8
Total Current Assets	330	343.8
Deferred Charges:	'	'
Regulatory assets	540	545.9
Other	12.6	13.6
Total Deferred Charges	552.6	559.5
Total Assets	2,976.50	2,981
Capitalization:	'	'
Common stock and Paid-in capital ($1.00 per share par value; 50,000,000 authorized; 24,577 and 24,549 shares issued and outstanding at June 30, 2014 and September 30, 2013, respectively)	742.9	738.2
Retained earnings	286.1	237.8
Accumulated other comprehensive loss	-2	-2.1
Total Common Stock Equity	1,027	973.9
Long-term debt (less current portion)	807.9	887.7
Total Capitalization	1,834.90	1,861.60
Current Liabilities:	'	'
Notes payable	0	74
Notes payable – associated companies	126.9	46.7
Accounts payable	66.9	66.6
Accounts payable – associated companies	10.9	6.1
Advance customer billings	0	23.7
Wages and compensation accrued	25.3	20.8
Taxes accrued	53.2	32.6
Other	62.1	56.4
Total Current Liabilities	345.3	326.9
Deferred Credits and Other Liabilities:	'	'
Deferred income taxes	402.7	380.1
Pension and postretirement benefit costs	209.6	228.7
Asset retirement obligations	74	74.3
Regulatory liabilities	70.8	64.8
Other	39.2	44.6
Total Deferred Credits and Other Liabilities	796.3	792.5
Commitments and Contingencies (Note 12)	'	'
Total Capitalization and Liabilities	$2,976.50	$2,981

CONSOLIDATED_BALANCE_SHEETS_UN1

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $)	Jun. 30, 2014	Sep. 30, 2013
Capitalization:	'	'
Common Stock Par Value (in dollars per share)	$1	$1
Common Stock Shares Authorized (in shares)	70,000,000	70,000,000
Common Stock Shares Issued (in shares)	43,200,000	32,700,000
Common Stock Shares Outstanding (in shares)	43,200,000	32,700,000
Laclede Gas Company	'	'
Capitalization:	'	'
Common Stock Par Value (in dollars per share)	$1	$1
Common Stock Shares Authorized (in shares)	50,000,000	50,000,000
Common Stock Shares Issued (in shares)	24,577	24,549
Common Stock Shares Outstanding (in shares)	24,577	24,549

STATEMENTS_OF_CONSOLIDATED_CAS

STATEMENTS OF CONSOLIDATED CASH FLOWS (UNAUDITED) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Operating Activities:	'	'
Net Income	$99.50	$62.40
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, amortization, and accretion	59.1	34.7
Other – net	17.8	15
Changes in assets and liabilities:	'	'
Accounts receivable – net	-36.8	1.7
Unamortized purchased gas adjustments	17.4	34.4
Deferred purchased gas costs	1.7	12.2
Accounts payable	11.3	21.7
Delayed customer billings - net	-52.4	-36.5
Taxes accrued	22.3	16.6
Natural gas stored underground	63.8	33.6
Other assets and liabilities	-18.7	-28.8
Net cash provided by operating activities	185	167
Investing Activities:	'	'
Capital expenditures	-109.5	-96.8
Proceeds from sale of right to acquire New England Gas Company	11	0
Proceeds from final reconciliation of acquisition of Missouri Gas Energy	23.9	0
Other	2.9	-2.6
Net cash used in investing activities	-71.7	-99.4
Financing Activities:	'	'
Issuance of long-term debt	143.8	125
Redemption and maturity of first mortgage bonds	-80	-25
Repayment of short-term debt – net	-74	-40.1
Dividends paid	-42.9	-28.7
Issuance of common stock	459.7	431.3
Other	-1.1	-1.1
Net cash provided by financing activities	405.5	461.4
Net Increase in Cash and Cash Equivalents	518.8	529
Cash and Cash Equivalents at Beginning of Period	53	27.5
Cash and Cash Equivalents at End of Period	571.8	556.5
Supplemental disclosure of cash flow information:	'	'
Interest paid	26.6	22.7
Income taxes paid (refunded)	3	-2.8
Laclede Gas Company	'	'
Operating Activities:	'	'
Net Income	91.5	59.3
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation, amortization, and accretion	58.5	33.8
Other – net	18.3	12.4
Changes in assets and liabilities:	'	'
Accounts receivable – net	-20.3	4.3
Unamortized purchased gas adjustments	17.4	34.4
Deferred purchased gas costs	1.7	12.2
Accounts payable	4.7	9
Delayed customer billings - net	-52.4	-36.5
Taxes accrued	19.9	16.2
Natural gas stored underground	50.7	42.4
Other assets and liabilities	-12.4	-34.2
Net cash provided by operating activities	177.6	153.3
Investing Activities:	'	'
Capital expenditures	-108.4	-96
Proceeds from final reconciliation of acquisition of Missouri Gas Energy	23.9	0
Other	3.1	-1.4
Net cash used in investing activities	-81.4	-97.4
Financing Activities:	'	'
Issuance of first mortgage bonds	0	100
Redemption and maturity of first mortgage bonds	-80	-25
Repayment of short-term debt – net	-74	-40.1
Borrowings from Laclede Group	198.8	80.2
Repayment of borrowings from Laclede Group	-118.6	-117.4
Dividends paid	-42.8	-28.5
Issuance of common stock	1.2	1.9
Other	1.3	-0.6
Net cash provided by financing activities	-114.1	-29.5
Net Increase in Cash and Cash Equivalents	-17.9	26.4
Cash and Cash Equivalents at Beginning of Period	23.9	2.4
Cash and Cash Equivalents at End of Period	6	28.8
Supplemental disclosure of cash flow information:	'	'
Interest paid	26.1	22.3
Income taxes paid (refunded)	($0.50)	($6.60)

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Jun. 30, 2014
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) and Laclede Gas Company (Laclede Gas or the Utility), a 100% owned subsidiary of the Company. 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 Consolidated Financial Statements and Notes to Financial Statements contained in the Company’s and the Utility's Fiscal Year 2013 Form 10-K, respectively.
	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 Laclede Gas Company. In compliance with GAAP, transactions between the Utility and its affiliates as well as intercompany balances on the Utility's Balance Sheets have not been eliminated from the Utility's financial statements. The Utility's recent acquisition of Missouri Gas Energy (MGE) is included in the results of operations for the nine months ended June 30, 2014, and impacts the comparability of the current year financial statements to prior years. For a further discussion of the acquisition, see Note 2, Acquisitions. The Utility is a regulated natural gas distribution utility having a material seasonal cycle. As a result, these interim statements of income for Laclede Group are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year. Due to the seasonal nature of the Utility, Laclede Group’s earnings are typically concentrated during the heating season of November through April each fiscal year, although earnings for MGE are less seasonal than earnings from Laclede Gas due to MGE's rate design, which recovers fixed costs more evenly throughout the year.
	NATURE OF OPERATIONS - The Laclede Group, Inc. (NYSE: LG), headquartered in St. Louis, Missouri, is a public utility holding company. The Company has three operating segments: Gas Utility, Gas Marketing and Other. The Gas Utility segment serves St. Louis and eastern Missouri through Laclede Gas and serves Kansas City and western Missouri through MGE that provide residential, commercial and industrial customers with safe and reliable natural gas service. 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 and the non-regulated activities of Laclede Gas are described in Note 11, Information by Operating Segment, and are included in the Other column.
	REVENUE RECOGNITION - The Utility reads meters and bills its customers on monthly cycles. The Utility records its gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at June 30, 2014 and September 30, 2013 for the Utility, were $32.4 and $25.2, 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 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. For additional information on derivative instruments, refer to Note 8, Derivative Instruments and Hedging Activities. 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 Statements of Consolidated Income. This net presentation has no effect on operating income or net income.
	GROSS RECEIPTS TAXES - Gross receipts taxes associated with the Utility’s natural gas utility service are imposed on the Utility and billed to its customers. These amounts are recorded gross in the Statements of Consolidated Income. Amounts recorded in Gas Utility Operating Revenues for the three months ended June 30, 2014 and 2013 were $13.7 and $7.8, respectively. Amounts recorded in Gas Utility Operating Revenues for the nine months ended June 30, 2014 and 2013 were $67.9 and $35.3, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
	REGULATED OPERATIONS - The Utility accounts for its regulated operations in accordance with 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. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities).
	The following regulatory assets and regulatory liabilities were reflected in the Company's Condensed Consolidated Balance Sheets and the Utility's Balance Sheets as of June 30, 2014 and September 30, 2013, respectively. Unamortized Purchased Gas Adjustments are also included below, which are listed in the current assets section of each respective balance sheet.
		June 30,		September 30,
		2014		2013
	Regulatory Assets:
	Future income taxes due from customers	$	119.3	$	112.9
	Pension and postretirement benefit costs	328.7		381.4
	Purchased gas costs	16.6		18.2
	Compensated absences	8.1		8
	Other	67.3		25.4
	Total Regulatory Assets (non-current)	$	540	$	545.9
	Unamortized purchased gas adjustments (current)	0.2		17.5
	Total Regulatory Assets (current)	540.2		563.4
	Regulatory Liabilities:
	Unamortized investment tax credits	$	2.7	$	2.9
	Accrued cost of removal	58.9		59.1
	Other	28.5		23.5
	Total Regulatory Liabilities	$	90.1	$	85.5
	TRANSACTIONS WITH AFFILIATES - In compliance with GAAP, transactions between the Utility and its affiliates as well as intercompany balances on the Utility Balance Sheets have not been eliminated from the Utility financial statements. Transactions with associated companies include sales of natural gas from the Utility to LER, sales of natural gas from LER to the Utility, and propane transportation services provided by Laclede Pipeline Company to the Utility. For the three and nine months ended June 30, 2014, sales of natural gas from the Utility to LER were $0.2 and $4.5, respectively. For the three and nine months ended June 30, 2013, sales of natural gas from the Utility to LER were $0.0 and $10.5, respectively. For the three and nine months ended June 30, 2014, sales of natural gas from LER to the Utility were $28.1 and $72.5, respectively. For the three and nine months ended June 30, 2013, sales of natural gas from LER to the Utility were $9.4 and $24.5, respectively. Transportation services provided by Laclede Pipeline Company to the Utility during both the three months ended June 30, 2014 and 2013, totaled $0.3, and during both the nine months ended June 30, 2014 and 2013 totaled $0.8. Transactions between the Company and its affiliates have been eliminated.
	The Utility provides administrative and general support to affiliates. All such costs, which are not material, are billed to the appropriate affiliates. Also, Laclede Group may charge or reimburse the Utility for certain tax-related amounts. Unpaid balances relating to these activities are reflected in the Utility Balance Sheets as Accounts receivable-associated companies or as Accounts payable-associated companies. Additionally, the Utility may borrow funds from Laclede Group. Unpaid balances relating to this arrangement, if any, are reflected in Notes payable-associated companies. The Utility had outstanding borrowings from Laclede Group under a revolving credit note of $126.9 at June 30, 2014 and $46.7 at September 30, 2013. Advances under this note are due and payable on demand. The interest rate on the borrowing was 0.3% at June 30, 2014.
	NEW ACCOUNTING PRONOUNCEMENT - In May 2014, the FASB issued 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 effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early adoption not permitted. The Company and the Utility have not yet selected a transition method nor have they determined the impact, if any, of the standard on their ongoing financial conditions and results of operations.

ACQUISITIONS

ACQUISITIONS	9 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
ACQUISITIONS	'
	ACQUISITIONS
	Missouri Gas Energy (MGE)
	Effective September 1, 2013, the Utility completed the purchase from Southern Union Company (SUG), an affiliate of Energy Transfer Equity, L.P. (ETE) and Energy Transfer Partners, L.P., of substantially all of the assets and liabilities of MGE, a utility engaged in the distribution of natural gas on a regulated basis in western Missouri. The purchase was completed pursuant to the Purchase and Sale Agreement (MGE PSA) dated December 14, 2012. Under the terms of the MGE PSA, the Utility acquired MGE for a purchase price of $975.0, subject to reconciliation of certain amounts as discussed below.
	In accordance with Section 3.2 of the MGE PSA, Laclede Gas provided to SUG a reconciliation of certain balance sheet accounts from the amounts at September 30, 2012 to August 31, 2013, indicating the difference due to changes in the actual net assets transferred to the Company at closing from the level at September 30, 2012. Laclede Gas and SUG agreed to the final reconciliation amount of $23.9, which was paid by ETE to Laclede Gas on February 14, 2014.
	Also, on December 12, 2012, a subsidiary of Laclede Group, Plaza Massachusetts Acquisition Inc. (Plaza Mass), agreed to purchase New England Gas Company (NEG) from SUG. Subsequently, on February 11, 2013, the Company agreed to sell Plaza Mass to Algonquin Power & Utilities Corp. (APUC). On December 13, 2013, the Massachusetts Department of Public Utilities (MDPU) approved the transfer of NEG to an APUC subsidiary. Consistent with the February 11, 2013 agreements, on December 20, 2013, the Company closed the sale of Plaza Mass to an APUC subsidiary and received $11.0 from APUC. On December 24, 2013, the Massachusetts Attorney General filed a Motion for Clarification/Reconsideration with the MDPU claiming, among other things, that legislative approval was required for a transfer of utility assets. On March 26, 2014, the MDPU issued an order denying the Attorney General's motion. The Attorney General did not appeal, thus the MDPU's order approving the sale of NEG is now final.
	These receipts of funds in December and February and other working capital adjustments in the third quarter of 2014 effectively reduced the Utility's purchase price of MGE to $940.1 and reduced goodwill related to the transaction from $247.1 to $210.0. The purchase of MGE was accounted for in accordance with ASC 805 (“Topic 805”), “Business Combinations.” Accordingly, goodwill was 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. As part of the MGE acquisition, Laclede Gas has estimated the asset retirement obligation of MGE's long-lived assets as of the acquisition date. This allocation of asset retirement obligations is preliminary and will be finalized upon completion of a detailed fair value analysis that is being performed by the Company, which will be finalized prior to September 1, 2014.
	The following table summarizes the preliminary fair value of assets acquired and liabilities assumed at the date of acquisition:
		1-Sep-13
	Assets
	Utility plant	$	671.1
	Goodwill	210
	Other property and investments	3.3
	Total Other Property and Investments	884.4
	Accounts receivable	35.5
	Inventories	62.7
	Prepaid and other	0.3
	Total Current Assets	98.5
	Deferred charges	95.7
	Total Assets Acquired	$	1,078.60
	Liabilities
	Current liabilities	$	65.7
	Deferred credits and other liabilities	72.8
	Total Liabilities Assumed	138.5
	Net Assets Acquired	$	940.1
	For the three and nine months ended June 30, 2014, operating revenues were $87.3 and $484.0, respectively.
	Alabama Gas Corporation (Alagasco)
	On April 5, 2014, Laclede Group entered into an agreement with Energen Corporation (Energen) to acquire 100 percent of the common stock of Alabama Gas Corporation (Alagasco) (the Alagasco Transaction). Alagasco, a subsidiary of Energen, is engaged in the distribution of natural gas in central and parts of northern Alabama and serves more than 422,000 customers.
	On April 14, 2014, Laclede Group, Energen and Alagasco jointly filed with the Alabama Public Service Commission (APSC) to request approval of the Alagasco Transaction. On May 7, 2014, Laclede Group received confirmation of the early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvement Act of 1976, as amended. On July 1, 2014, a hearing on the application for approval of the Alagasco Transaction was held before the APSC. On July 22, 2014 the APSC unanimously voted to approve the Alagasco Transaction and subsequently issued a written order reflecting their decision effective July 24, 2014. Pursuant to Alabama law, a party has 30 days to appeal an order of the APSC. No party to the proceeding before the APSC formally opposed the application for approval.
	The stated purchase price is $1,600.0, subject to customary closing adjustments, which includes approximately $1,350.0 in cash and approximately $250.0 of assumed Alagasco long-term debt. The Alagasco Transaction was originally supported by a fully committed $1,350.0 bridge loan facility with Credit Suisse AG and Wells Fargo Bank, National Association, which as of April 28th has been syndicated to a group of eleven additional banks (collectively, together with Credit Suisse AG and Wells Fargo Bank, National Association, the "Bridge Lenders").
	On June 11, 2014, Laclede Group completed public offerings and sales of its common stock and equity units generating net proceeds in the aggregate of approximately $600.0, which are to be used to fund a portion of the purchase price for the Alagasco Transaction, or other general corporate purposes if the Alagasco Transaction is not consummated. The proceeds from such offerings automatically reduced the commitments of the Bridge Lenders by an equal amount. On June 16, 2014, Laclede Group and the Bridge Lenders entered into a first amendment to the bridge loan facility to further reduce the aggregate commitments of the Bridge Lenders to $700.0.

STOCKBASED_COMPENSATION

STOCK-BASED COMPENSATION	9 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
STOCK-BASED COMPENSATION	'
	STOCK-BASED COMPENSATION
	During the nine months ended June 30, 2014, the Company granted 125,727 performance-contingent restricted stock units to executive officers and key employees at a weighted average grant date fair value of $37.21 per share.
	During the nine months ended June 30, 2014, the Company granted 73,768 shares of time-vested restricted stock and stock units to executive officers, key employees, and directors at a weighted average grant date fair value of $45.68 per share. Of the 73,768 shares, 15,200 shares vested on July 30, 2014, 12,168 shares will vest on December 2, 2014, and the remaining 46,400 shares will vest during the fiscal year 2017. In the interim, participants receive full voting rights and dividends, which are not subject to forfeiture.
	During the nine months ended June 30, 2014, 70,953 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on December 1, 2010 and October 17, 2012, vested. The Company withheld 22,983 of the vested shares at a weighted average price of $45.83 per share pursuant to elections by employees to satisfy tax withholding obligations.

EARNINGS_PER_COMMON_SHARE

EARNINGS PER COMMON SHARE	9 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
EARNINGS PER COMMON SHARE	'
	EARNINGS PER COMMON SHARE
		Three Months Ended June 30,				Nine Months Ended June 30,
		2014		2013		2014		2013
	Basic EPS:
	Net Income	$	11.7	$	6.6	$	99.5	$	62.4
	Less: Income allocated to participating securities	—		0.1		0.4		0.4
	Net Income Available to Common Shareholders	$	11.7	$	6.5	$	99.1	$	62
	Weighted Average Shares Outstanding	34.9		26.1		33.3		23.6
	Basic Earnings Per Share of Common Stock	$	0.34	$	0.25	$	2.97	$	2.62
	Diluted EPS:
	Net Income	$	11.7	$	6.6	$	99.5	$	62.4
	Less: Income allocated to participating securities	—		0.1		0.4		0.4
	Net Income Available to Common Shareholders	$	11.7	$	6.5	$	99.1	$	62
	Weighted Average Shares Outstanding	34.9		26.1		33.3		23.6
	Dilutive Effect of Stock Options, Restricted Stock	0.1		0.1		0.1		0.1
	and Restricted Stock Units
	Weighted Average Diluted Shares	35		26.2		33.4		23.7
	Diluted Earnings Per Share of Common Stock	$	0.33	$	0.25	$	2.97	$	2.62
	Outstanding Shares Excluded from the Calculation
	of Diluted EPS Attributable to:
	Restricted stock and stock units subject to	0.3		0.2		0.3		0.2
	performance and/or market conditions

FINANCING

FINANCING

9 Months Ended

Jun. 30, 2014

Equity [Abstract]

'

FINANCING

'

FINANCING

Common Stock

In June 2014, the Company raised $478.7 of capital through the issuance of 10.4 million shares of common stock.

Equity Units

In June 2014, Laclede Group issued 2.875 million of Equity Units, initially consisting of Corporate Units, for an aggregate stated amount of approximately $143.8. Each Corporate Unit has a stated amount of fifty dollars and consists of (i) a stock purchase contract obligating the holder to purchase shares of Laclede Group's common stock, par value $1.00 per share (Common Stock) and (ii) a 1/20, or 5%, undivided beneficial ownership interest in one thousand dollars principal amount of Laclede Group's 2014 Series A 2.00% Remarketable Junior Subordinated Notes due 2022 (RSNs). The stock purchase contracts obligate the holders to purchase shares of Common Stock at a future settlement date prior to the relevant RSN maturity date. The purchase price to be paid under the stock purchase contracts is fifty dollars per Corporate Unit and the number of shares to be purchased will be determined under a formula based upon the average closing price of the Common Stock near the settlement date. The RSNs are pledged as collateral to secure the purchase of Common Stock under the related stock purchase contracts.

The Company makes quarterly interest payments on the RSNs and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. The Company may defer payments on the stock purchase contracts and the RSNs for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, interest on the RSNs and contract adjustment payments will compound on each respective payment date in which the payment was deferred. Also, during the deferral period, the Company may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Additionally, the Company may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs during the deferral period.

The Company has recorded the present value of the stock purchase contract payments as a liability offset by a charge to additional paid-in capital in equity. Interest payments on the RSNs are recorded as interest expense and stock purchase contract payments are charged against the liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense. In calculating diluted EPS, the Company applies the treasury stock method to the Corporate Units. These securities did not have an effect on diluted EPS for the three and nine months ended June 30, 2014.

Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Laclede Group will issue between approximately 2.5 million and 3.1 million shares of its common stock in April 2017. A total of approximately 4.2 million shares of Common Stock have been reserved for issuance in connection with the stock purchase contracts.

Selected information about the Company’s Equity Units is presented below:

Issuance Date

Units Issued (Millions)

Total Net Proceeds

Total Long-term Debt

RSN Annual Interest Rate

Stock Purchase Contract Annual Rate

Stock Purchase Contract Liability

6/11/14

2.875

$

139.4

$

143.8

2

%

4.75

%

$

19.7

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	9 Months Ended
	Jun. 30, 2014
Financial Instruments, Owned, at Fair Value [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	FAIR VALUE OF FINANCIAL INSTRUMENTS
	The carrying amounts for cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. Refer to Note 7, Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis.
	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
		Carrying		Fair		Quoted		Significant Observable Inputs		Significant Unobservable Inputs
		Amount		Value		Prices in Active Markets		(Level 2)		(Level 3)
						(Level 1)
	As of June 30, 2014
	Cash and cash equivalents	$	571.8	$	571.8	$	250.4	$	321.4	$	—
	Short-term debt	—		—		—		—		—
	Long-term debt	976.6		1,044.00		—		1,044.00		—
	As of September 30, 2013
	Cash and cash equivalents	$	53	$	53	$	52.8	$	0.2	$	—
	Short-term debt	74		74		—		74		—
	Long-term debt	912.7		954.1		—		954.1		—
	The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for the Utility are as follows:
						Classification of Estimated Fair Value
		Carrying		Fair		Quoted		Significant Observable Inputs		Significant Unobservable Inputs
		Amount		Value		Prices in Active Markets		(Level 2)		(Level 3)
						(Level 1)
	As of June 30, 2014
	Cash and cash equivalents	$	6	$	6	$	6	$	—	$	—
	Short-term debt	126.9		126.9		—		126.9		—
	Long-term debt	807.9		876.2		—		876.2		—
	As of September 30, 2013
	Cash and cash equivalents	$	23.9	$	23.9	$	23.9	$	—	$	—
	Short-term debt	120.7		120.7		—		120.7		—
	Long-term debt	887.7		930.4		—		930.4		—

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
FAIR VALUE MEASUREMENTS	'
	FAIR VALUE MEASUREMENTS
	The following table for the Company categorizes the assets and liabilities in the Condensed Consolidated Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition:
		Quoted		Significant		Significant		Effects of Netting and Cash Margin Receivables			Total
		Prices in		Observable		Unobservable		/Payables
		Active		Inputs		Inputs
		Markets		(Level 2)		(Level 3)
		(Level 1)
	As of June 30, 2014
	ASSETS
	Gas Utility
	U. S. Stock/Bond Mutual Funds	$	16.7	$	2.9	$	—	$	—		$	19.6
	Natural gas contracts	5.2		3.2		—		(0.5		)	7.9
	Gasoline and heating oil contracts	0.1		—		—		—			0.1
	Subtotal	22		6.1		—		(0.5		)	27.6
	Gas Marketing
	Natural gas contracts	0.8		5		0.8		(2.0		)	4.6
	Total	$	22.8	$	11.1	$	0.8	$	(2.5	)	$	32.2
	LIABILITIES
	Gas Utility
	Natural gas contracts	$	4	$	0.9	$	—	$	(4.7	)	$	0.2
	Gas Marketing
	Natural gas contracts	0.8		1.3		—		(2.0		)	0.1
	Other
	Interest Rate Swaps	—		10.5		—		—			10.5
	Total	$	4.8	$	12.7	$	—	$	(6.7	)	$	10.8
	As of September 30, 2013
	ASSETS
	Gas Utility
	U. S. Stock/Bond Mutual Funds	$	14.5	$	—	$	—	$	—		$	14.5
	Natural gas contracts	1.5		0.2		—		(1.7		)	—
	Gasoline and heating oil contracts	0.1		—		—		(0.1		)	—
	Subtotal	16.1		0.2		—		(1.8		)	14.5
	Gas Marketing
	Natural gas contracts	2.8		1.5		0.2		(1.2		)	3.3
	Total	$	18.9	$	1.7	$	0.2	$	(3.0	)	$	17.8
	LIABILITIES
	Gas Utility
	Natural gas contracts	$	3.5	$	5.4	$	—	$	(3.7	)	$	5.2
	Gas Marketing
	Natural gas contracts	0.2		1.5		—		(1.0		)	0.7
	Total	$	3.7	$	6.9	$	—	$	(4.7	)	$	5.9
	The mutual funds included in Level 1 are valued based on exchange-quoted market prices of individual securities. Derivative instruments included in Level 1 are valued using quoted market prices on the 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. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. The Company’s and Utility's policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer.
	There were no material Level 3 beginning and ending net derivative balances for the Company.
	The mutual funds are included in the Other investments line of the Condensed Consolidated Balance Sheets and Balance Sheets for the Company and the Utility, respectively. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the Condensed Consolidated Balance Sheets and Balance Sheets for the Company and the Utility, respectively, when a legally enforceable netting agreement exists between the Company or the Utility and the counterparty to a derivative contract. For additional information on derivative instruments, see Note 8, Derivative Instruments and Hedging Activities.

DERIVATIVE_INSTRUMENTS_AND_HED

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	9 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	'
	DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
	The Utility has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation and permits the Utility to hedge up to 70% of its normal volumes purchased for up to a 36-month period. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its Purchased Gas Adjustment (PGA) Clause, through which the Missouri Public Service Commission (MoPSC) allows the Utility to recover gas supply costs, subject to prudence review by the MoPSC. Accordingly, the Utility does not expect any adverse earnings impact as a result of the use of these derivative instruments. The Utility does not designate these instruments as hedging instruments for financial reporting purposes because gains or losses associated with the use of these derivative instruments are deferred and recorded as regulatory assets or regulatory liabilities pursuant to ASC Topic 980, “Regulated Operations,” and, as a result, have no direct impact on the Statements of Consolidated Income. The timing of the operation of the PGA Clause may cause interim variations in short-term cash flows, because the Utility is subject to cash margin requirements associated with changes in the values of these instruments. Nevertheless, carrying costs associated with such requirements are recovered through the PGA Clause.
	From time to time, the Utility purchases NYMEX futures and options contracts to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of its business. At June 30, 2014, Laclede Gas held 0.2 million gallons of gasoline futures contracts at an average price of $2.71 per gallon. Most of these contracts, the longest of which extends to September 2014, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815. The gains or losses on these derivative instruments are not subject to the Utility’s PGA Clause.
	In the course of its business, Laclede Group’s gas marketing subsidiary, LER, which includes its 100% owned subsidiary LER Storage Services, Inc., enters into commitments associated with the purchase or sale of natural gas. Certain of LER’s derivative natural gas contracts are designated as normal purchases or normal sales and, as such, are excluded from the scope of ASC Topic 815 and are accounted for as executory contracts on an accrual basis. Any of LER’s derivative natural gas contracts that are not designated as normal purchases or normal sales are accounted for at fair value. At June 30, 2014, the fair values of 63.0 million MMBtu of non-exchange traded natural gas commodity contracts were reflected in the Consolidated Balance Sheet of the Company. Of these contracts, 39.0 million MMBtu will settle during fiscal year 2014, 22.6 million MMBtu will settle during fiscal year 2015, while the remaining 1.4 million MMBtu will settle during fiscal year 2016. These contracts have not been designated as hedges; therefore, changes in the fair value of these contracts are reported in earnings each period.
	Furthermore, LER manages the price risk associated with its fixed-priced commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of NYMEX or Ice Clear Europe (ICE) futures, swap, and option contracts to lock in margins.
	At June 30, 2014, LER’s unmatched fixed-price positions were not material to Laclede Group’s financial position or results of operations. LER’s NYMEX and ICE natural gas futures, swap, and option contracts used to lock in margins may be designated as cash flow hedges of forecasted transactions for financial reporting purposes.
	On April 14, 2014, as amended on July 8, 2014, Laclede Group entered into certain interest rate swap agreements to effectively lock in interest rates on a portion of the long-term debt it anticipates issuing to finance its pending acquisition of Alagasco. These derivative instruments have been designated as cash flow hedges of forecasted transactions. These forward starting swaps involve the payment of a fixed interest rate and the receipt of a floating interest rate (the London Interbank Offered Rate, also known as LIBOR) over the terms specified in the contracts. At June 30, 2014, the notional amount of interest rate swaps outstanding was $375.0 with stated maturities ranging from 2019 to 2044 and fixed interest rates ranging between 1.89% and 3.54%. On July 8, 2014, these swaps were amended with fixed interest rates ranging between 1.95% and  3.56%. The notional amount of the interest rate swaps and stated maturities were unchanged under the amendment.
	The Company’s and the Utility's exchange-traded/cleared derivative instruments consist primarily of NYMEX, OTCBB, and ICE positions. The NYMEX and OTCBB is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX/ICE and OTCBB natural gas futures and swap positions at June 30, 2014 were as follows:
		Gas Utility							Gas Marketing
		MMBtu			Avg. Price				MMBtu		Avg. Price
		(millions)			Per				(millions)		Per
					MMBtu						MMBtu
	NYMEX/ICE Open short futures positions
	Fiscal 2014	—			$	—			3.09		$	4.45
	Fiscal 2015	—			—				3.15		4.63
	Fiscal 2016	—			—				0.05		4.22
	NYMEX/ICE Open long futures positions
	Fiscal 2014	1.71			$	3.82			1.39		$	4.5
	Fiscal 2015	0.94			3.84				3.05		4.53
	Fiscal 2016	—			—				0.2		4.2
	Fiscal 2017	—			—				0.02		4.28
	ICE Open long basis swap positions
	Fiscal 2014	—			$	—			3.45		$	0.38
	Fiscal 2015	—			—				1.16		0.38
	Fiscal 2016	—			—				2.75		0.58
	Fiscal 2017	—			—				6.87		0.5
	Fiscal 2018	—			—				1.09		0.5
	ICE Open short basis swap positions
	Fiscal 2014	—			$	—			2.62		$	0.02
	Fiscal 2015	—			—				0.62		0.09
	OTCBB Open long futures positions
	Fiscal 2014	3.85			$	4.06			—		$	—
	Fiscal 2015	15.62			4.29				—		—
	Fiscal 2016	1.78			4.27				—		—
	At June 30, 2014, the Utility had 26.0 million MMBtu of other price mitigation in place through the use of NYMEX and OTCBB natural gas option-based strategies while Gas Marketing had none.
	Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the Condensed Consolidated Balance Sheets and Balance Sheets for the Company and the Utility, respectively, at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in other comprehensive income (OCI). Accumulated other comprehensive income (AOCI) is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at June 30, 2014, it is expected that approximately $0.4 of pre-tax unrealized loss and $0.1 of pre-tax unrealized gains will be reclassified into the Statements of Condensed Consolidated Income and Statements of Condensed Income for the Company and the Utility, respectively, during the next twelve months. Cash flows from hedging transactions are classified in the same category as the cash flows from the items that are being hedged in the Statements of Consolidated Cash Flows and Statements of Cash Flows for the Company and the Utility, respectively.
	The Effect of Derivative Instruments on the Statements of Condensed Consolidated Income and Statements of Condensed Consolidated Comprehensive Income
		Location of Gain (Loss)	Three Months Ended June 30,							Nine Months Ended June 30,
		Recorded in Income	2014				2013			2014			2013
	Derivatives in Cash Flow Hedging Relationships
	Effective portion of gain (loss) recognized in OCI on derivatives:
	Gas Marketing natural gas contracts		$	0.1			$	5.5		$	(5.1	)	$	3.6
	Gas Utility gasoline and heating oil contracts		—				(0.1		)	0.1			0.1
	Interest rate swaps		(10.5		)		22.2			(10.5		)	17.7
	Total		$	(10.4	)		$	27.6		$	(15.5	)	$	21.4
	Effective portion of gain (loss) reclassified from AOCI to income:
	Natural gas contracts	Gas Marketing Operating Revenues	$	(1.1	)		$	(1.5	)	$	(4.6	)	$	(3.1	)
		Gas Marketing Operating Expenses	0.3				0.2			1.7			(0.5		)
	Sub-total		(0.8		)		(1.3		)	(2.9		)	(3.6		)
	Gasoline and heating oil contracts	Gas Utility Other Operations and Maintenance Expenses	—				—			0.1			0.1
	Total		$	(0.8	)		$	(1.3	)	$	(2.8	)	$	(3.5	)
	Ineffective portion of gain (loss) on derivatives recognized in income:
	Natural gas contracts	Gas Marketing Operating Revenues	$	—			$	—		$	(0.1	)	$	(0.4	)
		Gas Marketing Operating Expenses	—				—			0.1			(0.2		)
	Sub-total		—				—			—			(0.6		)
	Gasoline and heating oil contracts	Gas Utility Other Operations and Maintenance Expenses	—				—			—			(0.1		)
	Total		$	—			$	—		$	—		$	(0.7	)
	Derivatives Not Designated as Hedging Instruments *
	Gain (loss) recognized in income on derivatives:
	Natural gas contracts	Gas Marketing Operating Revenues	$	(3.2	)		$	0.2		$	12.9		$	0.4
	Total		$	(3.2	)		$	0.2		$	12.9		$	0.4
	*	Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Utility’s PGA Clause and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Consolidated Income. Such amounts are recognized in the Statements of Consolidated Income as a component of Gas Utility Natural and Propane Gas operating expenses when they are recovered through the PGA Clause and reflected in customer billings.
	Fair Value of Derivative Instruments in the Condensed Consolidated Balance Sheet at June 30, 2014
	Asset Derivatives*					Liability Derivatives*
	Balance Sheet Location	Fair				Balance Sheet Location	Fair
		Value					Value
Derivatives designated as hedging instruments
Gas Utility:
Gasoline and heating oil contracts	Prepayments and other	$	0.1			Prepayments and other	$	—
Gas Marketing:
Natural gas contracts	Prepayments and other	0.8				Prepayments and other	0.5
	Deferred Charges - Other	0.3				Deferred Charges - Other	0.4
Other:
Interest rate swaps	Current Liabilities - Other	—				Current Liabilities - Other	10.5
Sub-total		1.2					11.4
Derivatives not designated as hedging instruments
Gas Utility:
Natural gas contracts	Prepayments and other	8.4				Prepayments and other	4.7
	Accounts Receivable – Other	4.2				Accounts Receivable – Other	—
	Deferred Charges - Other	—				Deferred Charges - Other	0.2
Sub-total		12.6					4.9
Gas Marketing:
Natural gas contracts	Prepayments and other	3.5				Prepayments and other	0.9
	Deferred Charges - Other	1.9				Deferred Charges - Other	0.2
	Current Liabilities - Other	—				Current Liabilities - Other	0.1
Sub-total		5.4					1.2
Total derivatives		$	19.2				$	17.5
Fair Value of Derivative Instruments in the Condensed Consolidated Balance Sheet at September 30, 2013
	Asset Derivatives*					Liability Derivatives*
	Balance Sheet Location	Fair			*	Balance Sheet Location	Fair
		Value					Value
Derivatives designated as hedging instruments
Gas Utility:
Gasoline and heating oil contracts	Accounts Receivable – Other	$	0.1			Accounts Receivable – Other	$	—
Gas Marketing:
Natural gas contracts	Prepayments and other	2.2				Prepayments and other	0.5
Sub-total		2.3					0.5
Derivatives not designated as hedging instruments
Gas Utility:
Natural gas contracts	Accounts Receivable – Other	1.5				Accounts Receivable – Other	3.5
	Current Liabilities - Other	0.2				Current Liabilities - Other	4
	Deferred Credits and Other Liabilities - Other	—				Deferred Credits and Other Liabilities - Other	1.4
Sub-total		1.7					8.9
Gas Marketing:
Natural gas contracts	Prepayments and other	1.9				Prepayments and other	0.2
	Current Liabilities - Other	0.2				Current Liabilities - Other	0.8
	Deferred Charges - Other	0.2				Deferred Charges - Other	0.1
	Deferred Credits and Other Liabilities - Other	—				Deferred Credits and Other Liabilities - Other	0.1
Sub-total		2.3					1.2
Total derivatives		$	6.3				$	10.6
*	The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Consolidated Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Company’s net economic exposure. Refer to Note 7, Fair Value Measurements, for information on the valuation of derivative instruments.
Following is a reconciliation of the amounts in the tables above to the amounts presented in the Condensed Consolidated    Balance Sheets:
	30-Jun-14				30-Sep-13
Fair value of asset derivatives presented above:	$	19.2			$	6.3
Fair value of cash margin receivables offset with derivatives	—				1.7
Netting of assets and liabilities with the same counterparty	(6.7		)		(4.7		)
Total	$	12.5			$	3.3
Derivative Instrument Assets, per Balance Sheets:
Prepayments and other	$	11.9			$	3.3
Deferred Charges - Other	0.6				—
Total	$	12.5			$	3.3
Fair value of liability derivatives presented above	$	17.5			$	10.6
Fair value of cash margin payables offset with derivatives	—				—
Netting of assets and liabilities with the same counterparty	(6.7		)		(4.7		)
Total	$	10.8			$	5.9
Derivative Instrument Liabilities, per Balance Sheets:
Current Liabilities - Other	$	10.6			$	4.4
Deferred Credits and Other Liabilities - Other	0.2				1.5
Total	$	10.8			$	5.9
Additionally, at June 30, 2014, and September 30, 2013, the Company had $2.6 and $3.2, respectively, in cash margin receivables not offset with derivatives, that are presented in Accounts Receivable - Other.
Following is a reconciliation of the amounts in the tables above to the amounts presented in the Utility Balance Sheets:
	30-Jun-14				30-Sep-13
Fair value of asset derivatives presented above:	$	12.7			$	1.8
Fair value of cash margin receivables offset with derivatives	—				1.9
Netting of assets and liabilities with the same counterparty	(4.7		)		(3.7		)
Total	$	8			$	—
Derivative Instrument Assets, per Balance Sheets:
Prepayments and other	$	8			$	—
Deferred Charges - Other	—				—
Total	$	8			$	—
Fair value of liability derivatives presented above	$	4.9			$	8.9
Fair value of cash margin payables offset with derivatives	—				—
Netting of assets and liabilities with the same counterparty	(4.7		)		(3.7		)
Total	$	0.2			$	5.2
Derivative Instrument Liabilities, per Balance Sheets:
Current Liabilities - Other	$	—			$	5.2
Deferred Credits and Other Liabilities - Other	0.2				—
Total	$	0.2			$	5.2
Additionally, at June 30, 2014, and September 30, 2013, the Utility had $0.9, and  $2.9, respectively, in cash margin receivables not offset with derivatives, that are presented in Accounts Receivable - Other.

CONCENTRATIONS_OF_CREDIT_RISK

CONCENTRATIONS OF CREDIT RISK	9 Months Ended
	Jun. 30, 2014
Risks and Uncertainties [Abstract]	'
CONCENTRATIONS OF CREDIT RISK	'
	CONCENTRATIONS OF CREDIT RISK
	A significant portion of LER’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of transactions with these counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. To manage this risk, as well as credit risk from significant counterparties in these and other industries, LER has established procedures to determine the creditworthiness of its counterparties. These procedures include obtaining credit ratings and credit reports, analyzing counterparty financial statements to assess financial condition, and considering the industry environment in which the counterparty operates. This information is monitored on an ongoing basis. In some instances, LER may require credit assurances such as prepayments, letters of credit, or parental guarantees. In addition, LER may enter into netting arrangements to mitigate credit risk with counterparties in the energy industry from which LER both sells and purchases natural gas. Sales are typically made on an unsecured credit basis with payment due the month following delivery. Accounts receivable amounts are closely monitored and provisions for uncollectible amounts are accrued when losses are probable. LER records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in accounts receivable attributable to energy producers and their marketing affiliates amounted to $16.3 at June 30, 2014. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $9.3. Accounts receivable attributable to utility companies and their marketing affiliates comprised $34.6 of total accounts receivable at June 30, 2014, while net receivable amounts from these customers, reflecting netting arrangements, were $29.1. LER also has concentrations of credit risk with certain individually significant counterparties. At June 30, 2014, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure) were $30.6. These five counterparties are investment-grade rated. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $24.4. Additionally, LER has concentrations of credit risk with pipeline companies associated with its natural gas receivable amounts.

PENSION_PLANS_AND_OTHER_POSTRE

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS	9 Months Ended
	Jun. 30, 2014
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS	'
	PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS
	Pension Plans
	The Utility has non-contributory, defined benefit, trusteed forms of pension plans covering substantially all employees. Plan assets consist primarily of corporate and U.S. government obligations and a growth segment consisting of exposure to equity markets, commodities, real estate and inflation-indexed securities, achieved through derivative instruments.
	The net periodic pension costs include the following components:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Service cost – benefits earned during the period	$	2.4		$	2.3		$	7.3		$	6.9
	Interest cost on projected benefit obligation	6			4.1			18			12.2
	Expected return on plan assets	(6.6		)	(4.7		)	(19.9		)	(14.2		)
	Amortization of prior service cost	0.2			0.1			0.4			0.4
	Amortization of actuarial loss	1.8			2.8			5.3			8.5
	Loss on lump-sum settlement	—			12.3			1.3			12.3
	Sub-total	3.8			16.9			12.4			26.1
	Regulatory adjustment	2.9			(12.7		)	7.4			(13.6		)
	Net pension cost	$	6.7		$	4.2		$	19.8		$	12.5
	Pursuant to the provisions of the Utility'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 recognized as settlements during the nine months ended June 30, 2014 were $19.8. There were $39.7 lump-sum payments recognized as settlements during the nine months ended June 30, 2013.
	Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains or losses not yet included in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for Laclede Gas' qualified pension plans is based on an annual allowance of $15.5 effective January 1, 2011. The recovery in rates for MGE's qualified pension plan is based on an annual allowance of $10.0 originally effective February 20, 2010. Recently, the MoPSC approved an annual allowance of $9.9 effective May 1, 2014. The difference between these amounts and pension expense as calculated pursuant to the above and that otherwise would be included in the Group's Statements of Condensed Consolidated Income and Statements of Consolidated Comprehensive Income and the Utility's Statements of Condensed Income and Statements of Comprehensive Income, is deferred as a regulatory asset or regulatory liability.
	The funding policy of the Utility 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 2014 contributions to the pension plans through June 30, 2014 were $18.2 to the qualified trusts and $0.3 to the non-qualified plans.
	Contributions to the pension plans for the remaining three months of fiscal 2014 are anticipated to be approximately $5.7 to the qualified trusts and $0.1 to the non-qualified plans.
	Postretirement Benefits
	The Utility provides certain life insurance benefits at retirement. Under the Laclede Gas plans, medical insurance is currently available after early retirement until age 65. Under the MGE plans, medical insurance is currently available upon retirement until death. The transition obligation not yet included in postretirement benefit cost is being amortized over 20 years.
	Net periodic postretirement benefit costs consisted of the following components:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Service cost – benefits earned during the period	$	2.8		$	2.5		$	8.4		$	7.6
	Interest cost on accumulated postretirement benefit obligation	2.1			1.2			6.5			3.8
	Expected return on plan assets	(1.7		)	(1.0		)	(5.1		)	(3.2		)
	Amortization of transition obligation	—			0.1			—			0.1
	Amortization of prior service cost (credit)	—			—			—			—
	Amortization of actuarial loss	1.5			1.2			4.5			3.9
	Sub-total	4.7			4			14.3			12.2
	Regulatory adjustment	(2.4		)	(1.7		)	(7.2		)	(5.1		)
	Net postretirement benefit cost	$	2.3		$	2.3		$	7.1		$	7.1
	Missouri state law provides for the recovery in rates of costs accrued pursuant to GAAP provided that such costs are funded through an independent, external funding mechanism. The Utility established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi trusts as its external funding mechanisms. The assets of VEBA and Rabbi trusts consist primarily of money market securities and mutual funds invested in stocks and bonds.
	Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains and losses not yet included in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s postretirement benefit plans is based on an annual allowance of $9.5 effective January 1, 2011. The difference between these amounts and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Condensed Consolidated Income and Statements of Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.
	The Utility's 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 2014 contributions to the postretirement plans through June 30, 2014 were $9.5. Contributions to the postretirement plans for the remaining three months of fiscal year 2014 are anticipated to be $9.7 to the qualified trusts and $0.3 paid directly to participants from the Utility's funds.

INFORMATION_BY_OPERATING_SEGME

INFORMATION BY OPERATING SEGMENT	9 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
INFORMATION BY OPERATING SEGMENT	'
	INFORMATION BY OPERATING SEGMENT
	All of Laclede Group’s subsidiaries are 100% owned. The Gas Utility segment consists of the regulated operations of the Utility and is the core business segment of each of Laclede Group and the Utility. The Utility is a public utility engaged in the retail distribution and sale of natural gas serving an area in eastern Missouri, including the City of St. Louis, through Laclede Gas and an area in western Missouri, including Kansas City, through MGE. Laclede Group's Gas Marketing segment includes the results of LER, a subsidiary engaged in the non-regulated marketing of natural gas. Other includes, for Laclede Group only, Laclede Pipeline Company’s transportation of liquid propane regulated by the Federal Energy Regulatory Commission (FERC) as well as non-regulated activities, including, among other activities, natural gas fueling stations, real estate development, the compression of natural gas, and financial investments in other enterprises. Other also includes the Utility's non-regulated business activities, which are comprised of its propane storage and related services. Beginning July 1, 2013, propane-related services were included within Gas Utility operations pursuant to Laclede Gas' most recent rate case. Accounting policies are described in Note 1, Summary of Significant Accounting Policies. Intersegment transactions include sales of natural gas from the Utility to LER, propane storage services provided by the Utility to Laclede Pipeline Company, sales of natural gas from LER to the Utility, and propane transportation services provided by Laclede Pipeline Company to the Utility.
	Management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impacts of net unrealized gains and losses and other timing differences associated with energy-related transactions. Net economic earnings also excludes the after-tax impacts related to acquisition, divestiture, and restructuring activities.
	Laclede Group	Gas Utility			Gas Marketing			Other			Eliminations			Consolidated
	Three Months Ended June 30, 2014
	Revenues from external customers	$	214		$	27.1		$	0.7		$	—		$	241.8
	Intersegment revenues	0.2			27.9			0.5			(28.6		)	—
	Total Operating Revenues	214.2			55			1.2			(28.6		)	241.8
	Operating Expenses
	Gas Utility
	Natural and propane gas	77.6			—			—			(28.3		)	49.3
	Other operation and maintenance	73.3			—			—			(0.3		)	73
	Depreciation and amortization	18.4			—			—			—			18.4
	Taxes, other than income taxes	22.2			—			—			—			22.2
	Total Gas Utility Operating Expenses	191.5			—			—			(28.6		)	162.9
	Gas Marketing	—			50			—			—			50
	Other	—			—			4.2			—			4.2
	Total Operating Expenses	191.5			50			4.2			(28.6		)	217.1
	Operating Income	$	22.7		$	5		$	(3.0	)	$	—		$	24.7
	Net Economic Earnings (Losses)	$	13.3		$	1.9		$	(0.7	)	$	—		$	14.5
	Three Months Ended June 30, 2013
	Revenues from external customers	$	131.5		$	33.4		$	0.4		$	—		$	165.3
	Intersegment revenues	—			9.4			0.7			(10.1		)	—
	Total Operating Revenues	131.5			42.8			1.1			(10.1		)	165.3
	Operating Expenses
	Gas Utility
	Natural and propane gas	52.8			—			—			(9.6		)	43.2
	Other operation and maintenance	42.2			—			—			0.3			42.5
	Depreciation and amortization	11.5			—			—			—			11.5
	Taxes, other than income taxes	12.9			—			—			—			12.9
	Total Gas Utility Operating Expenses	119.4			—			—			(9.3		)	110.1
	Gas Marketing	—			40.6			—			—			40.6
	Other	—			—			3.1			(0.8		)	2.3
	Total Operating Expenses	119.4			40.6			3.1			(10.1		)	153
	Operating Income	$	12.1		$	2.2		$	(2.0	)	$	—		$	12.3
	Net Economic Earnings	$	6.8		$	1.6		$	(0.2	)	$	—		$	8.2
	Laclede Group	Gas Utility			Gas Marketing			Other			Eliminations			Consolidated
	Nine Months Ended June 30, 2014
	Revenues from external customers	$	1,283.60		$	120.2		$	1.1		$	—		$	1,404.90
	Intersegment revenues	4.5			68			1.5			(74.0		)	—
	Total Operating Revenues	1,288.10			188.2			2.6			(74.0		)	1,404.90
	Operating Expenses
	Gas Utility
	Natural and propane gas	769.7			—			—			(73.3		)	696.4
	Other operation and maintenance	208			—			—			(0.7		)	207.3
	Depreciation and amortization	58.5			—			—			—			58.5
	Taxes, other than income taxes	92.6			—			—			—			92.6
	Total Gas Utility Operating Expenses	1,128.80			—			—			(74.0		)	1,054.80
	Gas Marketing	—			166.8			—			—			166.8
	Other	—			—			8.5			—			8.5
	Total Operating Expenses	1,128.80			166.8			8.5			(74.0		)	1,230.10
	Operating Income	$	159.3		$	21.4		$	(5.9	)	$	—		$	174.8
	Net Economic Earnings (Losses)	$	93.8		$	9.8		$	(1.1	)	$	—		$	102.5
	Nine Months Ended June 30, 2013
	Revenues from external customers	$	735.7		$	129.9		$	4.3		$	—		$	869.9
	Intersegment revenues	10.5			14			1.1			(25.6		)	—
	Total Operating Revenues	746.2			143.9			5.4			(25.6		)	869.9
	Operating Expenses
	Gas Utility
	Natural and propane gas	435.3			—			—			(25.1		)	410.2
	Other operation and maintenance	123			—			—			0.3			123.3
	Depreciation and amortization	33.7			—			—			—			33.7
	Taxes, other than income taxes	49.5			—			—			—			49.5
Total Gas Utility Operating Expenses	641.5			—			—			(24.8		)	616.7
Gas Marketing	—			134			—			—			134
Other	—			—			13.8			(0.8		)	13
Total Operating Expenses	641.5			134			13.8			(25.6		)	763.7
Operating Income	$	104.7		$	9.9		$	(8.4	)	$	—		$	106.2
Net Economic Earnings	$	62.3		$	7.3		$	(0.7	)	$	—		$	68.9
The Company's total asset detail is as follows:
	June 30,			September 30,
Laclede Group	2014			2013
Total Assets:
Gas Utility	$	2,976.50		$	2,981.00
Gas Marketing	185.8			163.9
Other	989			115.6
Eliminations	(494.6		)	(135.1		)
Total Assets	$	3,656.70		$	3,125.40
Laclede Gas	Gas Utility			Other			Adjustments & Eliminations			Total
Three Months Ended June 30, 2014
Operating revenues	$	214.2		$	—		$	—		$	214.2
Net Economic Earnings	13.3			(0.1		)	—			13.2
Nine Months Ended June 30, 2014
Operating revenues	$	1,288.10		$	0.1		$	—		$	1,288.20
Net Economic Earnings	93.8			(0.1		)	—			93.7
Three Months Ended June 30, 2013
Operating revenues	$	131.5		$	0.2		$	—		$	131.7
Net Economic Earnings	6.8			(0.1		)	—			6.7
Nine Months Ended June 30, 2013
Operating revenues	$	746.2		$	1.6		$	—		$	747.8
Net Economic Earnings	62.3			0.7			—			63
The Utility's total asset detail is as follows:
	June 30,			September 30,
Laclede Gas	2014			2013
Total Assets:
Gas Utility	$	2,976.50		$	2,981.00
Other	—			—
Total Assets	$	2,976.50		$	2,981.00
The following table reconciles the Company's Net Income (GAAP) to Net Economic Income (Non-GAAP):
	Three Months Ended June 30,						Nine Months Ended June 30,
Laclede Group	2014			2013			2014			2013
Net income (GAAP)	$	11.7		$	6.6		$	99.5		$	62.4
Unrealized (gain) loss on energy-related derivative contracts	(1.0		)	(0.3		)	(2.3		)	0.6
Lower of cost or market inventory adjustments	(0.1		)	0.5			(0.7		)	0.6
Realized (gain) loss on economic hedges prior to sale of the physical commodity	—			—			(0.1		)	—
Acquisition, divestiture and restructuring activities	3.9			1.4			6.1			5.3
Net Economic Earnings (Non-GAAP)	$	14.5		$	8.2		$	102.5		$	68.9
The following table reconciles the Utility's Net Income (GAAP) to Net Economic Income (Non-GAAP):
	Three Months Ended June 30,						Nine Months Ended June 30,
Laclede Gas	2014			2013			2014			2013
Net Income (GAAP)	$	12		$	3.8		$	91.5		$	59.3
Unrealized (gain) loss on energy-related derivative contracts	—			—			—			0.1
Acquisition, divestiture and restructuring activities	1.2			2.9			2.2			3.6
Net Economic Earnings (Non-GAAP)	$	13.2		$	6.7		$	93.7		$	63

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	COMMITMENTS AND CONTINGENCIES
	Commitments
	The Company and the Utility 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 June 30, 2014 are estimated at approximately $1,150 for the Company and $695 for the Utility. Additional contracts are generally entered into prior to or during the heating season. The Utility recovers its costs from customers in accordance with the PGA Clause.
	Contingencies
	The Utility 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 the Utility's financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, the Company or the Utility may be required to incur additional costs.
	Similar to other natural gas utility companies, the Utility faces the risk of incurring environmental liabilities. In the natural gas industry, these are typically associated with sites formerly owned or operated by gas distribution companies like Laclede Gas and MGE or its predecessor companies at which manufactured gas operations took place. At this time, Laclede Gas has identified three former manufactured gas plant (MGP) sites where costs have been incurred and claims have been asserted: one in Shrewsbury, Missouri and two in the City of St. Louis, Missouri. 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.
	One of the sites located in the City of St. Louis is currently owned by a development agency of the City, which, together with other City development agencies, has selected a developer to redevelop the site. In conjunction with this redevelopment effort, Laclede Gas and another former owner of the site entered into an agreement (Remediation Agreement) with the City development agencies, the developer, and an environmental consultant that obligates one of the City agencies and the environmental consultant to remediate the site and obtain a No Further Action letter from the Missouri Department of Natural Resources. The Remediation Agreement also provides for a release of Laclede Gas and the other former site owner from certain liabilities related to the past and current environmental condition of the site and requires the developer and the environmental consultant to maintain certain insurance 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.
	To date, amounts required for remediation at these sites have not been material. However, the amount of costs relative to future remedial actions at these and other sites is unknown and may be material. Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the MGP sites. While some of the insurers have denied coverage and reserved their rights, Laclede Gas continues to discuss potential reimbursements with them. In 2005, the Utility’s outside consultant completed an analysis of the MGP sites to determine cost estimates for a one-time contractual transfer of risk from each of the Utility’s insurers of environmental coverage for the MGP sites. That analysis demonstrated a range of possible future expenditures to investigate, monitor, and remediate these MGP sites from $5.8 to $36.3 based upon then currently available facts, technology, and laws and regulations.
	The actual costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remedial actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and governmental regulations, the ultimate ability of other potentially responsible parties to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries.
	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. The Missouri Department of Natural Resources awarded a Certificate of Completion to Missouri Gas Energy in 2001 for a site located at 20th and Indiana in Kansas City after an initial site analysis and the property was subsequently sold.
	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 Missouri Department of Natural Resources with respect to its remediation efforts and monitoring activities at these sites.
	Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable. The Utility anticipates that any costs it may incur in the future to remediate these sites, less any amounts received as insurance proceeds or as contributions from other potentially responsible parties, would be deferred and recovered in rates through periodic adjustments approved by the MoPSC. Accordingly, any potential liabilities that may arise associated with remediating these sites are not expected to have a material impact on the future financial position and results of operations of the Utility or the Company.
	As discussed in Note 8, Derivative Instruments and Hedging Activities, Laclede Gas and LER enter into NYMEX and ICE exchange-traded/cleared derivative instruments. Previously, these instruments were held in accounts at MF Global, Inc. On October 31, 2011, affiliated entities of MF Global filed a Chapter 11 petition at the U.S. Bankruptcy Court in the Southern District of New York. Subsequently, the court-appointed bankruptcy trustee transferred all of the open positions and a significant portion of the margin deposits of Laclede Gas and LER to a new brokerage firm. On June 27, 2013, the bankruptcy Trustee issued a statement projecting that MF Global customers would receive a full payout of their claims. In 2014, both the Laclede Gas and LER accounts were paid in full.
	The Company and the Utility are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome will not have a material effect on the Statements of Condensed Consolidated Income, Condensed Consolidated Balance Sheets, and Condensed Consolidated Statement of Cash Flows of the Company and the Statements of Condensed Income, Balance Sheets and Statements of Condensed Cash Flows of the Utility.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Intercompany Profit to Regulated Affiliates, Policy [Policy Text Block]	'
	TRANSACTIONS WITH AFFILIATES - In compliance with GAAP, transactions between the Utility and its affiliates as well as intercompany balances on the Utility Balance Sheets have not been eliminated from the Utility financial statements. Transactions with associated companies include sales of natural gas from the Utility to LER, sales of natural gas from LER to the Utility, and propane transportation services provided by Laclede Pipeline Company to the Utility.
BASIS OF PRESENATION	'
	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) and Laclede Gas Company (Laclede Gas or the Utility), a 100% owned subsidiary of the Company. 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 Consolidated Financial Statements and Notes to Financial Statements contained in the Company’s and the Utility's Fiscal Year 2013 Form 10-K, respectively.
	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 Laclede Gas Company. In compliance with GAAP, transactions between the Utility and its affiliates as well as intercompany balances on the Utility's Balance Sheets have not been eliminated from the Utility's financial statements. The Utility's recent acquisition of Missouri Gas Energy (MGE) is included in the results of operations for the nine months ended June 30, 2014, and impacts the comparability of the current year financial statements to prior years. For a further discussion of the acquisition, see Note 2, Acquisitions. The Utility is a regulated natural gas distribution utility having a material seasonal cycle. As a result, these interim statements of income for Laclede Group are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year. Due to the seasonal nature of the Utility, Laclede Group’s earnings are typically concentrated during the heating season of November through April each fiscal year, although earnings for MGE are less seasonal than earnings from Laclede Gas due to MGE's rate design, which recovers fixed costs more evenly throughout the year.
REVENUE RECOGNITION	'
	REVENUE RECOGNITION - The Utility reads meters and bills its customers on monthly cycles. The Utility records its gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at June 30, 2014 and September 30, 2013 for the Utility, were $32.4 and $25.2, 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 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. For additional information on derivative instruments, refer to Note 8, Derivative Instruments and Hedging Activities. 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 Statements of Consolidated 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 Utility’s natural gas utility service are imposed on the Utility and billed to its customers. These amounts are recorded gross in the Statements of Consolidated Income. Amounts recorded in Gas Utility Operating Revenues for the three months ended June 30, 2014 and 2013 were $13.7 and $7.8, respectively. Amounts recorded in Gas Utility Operating Revenues for the nine months ended June 30, 2014 and 2013 were $67.9 and $35.3, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
REGULATED OPERATIONS	'
	REGULATED OPERATIONS - The Utility accounts for its regulated operations in accordance with 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. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities).
TRANSACTIONS WITH AFFILIATES	'
	The Utility provides administrative and general support to affiliates. All such costs, which are not material, are billed to the appropriate affiliates. Also, Laclede Group may charge or reimburse the Utility for certain tax-related amounts. Unpaid balances relating to these activities are reflected in the Utility Balance Sheets as Accounts receivable-associated companies or as Accounts payable-associated companies. Additionally, the Utility may borrow funds from Laclede Group. Unpaid balances relating to this arrangement, if any, are reflected in Notes payable-associated companies.
NEW ACCOUNTING PRONOUNCEMENT	'
	NEW ACCOUNTING PRONOUNCEMENT - In May 2014, the FASB issued 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 effective for fiscal years, and interim periods within those years, beginning after December 15, 2016, with early adoption not permitted. The Company and the Utility have not yet selected a transition method nor have they determined the impact, if any, of the standard on their ongoing financial conditions and results of operations.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	9 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Regulatory Assets and Liabilities	'
	The following regulatory assets and regulatory liabilities were reflected in the Company's Condensed Consolidated Balance Sheets and the Utility's Balance Sheets as of June 30, 2014 and September 30, 2013, respectively. Unamortized Purchased Gas Adjustments are also included below, which are listed in the current assets section of each respective balance sheet.
		June 30,		September 30,
		2014		2013
	Regulatory Assets:
	Future income taxes due from customers	$	119.3	$	112.9
	Pension and postretirement benefit costs	328.7		381.4
	Purchased gas costs	16.6		18.2
	Compensated absences	8.1		8
	Other	67.3		25.4
	Total Regulatory Assets (non-current)	$	540	$	545.9
	Unamortized purchased gas adjustments (current)	0.2		17.5
	Total Regulatory Assets (current)	540.2		563.4
	Regulatory Liabilities:
	Unamortized investment tax credits	$	2.7	$	2.9
	Accrued cost of removal	58.9		59.1
	Other	28.5		23.5
	Total Regulatory Liabilities	$	90.1	$	85.5

ACQUISITIONS_Tables

ACQUISITIONS (Tables)	9 Months Ended
	Jun. 30, 2014
Business Combinations [Abstract]	'
Schedule of preliminary fair value of assets acquired and liabilities assumed	'
	The following table summarizes the preliminary fair value of assets acquired and liabilities assumed at the date of acquisition:
		1-Sep-13
	Assets
	Utility plant	$	671.1
	Goodwill	210
	Other property and investments	3.3
	Total Other Property and Investments	884.4
	Accounts receivable	35.5
	Inventories	62.7
	Prepaid and other	0.3
	Total Current Assets	98.5
	Deferred charges	95.7
	Total Assets Acquired	$	1,078.60
	Liabilities
	Current liabilities	$	65.7
	Deferred credits and other liabilities	72.8
	Total Liabilities Assumed	138.5
	Net Assets Acquired	$	940.1

EARNINGS_PER_COMMON_SHARE_Tabl

EARNINGS PER COMMON SHARE (Tables)	9 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Earnings Per Common Share	'
	EARNINGS PER COMMON SHARE
		Three Months Ended June 30,				Nine Months Ended June 30,
		2014		2013		2014		2013
	Basic EPS:
	Net Income	$	11.7	$	6.6	$	99.5	$	62.4
	Less: Income allocated to participating securities	—		0.1		0.4		0.4
	Net Income Available to Common Shareholders	$	11.7	$	6.5	$	99.1	$	62
	Weighted Average Shares Outstanding	34.9		26.1		33.3		23.6
	Basic Earnings Per Share of Common Stock	$	0.34	$	0.25	$	2.97	$	2.62
	Diluted EPS:
	Net Income	$	11.7	$	6.6	$	99.5	$	62.4
	Less: Income allocated to participating securities	—		0.1		0.4		0.4
	Net Income Available to Common Shareholders	$	11.7	$	6.5	$	99.1	$	62
	Weighted Average Shares Outstanding	34.9		26.1		33.3		23.6
	Dilutive Effect of Stock Options, Restricted Stock	0.1		0.1		0.1		0.1
	and Restricted Stock Units
	Weighted Average Diluted Shares	35		26.2		33.4		23.7
	Diluted Earnings Per Share of Common Stock	$	0.33	$	0.25	$	2.97	$	2.62
	Outstanding Shares Excluded from the Calculation
	of Diluted EPS Attributable to:
	Restricted stock and stock units subject to	0.3		0.2		0.3		0.2
	performance and/or market conditions

FINANCING_Tables

FINANCING (Tables)	9 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Schedule of Company's Equity Units	'
	Selected information about the Company’s Equity Units is presented below:
	Issuance Date	Units Issued (Millions)	Total Net Proceeds		Total Long-term Debt		RSN Annual Interest Rate		Stock Purchase Contract Annual Rate		Stock Purchase Contract Liability
	6/11/14	2.875	$	139.4	$	143.8	2	%	4.75	%	$	19.7

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Jun. 30, 2014
Financial Instruments, Owned, at Fair Value [Abstract]	'
Fair value - financial instruments	'
	The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for the Company are as follows:
						Classification of Estimated Fair Value
		Carrying		Fair		Quoted		Significant Observable Inputs		Significant Unobservable Inputs
		Amount		Value		Prices in Active Markets		(Level 2)		(Level 3)
						(Level 1)
	As of June 30, 2014
	Cash and cash equivalents	$	571.8	$	571.8	$	250.4	$	321.4	$	—
	Short-term debt	—		—		—		—		—
	Long-term debt	976.6		1,044.00		—		1,044.00		—
	As of September 30, 2013
	Cash and cash equivalents	$	53	$	53	$	52.8	$	0.2	$	—
	Short-term debt	74		74		—		74		—
	Long-term debt	912.7		954.1		—		954.1		—
	The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for the Utility are as follows:
						Classification of Estimated Fair Value
		Carrying		Fair		Quoted		Significant Observable Inputs		Significant Unobservable Inputs
		Amount		Value		Prices in Active Markets		(Level 2)		(Level 3)
						(Level 1)
	As of June 30, 2014
	Cash and cash equivalents	$	6	$	6	$	6	$	—	$	—
	Short-term debt	126.9		126.9		—		126.9		—
	Long-term debt	807.9		876.2		—		876.2		—
	As of September 30, 2013
	Cash and cash equivalents	$	23.9	$	23.9	$	23.9	$	—	$	—
	Short-term debt	120.7		120.7		—		120.7		—
	Long-term debt	887.7		930.4		—		930.4		—

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Measured on Recurring Basis	'
	The following table for the Company categorizes the assets and liabilities in the Condensed Consolidated Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition:
		Quoted		Significant		Significant		Effects of Netting and Cash Margin Receivables			Total
		Prices in		Observable		Unobservable		/Payables
		Active		Inputs		Inputs
		Markets		(Level 2)		(Level 3)
		(Level 1)
	As of June 30, 2014
	ASSETS
	Gas Utility
	U. S. Stock/Bond Mutual Funds	$	16.7	$	2.9	$	—	$	—		$	19.6
	Natural gas contracts	5.2		3.2		—		(0.5		)	7.9
	Gasoline and heating oil contracts	0.1		—		—		—			0.1
	Subtotal	22		6.1		—		(0.5		)	27.6
	Gas Marketing
	Natural gas contracts	0.8		5		0.8		(2.0		)	4.6
	Total	$	22.8	$	11.1	$	0.8	$	(2.5	)	$	32.2
	LIABILITIES
	Gas Utility
	Natural gas contracts	$	4	$	0.9	$	—	$	(4.7	)	$	0.2
	Gas Marketing
	Natural gas contracts	0.8		1.3		—		(2.0		)	0.1
	Other
	Interest Rate Swaps	—		10.5		—		—			10.5
	Total	$	4.8	$	12.7	$	—	$	(6.7	)	$	10.8
	As of September 30, 2013
	ASSETS
	Gas Utility
	U. S. Stock/Bond Mutual Funds	$	14.5	$	—	$	—	$	—		$	14.5
	Natural gas contracts	1.5		0.2		—		(1.7		)	—
	Gasoline and heating oil contracts	0.1		—		—		(0.1		)	—
	Subtotal	16.1		0.2		—		(1.8		)	14.5
	Gas Marketing
	Natural gas contracts	2.8		1.5		0.2		(1.2		)	3.3
	Total	$	18.9	$	1.7	$	0.2	$	(3.0	)	$	17.8
	LIABILITIES
	Gas Utility
	Natural gas contracts	$	3.5	$	5.4	$	—	$	(3.7	)	$	5.2
	Gas Marketing
	Natural gas contracts	0.2		1.5		—		(1.0		)	0.7
	Total	$	3.7	$	6.9	$	—	$	(4.7	)	$	5.9

DERIVATIVE_INSTRUMENTS_AND_HED1

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)	9 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments and Hedging Activities	'
	Open NYMEX/ICE and OTCBB natural gas futures and swap positions at June 30, 2014 were as follows:
		Gas Utility							Gas Marketing
		MMBtu			Avg. Price				MMBtu		Avg. Price
		(millions)			Per				(millions)		Per
					MMBtu						MMBtu
	NYMEX/ICE Open short futures positions
	Fiscal 2014	—			$	—			3.09		$	4.45
	Fiscal 2015	—			—				3.15		4.63
	Fiscal 2016	—			—				0.05		4.22
	NYMEX/ICE Open long futures positions
	Fiscal 2014	1.71			$	3.82			1.39		$	4.5
	Fiscal 2015	0.94			3.84				3.05		4.53
	Fiscal 2016	—			—				0.2		4.2
	Fiscal 2017	—			—				0.02		4.28
	ICE Open long basis swap positions
	Fiscal 2014	—			$	—			3.45		$	0.38
	Fiscal 2015	—			—				1.16		0.38
	Fiscal 2016	—			—				2.75		0.58
	Fiscal 2017	—			—				6.87		0.5
	Fiscal 2018	—			—				1.09		0.5
	ICE Open short basis swap positions
	Fiscal 2014	—			$	—			2.62		$	0.02
	Fiscal 2015	—			—				0.62		0.09
	OTCBB Open long futures positions
	Fiscal 2014	3.85			$	4.06			—		$	—
	Fiscal 2015	15.62			4.29				—		—
	Fiscal 2016	1.78			4.27				—		—
The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income	'
	The Effect of Derivative Instruments on the Statements of Condensed Consolidated Income and Statements of Condensed Consolidated Comprehensive Income
		Location of Gain (Loss)	Three Months Ended June 30,							Nine Months Ended June 30,
		Recorded in Income	2014				2013			2014			2013
	Derivatives in Cash Flow Hedging Relationships
	Effective portion of gain (loss) recognized in OCI on derivatives:
	Gas Marketing natural gas contracts		$	0.1			$	5.5		$	(5.1	)	$	3.6
	Gas Utility gasoline and heating oil contracts		—				(0.1		)	0.1			0.1
	Interest rate swaps		(10.5		)		22.2			(10.5		)	17.7
	Total		$	(10.4	)		$	27.6		$	(15.5	)	$	21.4
	Effective portion of gain (loss) reclassified from AOCI to income:
	Natural gas contracts	Gas Marketing Operating Revenues	$	(1.1	)		$	(1.5	)	$	(4.6	)	$	(3.1	)
		Gas Marketing Operating Expenses	0.3				0.2			1.7			(0.5		)
	Sub-total		(0.8		)		(1.3		)	(2.9		)	(3.6		)
	Gasoline and heating oil contracts	Gas Utility Other Operations and Maintenance Expenses	—				—			0.1			0.1
	Total		$	(0.8	)		$	(1.3	)	$	(2.8	)	$	(3.5	)
	Ineffective portion of gain (loss) on derivatives recognized in income:
	Natural gas contracts	Gas Marketing Operating Revenues	$	—			$	—		$	(0.1	)	$	(0.4	)
		Gas Marketing Operating Expenses	—				—			0.1			(0.2		)
	Sub-total		—				—			—			(0.6		)
	Gasoline and heating oil contracts	Gas Utility Other Operations and Maintenance Expenses	—				—			—			(0.1		)
	Total		$	—			$	—		$	—		$	(0.7	)
	Derivatives Not Designated as Hedging Instruments *
	Gain (loss) recognized in income on derivatives:
	Natural gas contracts	Gas Marketing Operating Revenues	$	(3.2	)		$	0.2		$	12.9		$	0.4
	Total		$	(3.2	)		$	0.2		$	12.9		$	0.4
	*	Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Utility’s PGA Clause and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Consolidated Income. Such amounts are recognized in the Statements of Consolidated Income as a component of Gas Utility Natural and Propane Gas operating expenses when they are recovered through the PGA Clause and reflected in customer billings.
	Fair Value of Derivative Instruments in the Condensed Consolidated Balance Sheet at June 30, 2014
		Asset Derivatives*					Liability Derivatives*
		Balance Sheet Location	Fair				Balance Sheet Location	Fair
			Value					Value
	Derivatives designated as hedging instruments
	Gas Utility:
	Gasoline and heating oil contracts	Prepayments and other	$	0.1			Prepayments and other	$	—
	Gas Marketing:
	Natural gas contracts	Prepayments and other	0.8				Prepayments and other	0.5
		Deferred Charges - Other	0.3				Deferred Charges - Other	0.4
	Other:
	Interest rate swaps	Current Liabilities - Other	—				Current Liabilities - Other	10.5
	Sub-total		1.2					11.4
	Derivatives not designated as hedging instruments
	Gas Utility:
	Natural gas contracts	Prepayments and other	8.4				Prepayments and other	4.7
		Accounts Receivable – Other	4.2				Accounts Receivable – Other	—
		Deferred Charges - Other	—				Deferred Charges - Other	0.2
	Sub-total		12.6					4.9
	Gas Marketing:
	Natural gas contracts	Prepayments and other	3.5				Prepayments and other	0.9
		Deferred Charges - Other	1.9				Deferred Charges - Other	0.2
		Current Liabilities - Other	—				Current Liabilities - Other	0.1
	Sub-total		5.4					1.2
	Total derivatives		$	19.2				$	17.5
	Fair Value of Derivative Instruments in the Condensed Consolidated Balance Sheet at September 30, 2013
		Asset Derivatives*					Liability Derivatives*
		Balance Sheet Location	Fair			*	Balance Sheet Location	Fair
			Value					Value
	Derivatives designated as hedging instruments
	Gas Utility:
	Gasoline and heating oil contracts	Accounts Receivable – Other	$	0.1			Accounts Receivable – Other	$	—
	Gas Marketing:
	Natural gas contracts	Prepayments and other	2.2				Prepayments and other	0.5
	Sub-total		2.3					0.5
	Derivatives not designated as hedging instruments
	Gas Utility:
Natural gas contracts	Accounts Receivable – Other	1.5				Accounts Receivable – Other	3.5
	Current Liabilities - Other	0.2				Current Liabilities - Other	4
	Deferred Credits and Other Liabilities - Other	—				Deferred Credits and Other Liabilities - Other	1.4
Sub-total		1.7					8.9
Gas Marketing:
Natural gas contracts	Prepayments and other	1.9				Prepayments and other	0.2
	Current Liabilities - Other	0.2				Current Liabilities - Other	0.8
	Deferred Charges - Other	0.2				Deferred Charges - Other	0.1
	Deferred Credits and Other Liabilities - Other	—				Deferred Credits and Other Liabilities - Other	0.1
Sub-total		2.3					1.2
Total derivatives		$	6.3				$	10.6
Fair Value of Derivative Instruments in the Consolidated Balance Sheet	'
	Fair Value of Derivative Instruments in the Condensed Consolidated Balance Sheet at June 30, 2014
		Asset Derivatives*					Liability Derivatives*
		Balance Sheet Location	Fair				Balance Sheet Location	Fair
			Value					Value
	Derivatives designated as hedging instruments
	Gas Utility:
	Gasoline and heating oil contracts	Prepayments and other	$	0.1			Prepayments and other	$	—
	Gas Marketing:
	Natural gas contracts	Prepayments and other	0.8				Prepayments and other	0.5
		Deferred Charges - Other	0.3				Deferred Charges - Other	0.4
	Other:
	Interest rate swaps	Current Liabilities - Other	—				Current Liabilities - Other	10.5
	Sub-total		1.2					11.4
	Derivatives not designated as hedging instruments
	Gas Utility:
	Natural gas contracts	Prepayments and other	8.4				Prepayments and other	4.7
		Accounts Receivable – Other	4.2				Accounts Receivable – Other	—
		Deferred Charges - Other	—				Deferred Charges - Other	0.2
	Sub-total		12.6					4.9
	Gas Marketing:
	Natural gas contracts	Prepayments and other	3.5				Prepayments and other	0.9
		Deferred Charges - Other	1.9				Deferred Charges - Other	0.2
		Current Liabilities - Other	—				Current Liabilities - Other	0.1
	Sub-total		5.4					1.2
	Total derivatives		$	19.2				$	17.5
	Fair Value of Derivative Instruments in the Condensed Consolidated Balance Sheet at September 30, 2013
		Asset Derivatives*					Liability Derivatives*
		Balance Sheet Location	Fair			*	Balance Sheet Location	Fair
			Value					Value
	Derivatives designated as hedging instruments
	Gas Utility:
	Gasoline and heating oil contracts	Accounts Receivable – Other	$	0.1			Accounts Receivable – Other	$	—
	Gas Marketing:
	Natural gas contracts	Prepayments and other	2.2				Prepayments and other	0.5
	Sub-total		2.3					0.5
	Derivatives not designated as hedging instruments
	Gas Utility:
	Natural gas contracts	Accounts Receivable – Other	1.5				Accounts Receivable – Other	3.5
		Current Liabilities - Other	0.2				Current Liabilities - Other	4
		Deferred Credits and Other Liabilities - Other	—				Deferred Credits and Other Liabilities - Other	1.4
	Sub-total		1.7					8.9
	Gas Marketing:
	Natural gas contracts	Prepayments and other	1.9				Prepayments and other	0.2
		Current Liabilities - Other	0.2				Current Liabilities - Other	0.8
		Deferred Charges - Other	0.2				Deferred Charges - Other	0.1
		Deferred Credits and Other Liabilities - Other	—				Deferred Credits and Other Liabilities - Other	0.1
	Sub-total		2.3					1.2
	Total derivatives		$	6.3				$	10.6
	*	The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Consolidated Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Company’s net economic exposure. Refer to Note 7, Fair Value Measurements, for information on the valuation of derivative instruments.
Derivative Instrument Reconciliation	'
	Following is a reconciliation of the amounts in the tables above to the amounts presented in the Condensed Consolidated    Balance Sheets:
		30-Jun-14				30-Sep-13
	Fair value of asset derivatives presented above:	$	19.2			$	6.3
	Fair value of cash margin receivables offset with derivatives	—				1.7
	Netting of assets and liabilities with the same counterparty	(6.7		)		(4.7		)
	Total	$	12.5			$	3.3
	Derivative Instrument Assets, per Balance Sheets:
	Prepayments and other	$	11.9			$	3.3
	Deferred Charges - Other	0.6				—
	Total	$	12.5			$	3.3
	Fair value of liability derivatives presented above	$	17.5			$	10.6
	Fair value of cash margin payables offset with derivatives	—				—
	Netting of assets and liabilities with the same counterparty	(6.7		)		(4.7		)
	Total	$	10.8			$	5.9
	Derivative Instrument Liabilities, per Balance Sheets:
	Current Liabilities - Other	$	10.6			$	4.4
	Deferred Credits and Other Liabilities - Other	0.2				1.5
	Total	$	10.8			$	5.9

PENSION_PLANS_AND_OTHER_POSTRE1

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS (Tables)	9 Months Ended
	Jun. 30, 2014
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'
Net Periodic Cost	'
	Net periodic postretirement benefit costs consisted of the following components:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Service cost – benefits earned during the period	$	2.8		$	2.5		$	8.4		$	7.6
	Interest cost on accumulated postretirement benefit obligation	2.1			1.2			6.5			3.8
	Expected return on plan assets	(1.7		)	(1.0		)	(5.1		)	(3.2		)
	Amortization of transition obligation	—			0.1			—			0.1
	Amortization of prior service cost (credit)	—			—			—			—
	Amortization of actuarial loss	1.5			1.2			4.5			3.9
	Sub-total	4.7			4			14.3			12.2
	Regulatory adjustment	(2.4		)	(1.7		)	(7.2		)	(5.1		)
	Net postretirement benefit cost	$	2.3		$	2.3		$	7.1		$	7.1
	The net periodic pension costs include the following components:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Service cost – benefits earned during the period	$	2.4		$	2.3		$	7.3		$	6.9
	Interest cost on projected benefit obligation	6			4.1			18			12.2
	Expected return on plan assets	(6.6		)	(4.7		)	(19.9		)	(14.2		)
	Amortization of prior service cost	0.2			0.1			0.4			0.4
	Amortization of actuarial loss	1.8			2.8			5.3			8.5
	Loss on lump-sum settlement	—			12.3			1.3			12.3
	Sub-total	3.8			16.9			12.4			26.1
	Regulatory adjustment	2.9			(12.7		)	7.4			(13.6		)
	Net pension cost	$	6.7		$	4.2		$	19.8		$	12.5

INFORMATION_BY_OPERATING_SEGME1

INFORMATION BY OPERATING SEGMENT (Tables)	9 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Schedule of operating segment information	'
	Laclede Group	Gas Utility			Gas Marketing			Other			Eliminations			Consolidated
	Three Months Ended June 30, 2014
	Revenues from external customers	$	214		$	27.1		$	0.7		$	—		$	241.8
	Intersegment revenues	0.2			27.9			0.5			(28.6		)	—
	Total Operating Revenues	214.2			55			1.2			(28.6		)	241.8
	Operating Expenses
	Gas Utility
	Natural and propane gas	77.6			—			—			(28.3		)	49.3
	Other operation and maintenance	73.3			—			—			(0.3		)	73
	Depreciation and amortization	18.4			—			—			—			18.4
	Taxes, other than income taxes	22.2			—			—			—			22.2
	Total Gas Utility Operating Expenses	191.5			—			—			(28.6		)	162.9
	Gas Marketing	—			50			—			—			50
	Other	—			—			4.2			—			4.2
	Total Operating Expenses	191.5			50			4.2			(28.6		)	217.1
	Operating Income	$	22.7		$	5		$	(3.0	)	$	—		$	24.7
	Net Economic Earnings (Losses)	$	13.3		$	1.9		$	(0.7	)	$	—		$	14.5
	Three Months Ended June 30, 2013
	Revenues from external customers	$	131.5		$	33.4		$	0.4		$	—		$	165.3
	Intersegment revenues	—			9.4			0.7			(10.1		)	—
	Total Operating Revenues	131.5			42.8			1.1			(10.1		)	165.3
	Operating Expenses
	Gas Utility
	Natural and propane gas	52.8			—			—			(9.6		)	43.2
	Other operation and maintenance	42.2			—			—			0.3			42.5
	Depreciation and amortization	11.5			—			—			—			11.5
	Taxes, other than income taxes	12.9			—			—			—			12.9
	Total Gas Utility Operating Expenses	119.4			—			—			(9.3		)	110.1
	Gas Marketing	—			40.6			—			—			40.6
	Other	—			—			3.1			(0.8		)	2.3
	Total Operating Expenses	119.4			40.6			3.1			(10.1		)	153
	Operating Income	$	12.1		$	2.2		$	(2.0	)	$	—		$	12.3
	Net Economic Earnings	$	6.8		$	1.6		$	(0.2	)	$	—		$	8.2
	Laclede Group	Gas Utility			Gas Marketing			Other			Eliminations			Consolidated
	Nine Months Ended June 30, 2014
	Revenues from external customers	$	1,283.60		$	120.2		$	1.1		$	—		$	1,404.90
	Intersegment revenues	4.5			68			1.5			(74.0		)	—
	Total Operating Revenues	1,288.10			188.2			2.6			(74.0		)	1,404.90
	Operating Expenses
	Gas Utility
	Natural and propane gas	769.7			—			—			(73.3		)	696.4
	Other operation and maintenance	208			—			—			(0.7		)	207.3
	Depreciation and amortization	58.5			—			—			—			58.5
	Taxes, other than income taxes	92.6			—			—			—			92.6
	Total Gas Utility Operating Expenses	1,128.80			—			—			(74.0		)	1,054.80
	Gas Marketing	—			166.8			—			—			166.8
	Other	—			—			8.5			—			8.5
	Total Operating Expenses	1,128.80			166.8			8.5			(74.0		)	1,230.10
	Operating Income	$	159.3		$	21.4		$	(5.9	)	$	—		$	174.8
	Net Economic Earnings (Losses)	$	93.8		$	9.8		$	(1.1	)	$	—		$	102.5
	Nine Months Ended June 30, 2013
	Revenues from external customers	$	735.7		$	129.9		$	4.3		$	—		$	869.9
	Intersegment revenues	10.5			14			1.1			(25.6		)	—
	Total Operating Revenues	746.2			143.9			5.4			(25.6		)	869.9
	Operating Expenses
	Gas Utility
	Natural and propane gas	435.3			—			—			(25.1		)	410.2
	Other operation and maintenance	123			—			—			0.3			123.3
	Depreciation and amortization	33.7			—			—			—			33.7
	Taxes, other than income taxes	49.5			—			—			—			49.5
	Total Gas Utility Operating Expenses	641.5			—			—			(24.8		)	616.7
	Gas Marketing	—			134			—			—			134
	Other	—			—			13.8			(0.8		)	13
Total Operating Expenses	641.5			134			13.8			(25.6		)	763.7
Operating Income	$	104.7		$	9.9		$	(8.4	)	$	—		$	106.2
Net Economic Earnings	$	62.3		$	7.3		$	(0.7	)	$	—		$	68.9
The Company's total asset detail is as follows:
	June 30,			September 30,
Laclede Group	2014			2013
Total Assets:
Gas Utility	$	2,976.50		$	2,981.00
Gas Marketing	185.8			163.9
Other	989			115.6
Eliminations	(494.6		)	(135.1		)
Total Assets	$	3,656.70		$	3,125.40
Laclede Gas	Gas Utility			Other			Adjustments & Eliminations			Total
Three Months Ended June 30, 2014
Operating revenues	$	214.2		$	—		$	—		$	214.2
Net Economic Earnings	13.3			(0.1		)	—			13.2
Nine Months Ended June 30, 2014
Operating revenues	$	1,288.10		$	0.1		$	—		$	1,288.20
Net Economic Earnings	93.8			(0.1		)	—			93.7
Three Months Ended June 30, 2013
Operating revenues	$	131.5		$	0.2		$	—		$	131.7
Net Economic Earnings	6.8			(0.1		)	—			6.7
Nine Months Ended June 30, 2013
Operating revenues	$	746.2		$	1.6		$	—		$	747.8
Net Economic Earnings	62.3			0.7			—			63
The Utility's total asset detail is as follows:
	June 30,			September 30,
Laclede Gas	2014			2013
Total Assets:
Gas Utility	$	2,976.50		$	2,981.00
Other	—			—
Total Assets	$	2,976.50		$	2,981.00
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 Income (Non-GAAP):
		Three Months Ended June 30,						Nine Months Ended June 30,
	Laclede Group	2014			2013			2014			2013
	Net income (GAAP)	$	11.7		$	6.6		$	99.5		$	62.4
	Unrealized (gain) loss on energy-related derivative contracts	(1.0		)	(0.3		)	(2.3		)	0.6
	Lower of cost or market inventory adjustments	(0.1		)	0.5			(0.7		)	0.6
	Realized (gain) loss on economic hedges prior to sale of the physical commodity	—			—			(0.1		)	—
	Acquisition, divestiture and restructuring activities	3.9			1.4			6.1			5.3
	Net Economic Earnings (Non-GAAP)	$	14.5		$	8.2		$	102.5		$	68.9
	The following table reconciles the Utility's Net Income (GAAP) to Net Economic Income (Non-GAAP):
		Three Months Ended June 30,						Nine Months Ended June 30,
	Laclede Gas	2014			2013			2014			2013
	Net Income (GAAP)	$	12		$	3.8		$	91.5		$	59.3
	Unrealized (gain) loss on energy-related derivative contracts	—			—			—			0.1
	Acquisition, divestiture and restructuring activities	1.2			2.9			2.2			3.6
	Net Economic Earnings (Non-GAAP)	$	13.2		$	6.7		$	93.7		$	63

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2013
			Operating_Segment
Related Party Transaction [Line Items]	'	'	'	'	'
Number of operating segments	'	'	3	'	'
Accrued unbilled revenue	$32.40	'	$32.40	'	$25.20
Gross Receipts taxes recorded in gas utility operating revenues	13.7	7.8	67.9	35.3	'
Gas Utility | Affiliated Entity	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Transportation services costs	0.3	0.3	0.8	0.8	'
Revolving Credit Facility	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Notes Receivable, Related Parties	126.9	'	126.9	'	46.7
Interest rate on revolving credit note	'	'	0.30%	'	'
Non-Regulated Gas Marketing | Gas Marketing | Affiliated Entity	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Intersegment revenues	0.2	0	4.5	10.5	'
Regulated Operation | Gas Utility | Affiliated Entity	'	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'	'
Intersegment revenues	$28.10	$9.40	$72.50	$24.50	'

SUMMARY_OF_SIGNIFICANT_ACCOUNT4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Regulatory Assets and Liabilities (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013
In Millions, unless otherwise specified
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (non-current)	$540	$545.90
Total Regulatory Assets (current)	540.2	563.4
Regulatory Liabilities	90.1	85.5
Unamortized investment tax credits	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Regulatory Liabilities	2.7	2.9
Accrued cost of removal	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Regulatory Liabilities	58.9	59.1
Other	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Regulatory Liabilities	28.5	23.5
Future income taxes due from customers	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (non-current)	119.3	112.9
Pension and postretirement benefit costs	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (non-current)	328.7	381.4
Purchased gas costs	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (non-current)	16.6	18.2
Compensated absences	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (non-current)	8.1	8
Other	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (non-current)	67.3	25.4
Unamortized purchased gas adjustments (current)	'	'
Schedule of Regulatory Assets and Liabilities[Line Items]	'	'
Total Regulatory Assets (current)	$0.20	$17.50

ACQUISITIONS_Missouri_Gas_Ener

ACQUISITIONS - Missouri Gas Energy (Details) (USD $)	3 Months Ended	9 Months Ended				0 Months Ended		9 Months Ended		0 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2013	Sep. 01, 2013	Feb. 14, 2014	Sep. 01, 2013	Jun. 30, 2014	Feb. 14, 2014	Dec. 20, 2013
					Missouri Gas Energy (MGE)	Laclede Group	Laclede Group	Gas Utility	Gas Utility	Gas Utility
						Missouri Gas Energy (MGE)	Missouri Gas Energy (MGE)	Missouri Gas Energy (MGE)	Missouri Gas Energy (MGE)	Laclede Group
										Missouri Gas Energy (MGE)
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'
Payments to acquired businesses	'	'	'	'	'	'	$975	'	'	'
Fair value adjustment of assets	'	'	'	'	'	23.9	'	'	'	'
Proceeds from final reconciliation of acquisition of Missouri Gas Energy	'	23.9	0	'	'	'	'	'	'	11
Total consideration transferred	'	'	'	'	'	'	'	940.1	'	'
Goodwill	210	210	'	247.1	210	'	'	'	247.1	'
Other regulated operating revenue	$87.30	$484	'	'	'	'	'	'	'	'

ACQUISITIONS_Schedule_of_preli

ACQUISITIONS - Schedule of preliminary fair value of assets and liabilities (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Sep. 01, 2013
In Millions, unless otherwise specified			Missouri Gas Energy (MGE)
Business Acquisition [Line Items]	'	'	'
Utility plant	'	'	$671.10
Goodwill	210	247.1	210
Other property and investments	'	'	3.3
Total Other Property and Investments	'	'	884.4
Accounts receivable	'	'	35.5
Inventories	'	'	62.7
Prepaid and other	'	'	0.3
Total Current Assets	'	'	98.5
Deferred charges	'	'	95.7
Total Assets Acquired	'	'	1,078.60
Current liabilities	'	'	65.7
Deferred credits and other liabilities	'	'	72.8
Total Liabilities Assumed	'	'	138.5
Net Assets Acquired	'	'	$940.10

ACQUISITIONS_Alabama_Gas_Corpo

ACQUISITIONS - Alabama Gas Corporation (Details) (USD $)	1 Months Ended	9 Months Ended		0 Months Ended		0 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Apr. 05, 2014	Jun. 11, 2014	Apr. 05, 2014	Jun. 11, 2014	Jul. 22, 2014
				Alabama Gas Corporation	Bridge Loan	Bridge Loan	IPO	Subsequent Event
				customer	Bridge Lenders	Bridge Lenders		Alabama Public Service Commission
						Alabama Gas Corporation
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'
Percentage of common stock acquired	'	'	'	100.00%	'	'	'	'
Number of customers acquired	'	'	'	422,000	'	'	'	'
Public Utilities, Number of Days to Appeal	'	'	'	'	'	'	'	'30 days
Total stated purchase price	'	'	'	$1,600,000,000	'	'	'	'
Expected payments to acquire businesses	'	'	'	1,350,000,000	'	'	'	'
Long-term debt assumed in business acquisition	'	'	'	250,000,000	'	'	'	'
Business combination bridge loan incurred	'	'	'	'	'	1,350,000,000	'	'
Issuance of common stock	478,700,000	459,700,000	431,300,000	'	'	'	600,000,000	'
Maximum borrowing capacity on bridge loan	'	'	'	'	$700,000,000	'	'	'

STOCKBASED_COMPENSATION_Detail

STOCK-BASED COMPENSATION (Details) (USD $)	9 Months Ended
	Jun. 30, 2014
Restricted Stock Awards	'
Restricted Stock Awards [Abstract]	'
Vested (in shares)	70,953
Vested restricted stock withheld for tax withholding obligations (in shares)	22,983
Vested restricted stock withheld for tax withholding obligations, weighted average price (in dollars per share)	$45.83
Executive Officers and Key Employees | Performance vesting | Restricted Stock Units (RSUs)	'
Restricted Stock Awards [Abstract]	'
Granted (in shares)	125,727
Granted, weighted average grant date fair value (per share)	$37.21
Executive Officers and Key Employees | Time vesting | Restricted Stock Awards	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Shares to vest on July 14, 2014	15,200
Shares to vest on December 2, 2014	12,168
Shares to vest during fiscal 2017	46,400
Restricted Stock Awards [Abstract]	'
Granted (in shares)	73,768
Granted, weighted average grant date fair value (per share)	$45.68

EARNINGS_PER_COMMON_SHARE_Deta

EARNINGS PER COMMON SHARE (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Basic EPS [Abstract]	'	'	'	'
Net Income	$11.70	$6.60	$99.50	$62.40
Less: Income allocated to participating securities	0	0.1	0.4	0.4
Net Income Available to Common Shareholders, Basic	11.7	6.5	99.1	62
Weighted Average Shares Outstanding, Basic	34.9	26.1	33.3	23.6
Earnings Per Share of Common Stock, Basic (Per Share)	$0.34	$0.25	$2.97	$2.62
Diluted EPS [Abstract]	'	'	'	'
Net Income	11.7	6.6	99.5	62.4
Less: Income allocated to participating securities	0	0.1	0.4	0.4
Net Income Available to Common Stockholders, Diluted	$11.70	$6.50	$99.10	$62
Weighted Average Shares Outstanding, Basic	34.9	26.1	33.3	23.6
Dilutive Effect of Stock Options, Restricted Stock and Restricted Stock Units	0.1	0.1	0.1	0.1
Weighted Average Diluted Shares	35	26.2	33.4	23.7
Earnings Per Share of Common Stock, Diluted (Per share)	$0.33	$0.25	$2.97	$2.62
Performance Contingent Restricted Stock and Stock Units	'	'	'	'
Outstanding Shares Excluded from the Calculation of Diluted EPS Attributable to:	'	'	'	'
Outstanding shares excluded from the calculation of diluted EPS	0.3	0.2	0.3	0.2

FINANCING_Details

FINANCING (Details) (USD $)

1 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

Share data in Millions, except Per Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 11, 2014

Sep. 30, 2013

Jun. 30, 2014

Apr. 30, 2017

Apr. 30, 2017

Jun. 30, 2014

Jun. 30, 2013

Sep. 30, 2013

Equity_Security

Junior Subordinated Debt

Minimum

Maximum

Laclede Gas Company

Laclede Gas Company

Laclede Gas Company

Scenario, Forecast

Scenario, Forecast

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest in subordinated notes

'

'

'

'

5.00%

'

'

'

'

'

'

'

Taxes accrued

$56,100,000

$56,100,000

$56,100,000

'

'

$32,900,000

'

'

'

$53,200,000

'

$32,600,000

Interest rate on subordinated borrowing (percent)

2.00%

2.00%

'

'

'

'

'

'

'

'

'

'

Issuance of common stock

'

478,700,000

459,700,000

431,300,000

'

'

'

'

'

1,200,000

1,900,000

'

Number of shares to be issued

10.4

10.4

'

'

'

'

'

2.5

3.1

'

'

'

Number of equity convertible equity units issued

0

2,875,000

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of interest in corporate unit

'

139,400,000

'

'

'

'

'

'

'

'

'

'

Issuance of long-term debt

'

'

143,800,000

125,000,000

'

'

143,800,000

'

'

'

'

'

Common Stock Par Value (in dollars per share)

$1

$1

$1

'

'

$1

'

'

'

$1

'

$1

Capital shares reserved for future issuance

4.2

4.2

4.2

'

'

'

'

'

'

'

'

'

RSN annual interest rate (in percent)

'

'

'

'

'

'

2.00%

'

'

'

'

'

Stock purchase contract annual rate (percent)

4.75%

4.75%

'

'

'

'

'

'

'

'

'

'

Stock purchase contract liability

'

19,700,000

'

'

'

'

'

'

'

'

'

'

Equity unit, stated value per unit

$50

$50

$50

'

'

'

'

'

'

'

'

'

Stated principal amount on subordinated notes

'

'

'

'

$1,000

'

'

'

'

'

'

'

FAIR_VALUE_OF_FINANCIAL_INSTRU2

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013	Sep. 30, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	$571.80	$53	$556.50	$27.50
Carrying Amount	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	571.8	53	'	'
Short-term debt	0	74	'	'
Long-term debt, including current portion	976.6	912.7	'	'
Fair Value	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	571.8	53	'	'
Short-term debt	0	74	'	'
Long-term debt, including current portion	1,044	954.1	'	'
Laclede Gas Company	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	6	23.9	28.8	2.4
Laclede Gas Company | Carrying Amount	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	6	23.9	'	'
Short-term debt	126.9	120.7	'	'
Long-term debt, including current portion	807.9	887.7	'	'
Laclede Gas Company | Fair Value	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	6	23.9	'	'
Short-term debt	126.9	120.7	'	'
Long-term debt, including current portion	876.2	930.4	'	'
Quoted Prices in Active Markets (Level 1)	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	250.4	52.8	'	'
Short-term debt	0	0	'	'
Long-term debt, including current portion	0	0	'	'
Quoted Prices in Active Markets (Level 1) | Laclede Gas Company	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	6	23.9	'	'
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	321.4	0.2	'	'
Short-term debt	0	74	'	'
Long-term debt, including current portion	1,044	954.1	'	'
Significant Observable Inputs (Level 2) | Laclede Gas Company	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	0	0	'	'
Short-term debt	126.9	120.7	'	'
Long-term debt, including current portion	876.2	930.4	'	'
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 Company	'	'	'	'
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	'	'

FAIR_VALUE_MEASUREMENTS_Detail

FAIR VALUE MEASUREMENTS (Details) (Fair Value, Measurements, Recurring, USD $)	Jun. 30, 2014	Sep. 30, 2013
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	$10.80	'
Total Liabilities	'	5.9
Quoted Prices in Active Markets (Level 1)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	4.8	'
Total Liabilities	'	3.7
Significant Observable Inputs (Level 2)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	12.7	'
Total Liabilities	'	6.9
Significant Unobservable Inputs (Level 3)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	0	'
Total Liabilities	'	0
Effects of Netting and Cash Margin Receivables /Payables	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	-6.7	'
Total Liabilities	'	-4.7
Gas Utility	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	19.6	14.5
Natural gas contracts	7.9	0
Gasoline and heating oil contracts	0.1	0
Total Assets	27.6	14.5
Natural gas contracts	0.2	5.2
Gas Utility | Quoted Prices in Active Markets (Level 1)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	16.7	14.5
Natural gas contracts	5.2	1.5
Gasoline and heating oil contracts	0.1	0.1
Total Assets	22	16.1
Natural gas contracts	4	3.5
Gas Utility | Significant Observable Inputs (Level 2)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	2.9	0
Natural gas contracts	3.2	0.2
Gasoline and heating oil contracts	0	0
Total Assets	6.1	0.2
Natural gas contracts	0.9	5.4
Gas Utility | Significant Unobservable Inputs (Level 3)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	0	0
Natural gas contracts	0	0
Gasoline and heating oil contracts	0	0
Total Assets	0	0
Natural gas contracts	0	0
Gas Utility | Effects of Netting and Cash Margin Receivables /Payables	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	0	0
Natural gas contracts	-0.5	-1.7
Gasoline and heating oil contracts	0	-0.1
Total Assets	-0.5	-1.8
Natural gas contracts	-4.7	-3.7
Gas Marketing	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	4.6	3.3
Total Assets	32.2	17.8
Natural gas contracts	0.1	0.7
Gas Marketing | Quoted Prices in Active Markets (Level 1)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	0.8	2.8
Total Assets	22.8	18.9
Natural gas contracts	0.8	0.2
Gas Marketing | Significant Observable Inputs (Level 2)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	5	1.5
Total Assets	11.1	1.7
Natural gas contracts	1.3	1.5
Gas Marketing | Significant Unobservable Inputs (Level 3)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	0.8	0.2
Total Assets	0.8	0.2
Natural gas contracts	0	0
Gas Marketing | Effects of Netting and Cash Margin Receivables /Payables	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	-2	-1.2
Total Assets	-2.5	-3
Natural gas contracts	-2	-1
Other	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	10.5	'
Other | Quoted Prices in Active Markets (Level 1)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	0	'
Other | Significant Observable Inputs (Level 2)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	10.5	'
Other | Significant Unobservable Inputs (Level 3)	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	0	'
Other | Effects of Netting and Cash Margin Receivables /Payables	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Natural gas contracts	$0	'

DERIVATIVE_INSTRUMENTS_AND_HED2

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Narratives (Details) (USD $)	3 Months Ended					9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2014	Jul. 08, 2014	Jul. 08, 2014
	MMBTU		Designated as Hedging Instrument	Minimum	Maximum	Laclede Gas Company	Laclede Gas Company	Fuel	Subsequent Event	Subsequent Event
			Interest Rate Swap	Designated as Hedging Instrument	Designated as Hedging Instrument	gal		Laclede Gas Company	Minimum	Maximum
			Cash Flow Hedging	Interest Rate Swap	Interest Rate Swap	MMBTU			Designated as Hedging Instrument	Designated as Hedging Instrument
				Cash Flow Hedging	Cash Flow Hedging				Interest Rate Swap	Interest Rate Swap
									Cash Flow Hedging	Cash Flow Hedging
Derivative [Line Items]	'	'	'	'	'	'	'	'	'	'
Maximum percentage of normal volumes hedged	'	'	'	'	'	70.00%	'	'	'	'
Hedging Volume Normal Percentage Period Maximum	'	'	'	'	'	'36 months	'	'	'	'
Derivative Nonmonetary Notional Amount Gasoline	'	'	'	'	'	200,000	'	'	'	'
Average price of gasoline futures contracts (dollars per gallon)	'	'	'	'	'	'	'	2.71	'	'
Nonmonetary Notional Amount Of Natural Gas Derivative Contracts Not Designated As Normal Purchases Or Normal Sales	63,000,000	'	'	'	'	'	'	'	'	'
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2014 (in MMBtu)	39,000,000	'	'	'	'	'	'	'	'	'
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2015 (in MMBtu)	22,600,000	'	'	'	'	'	'	'	'	'
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2016 (in MMBtu)	1,400,000	'	'	'	'	'	'	'	'	'
Notional amount	'	'	$375	'	'	'	'	'	'	'
Derivative fixed interest rates	'	'	'	1.89%	3.54%	'	'	'	1.95%	3.56%
Mmbtu	'	'	'	'	'	26,000,000	'	'	'	'
Expected pre-tax unrealized gain (loss) reclassifications into the Statements of Consolidated Income during the twelve months	-0.4	'	'	'	'	0.1	'	'	'	'
Cash margin receivables not offset with derivatives	$2.60	$3.20	'	'	'	$0.90	$2.90	'	'	'

DERIVATIVE_INSTRUMENTS_AND_HED3

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Exchange-Traded/Cleared Derivative (Details)

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Jun. 30, 2014

Mar. 31, 2014

Jun. 30, 2014

Jun. 30, 2014

Laclede Gas Company

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

NYMEX Natural Gas Contracts

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

ICE open basis swap positions

OTCBB Natural Gas Contracts

OTCBB Natural Gas Contracts

OTCBB Natural Gas Contracts

OTCBB Natural Gas Contracts

OTCBB Natural Gas Contracts

OTCBB Natural Gas Contracts

MMBTU

Fiscal 2014

Fiscal 2014

Fiscal 2014

Fiscal 2014

Fiscal 2015

Fiscal 2015

Fiscal 2015

Fiscal 2015

Fiscal 2016

Fiscal 2016

Fiscal 2016

Fiscal 2016

Fiscal 2017

Fiscal 2017

Fiscal 2014

Fiscal 2014

Fiscal 2014

Fiscal 2014

Fiscal 2015

Fiscal 2015

Fiscal 2015

Fiscal 2015

Fiscal 2016

Fiscal 2016

Fiscal 2017

Fiscal 2017

Fiscal 2018

Fiscal 2018

Fiscal 2014

Fiscal 2014

Fiscal 2015

Fiscal 2015

Fiscal 2016

Fiscal 2016

Laclede Gas Company

Laclede Gas Company

Laclede Energy Resources

Laclede Energy Resources

Laclede Gas Company

Laclede Gas Company

Laclede Energy Resources

Laclede Energy Resources

Laclede Gas Company

Laclede Gas Company

Laclede Energy Resources

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Laclede Gas Company

Laclede Gas Company

Laclede Energy Resources

Laclede Energy Resources

Laclede Gas Company

Laclede Gas Company

Laclede Energy Resources

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Laclede Gas Company

Laclede Energy Resources

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Short Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

Open Long Futures Positions

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

MMBTU

Derivative [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Mmbtu

26,000,000

0

1,710,000

3,090,000

1,390,000

0

940,000

3,150,000

3,050,000

0

0

50,000

200,000

0

20,000

0

0

2,620,000

3,450,000

0

0

620,000

1,160,000

0

2,750,000

0

6,870,000

0

1,090,000

3,850,000

0

15,620,000

0

1,780,000

0

Avg. Price Per MMBtu

'

0

3.82

4.45

4.5

0

3.84

4.63

4.53

0

0

4.22

4.2

0

4.28

0

0

0.02

0.38

0

0

0.09

0.38

0

0.58

0

0.5

0

0.5

4.06

0

4.29

0

4.27

0

DERIVATIVE_INSTRUMENTS_AND_HED4

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Gains (Loss) on Derivative Instruments (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	($0.80)	($1.30)	($2.80)	($3.50)
Ineffective portion of gain (loss) on derivatives recognized in income	0	0	0	-0.7
NYMEX Natural Gas Contracts | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	-0.8	-1.3	-2.9	-3.6
Ineffective portion of gain (loss) on derivatives recognized in income	0	0	0	-0.6
NYMEX Natural Gas Contracts | Other Comprehensive Income (Loss) | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) recognized in OCI on derivatives	0.1	5.5	-5.1	3.6
NYMEX Natural Gas Contracts | Non Regulated Gas Marketing Operating Revenue | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	-1.1	-1.5	'	'
Ineffective portion of gain (loss) on derivatives recognized in income	0	0	'	'
NYMEX Natural Gas Contracts | Gas Marketing Operating Revenue | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	'	'	-4.6	-3.1
Ineffective portion of gain (loss) on derivatives recognized in income	'	'	-0.1	-0.4
NYMEX Natural Gas Contracts | Non Regulated Gas Marketing Operating Expenses | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	0.3	0.2	'	'
Ineffective portion of gain (loss) on derivatives recognized in income	0	0	'	'
NYMEX Natural Gas Contracts | Gas Marketing Operating Expenses | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	'	'	1.7	-0.5
Ineffective portion of gain (loss) on derivatives recognized in income	'	'	0.1	-0.2
NYMEX Gasoline and Heating Oil Contracts | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) recognized in OCI on derivatives	-10.4	27.6	-15.5	21.4
NYMEX Gasoline and Heating Oil Contracts | Not Designated as Hedging Instrument	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Gain (loss) recognized in income on derivatives	-3.2	0.2	12.9	0.4
NYMEX Gasoline and Heating Oil Contracts | Other Comprehensive Income (Loss) | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) recognized in OCI on derivatives	0	-0.1	0.1	0.1
NYMEX Gasoline and Heating Oil Contracts | Other Regulated Gas Distribution Operating Expenses | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	0	0	'	'
Ineffective portion of gain (loss) on derivatives recognized in income	0	0	'	'
NYMEX Gasoline and Heating Oil Contracts | Gas Utility Other Operation and Maintenance Expenses | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	'	'	0.1	0.1
Ineffective portion of gain (loss) on derivatives recognized in income	'	'	0	-0.1
Natural Gas Commodity Contracts | Non Regulated Gas Marketing Operating Revenue | Not Designated as Hedging Instrument	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Gain (loss) recognized in income on derivatives	-3.2	0.2	'	'
Natural Gas Commodity Contracts | Gas Marketing Operating Revenue | Not Designated as Hedging Instrument | Not Designated as Hedging Instrument	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Gain (loss) recognized in income on derivatives	'	'	12.9	0.4
Interest Rate Swap | Other Comprehensive Income (Loss) | Designated as Hedging Instrument | Cash Flow Hedging	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Effective portion of gain (loss) recognized in OCI on derivatives	($10.50)	$22.20	($10.50)	$17.70

DERIVATIVE_INSTRUMENTS_AND_HED5

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Fair Value of Derivative Instruments (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	$19.20	$6.30
Fair value of derivative liabilities	17.5	10.6
Gas Utility | NYMEX Natural Gas Contracts | Designated as Hedging Instrument | Prepayments and other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	0.1	'
Fair value of derivative liabilities	0	'
Gas Utility | NYMEX Natural Gas Contracts | Designated as Hedging Instrument | Accounts Receivable – Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	0.1
Fair value of derivative liabilities	'	0
Gas Utility | NYMEX Natural Gas Contracts | Not Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	12.6	'
Fair value of derivative liabilities	4.9	'
Gas Utility | NYMEX Natural Gas Contracts | Not Designated as Hedging Instrument | Prepayments and other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	8.4	'
Fair value of derivative liabilities	4.7	'
Gas Utility | NYMEX Natural Gas Contracts | Not Designated as Hedging Instrument | Deferred Charges - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	0	'
Fair value of derivative liabilities	0.2	'
Gas Utility | NYMEX Natural Gas Contracts | Not Designated as Hedging Instrument | Accounts Receivable – Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	4.2	'
Fair value of derivative liabilities	0	'
Gas Utility | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	1.7
Fair value of derivative liabilities	'	8.9
Gas Utility | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Accounts Receivable – Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	1.5
Fair value of derivative liabilities	'	3.5
Gas Utility | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Current Liabilities - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	0.2
Fair value of derivative liabilities	'	4
Gas Utility | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Deferred Credits and Other Liabilities - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	0
Fair value of derivative liabilities	'	1.4
Gas Marketing | Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	2.3
Fair value of derivative liabilities	'	0.5
Gas Marketing | Not Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	5.4	'
Fair value of derivative liabilities	1.2	'
Gas Marketing | NYMEX Natural Gas Contracts | Designated as Hedging Instrument | Prepayments and other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	0.8	'
Fair value of derivative liabilities	0.5	'
Gas Marketing | NYMEX Natural Gas Contracts | Designated as Hedging Instrument | Deferred Charges - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	0.3	'
Fair value of derivative liabilities	0.4	'
Gas Marketing | Natural Gas Commodity Contracts	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	6.3
Fair value of derivative liabilities	'	10.6
Gas Marketing | Natural Gas Commodity Contracts | Designated as Hedging Instrument | Prepayments and other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	2.2
Fair value of derivative liabilities	'	0.5
Gas Marketing | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	2.3
Fair value of derivative liabilities	'	1.2
Gas Marketing | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Prepayments and other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	3.5	1.9
Fair value of derivative liabilities	0.9	0.2
Gas Marketing | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Deferred Charges - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	1.9	0.2
Fair value of derivative liabilities	0.2	0.1
Gas Marketing | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Current Liabilities - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	0	0.2
Fair value of derivative liabilities	0.1	0.8
Gas Marketing | Natural Gas Commodity Contracts | Not Designated as Hedging Instrument | Deferred Credits and Other Liabilities - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	'	0
Fair value of derivative liabilities	'	0.1
Other | Designated as Hedging Instrument	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	1.2	'
Fair value of derivative liabilities	11.4	'
Other | Interest Rate Swap | Designated as Hedging Instrument | Current Liabilities - Other	'	'
Derivatives, Fair Value [Line Items]	'	'
Fair value of derivative assets	0	'
Fair value of derivative liabilities	$10.50	'

DERIVATIVE_INSTRUMENTS_AND_HED6

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Derivative Instruments Reconciliation (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013
In Millions, unless otherwise specified
Derivative Asset [Abstract]	'	'
Fair value of asset derivatives presented above	$19.20	$6.30
Fair value of cash margin receivables offset with derivatives	0	1.7
Netting of assets and liabilities with the same counterparty	-6.7	-4.7
Total	12.5	3.3
Prepayments and other	11.9	3.3
Deferred Charges - Other	0.6	0
Derivative Liability [Abstract]	'	'
Fair value of liability derivatives presented above	17.5	10.6
Fair value of cash margin payables offset with derivatives	0	0
Total	10.8	5.9
Current Liabilities - Other	10.6	4.4
Deferred Credits and Other Liabilities - Other	0.2	1.5
Laclede Gas Company	'	'
Derivative Asset [Abstract]	'	'
Fair value of asset derivatives presented above	12.7	1.8
Fair value of cash margin receivables offset with derivatives	0	1.9
Netting of assets and liabilities with the same counterparty	-4.7	-3.7
Total	8	0
Prepayments and other	8	0
Deferred Charges - Other	0	0
Derivative Liability [Abstract]	'	'
Fair value of liability derivatives presented above	4.9	8.9
Fair value of cash margin payables offset with derivatives	0	0
Total	0.2	5.2
Current Liabilities - Other	0	5.2
Deferred Credits and Other Liabilities - Other	$0.20	$0

CONCENTRATIONS_OF_CREDIT_RISK_

CONCENTRATIONS OF CREDIT RISK (Details) (USD $)	Jun. 30, 2014
In Millions, unless otherwise specified	counterparty
Concentration Risk [Line Items]	'
Number of investment-grade rated counterparties for which credit risk is disclosed, in terms of net accounts receivable exposure	5
Energy Producers And Their Affiliates	'
Concentration Risk [Line Items]	'
Accounts receivable	16.3
Net receivable amount	9.3
Utility Companies And Their Affiliates	'
Concentration Risk [Line Items]	'
Accounts receivable	34.6
Net receivable amount	29.1
Largest Counterparties	'
Concentration Risk [Line Items]	'
Accounts receivable	30.6
Net receivable amount	24.4

PENSION_PLANS_AND_OTHER_POSTRE2

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Pension Plans (Details) (USD $)	9 Months Ended		3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	1-May-14	Dec. 31, 2010	Feb. 20, 2010
	Qualified Pension Plans	Nonqualified Pension Plans	Pension Plans	Pension Plans	Pension Plans	Pension Plans	Pension Plans	Laclede Gas	Missouri Gas Energy (MGE)
								Pension Plans	Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'	'	'	'	'
Service cost – benefits earned during the period	'	'	$2.40	$2.30	$7.30	$6.90	'	'	'
Interest cost on accumulated postretirement benefit obligation	'	'	6	4.1	18	12.2	'	'	'
Expected return on plan assets	'	'	-6.6	-4.7	-19.9	-14.2	'	'	'
Amortization of prior service cost (credit)	'	'	0.2	0.1	0.4	0.4	'	'	'
Amortization of actuarial loss	'	'	1.8	2.8	5.3	8.5	'	'	'
Loss on lump-sum settlement	'	'	0	12.3	1.3	12.3	'	'	'
Sub-total	'	'	3.8	16.9	12.4	26.1	'	'	'
Regulatory adjustment	'	'	2.9	-12.7	7.4	-13.6	'	'	'
Net postretirement benefit cost	'	'	6.7	4.2	19.8	12.5	'	'	'
Extent of Lump-sum payments recognized, percentage	'	'	'	'	100.00%	'	'	'	'
Lump-sum payments recognized as settlements	'	'	'	'	19.8	39.7	'	'	'
Implementation period used to calculate return on plan assets (in years)	'	'	'	'	'4 years	'	'	'	'
Rate Recovery Of Benefit Costs	'	'	'	'	'	'	9.9	15.5	10
Defined Benefit Plan, Contributions by Employer	18.2	0.3	'	'	'	'	'	'	'
Expected future benefit payments, remainder of fiscal year	$5.70	$0.10	'	'	'	'	'	'	'

PENSION_PLANS_AND_OTHER_POSTRE3

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Postretirement Benefits (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2010
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'
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	'	'
Postretirement Benefit	'	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'
Service cost – benefits earned during the period	$2.80	$2.50	$8.40	$7.60	'
Interest cost on accumulated postretirement benefit obligation	2.1	1.2	6.5	3.8	'
Expected return on plan assets	-1.7	-1	-5.1	-3.2	'
Amortization of transition obligation	0	0.1	0	0.1	'
Amortization of prior service cost (credit)	0	0	0	0	'
Amortization of actuarial loss	1.5	1.2	4.5	3.9	'
Sub-total	4.7	4	14.3	12.2	'
Regulatory adjustment	-2.4	-1.7	-7.2	-5.1	'
Net postretirement benefit cost	2.3	2.3	7.1	7.1	'
Gains Or Losses Includible In Cost Amortized To Extent Exceeds Projected Benefit Obligations Or Market Related Value Of Plan Assets Percentage	'	'	10.00%	'	'
Recovery in rates for postretirement benefit	'	'	'	'	9.5
Defined Benefit Plan, Contributions by Employer	'	'	9.5	'	'
Supplemental Employee Retirement Plan, Defined Benefit	'	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'
Expected future benefit payments, remainder of fiscal year	9.7	'	9.7	'	'
Qualified Postretirement Benefit	'	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'
Expected future benefit payments, remainder of fiscal year	$0.30	'	$0.30	'	'

INFORMATION_BY_OPERATING_SEGME2

INFORMATION BY OPERATING SEGMENT - Segments Operating Income (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2013
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'	'	'
Ownership percentage	100.00%	'	100.00%	'	'
Operating Revenues:	'	'	'	'	'
Revenues from external customers	$241.80	$165.30	$1,404.90	$869.90	'
Total Operating Revenues	241.8	165.3	1,404.90	869.9	'
Operating Expenses [Abstract]	'	'	'	'	'
Natural and propane gas	49.3	43.2	696.4	410.2	'
Other operation and maintenance expenses	73	42.5	207.3	123.3	'
Depreciation and amortization	18.4	11.5	58.5	33.7	'
Taxes, other than income taxes	22.2	12.9	92.6	49.5	'
Total Gas Utility Operating Expenses	162.9	110.1	1,054.80	616.7	'
Gas marketing and other	50	40.6	166.8	134	'
Other	4.2	2.3	8.5	13	'
Total Operating Expenses	217.1	153	1,230.10	763.7	'
Operating Income	24.7	12.3	174.8	106.2	'
Net Economic Earnings (Losses)	14.5	8.2	102.5	68.9	'
Assets [Abstract]	'	'	'	'	'
Total assets	3,656.70	'	3,656.70	'	3,125.40
Gas Utility	'	'	'	'	'
Operating Expenses [Abstract]	'	'	'	'	'
Net Economic Earnings (Losses)	13.3	'	93.8	'	'
Regulated Gas Distribution | Gas Utility	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Revenues from external customers	214	131.5	1,283.60	735.7	'
Total Operating Revenues	214.2	131.5	1,288.10	746.2	'
Operating Expenses [Abstract]	'	'	'	'	'
Natural and propane gas	77.6	52.8	769.7	435.3	'
Other operation and maintenance expenses	73.3	42.2	208	123	'
Depreciation and amortization	18.4	11.5	58.5	33.7	'
Taxes, other than income taxes	22.2	12.9	92.6	49.5	'
Total Gas Utility Operating Expenses	191.5	119.4	1,128.80	641.5	'
Gas marketing and other	0	0	0	0	'
Other	0	0	0	0	'
Total Operating Expenses	191.5	119.4	1,128.80	641.5	'
Operating Income	22.7	12.1	159.3	104.7	'
Net Economic Earnings (Losses)	'	6.8	'	62.3	'
Assets [Abstract]	'	'	'	'	'
Total assets	2,976.50	'	2,976.50	'	2,981
Non-Regulated Gas Marketing | Gas Marketing	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Revenues from external customers	27.1	33.4	120.2	129.9	'
Total Operating Revenues	55	42.8	188.2	143.9	'
Operating Expenses [Abstract]	'	'	'	'	'
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 and other	50	40.6	166.8	134	'
Other	0	0	0	0	'
Total Operating Expenses	50	40.6	166.8	134	'
Operating Income	5	2.2	21.4	9.9	'
Net Economic Earnings (Losses)	1.9	1.6	9.8	7.3	'
Assets [Abstract]	'	'	'	'	'
Total assets	185.8	'	185.8	'	163.9
Other | Other	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Revenues from external customers	0.7	0.4	1.1	4.3	'
Total Operating Revenues	1.2	1.1	2.6	5.4	'
Operating Expenses [Abstract]	'	'	'	'	'
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 and other	0	0	0	0	'
Other	4.2	3.1	8.5	13.8	'
Total Operating Expenses	4.2	3.1	8.5	13.8	'
Operating Income	-3	-2	-5.9	-8.4	'
Net Economic Earnings (Losses)	-0.7	-0.2	-1.1	-0.7	'
Assets [Abstract]	'	'	'	'	'
Total assets	989	'	989	'	115.6
Consolidation, Eliminations | Unallocated and Eliminations	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Revenues from external customers	0	0	0	0	'
Total Operating Revenues	-28.6	-10.1	-74	-25.6	'
Operating Expenses [Abstract]	'	'	'	'	'
Natural and propane gas	-28.3	-9.6	-73.3	-25.1	'
Other operation and maintenance expenses	-0.3	0.3	-0.7	0.3	'
Depreciation and amortization	0	0	0	0	'
Taxes, other than income taxes	0	0	0	0	'
Total Gas Utility Operating Expenses	-28.6	-9.3	-74	-24.8	'
Gas marketing and other	0	0	0	0	'
Other	0	-0.8	0	-0.8	'
Total Operating Expenses	-28.6	-10.1	-74	-25.6	'
Operating Income	0	0	0	0	'
Net Economic Earnings (Losses)	0	0	0	0	'
Assets [Abstract]	'	'	'	'	'
Total assets	-494.6	'	-494.6	'	-135.1
Intersubsegment Eliminations	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Intersegment revenues	0	0	0	0	'
Intersubsegment Eliminations | Regulated Gas Distribution | Gas Utility	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Intersegment revenues	0.2	0	4.5	10.5	'
Intersubsegment Eliminations | Non-Regulated Gas Marketing | Gas Marketing	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Intersegment revenues	27.9	9.4	68	14	'
Intersubsegment Eliminations | Other | Other	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Intersegment revenues	0.5	0.7	1.5	1.1	'
Intersubsegment Eliminations | Consolidation, Eliminations | Unallocated and Eliminations	'	'	'	'	'
Operating Revenues:	'	'	'	'	'
Intersegment revenues	($28.60)	($10.10)	($74)	($25.60)	'

INFORMATION_BY_OPERATING_SEGME3

INFORMATION BY OPERATING SEGMENT - Laclede Gas Segment Performance (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2013
Segment Reporting Information [Line Items]	'	'	'	'	'
Gas utility	$214	$131.50	$1,283.60	$735.70	'
Total Operating Revenues	241.8	165.3	1,404.90	869.9	'
Net Economic Earnings	14.5	8.2	102.5	68.9	'
Assets	3,656.70	'	3,656.70	'	3,125.40
Gas Utility	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Net Economic Earnings	13.3	'	93.8	'	'
Laclede Gas Company	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Gas utility	214.2	131.5	1,288.10	746.2	'
Total Operating Revenues	214.2	131.7	1,288.20	747.8	'
Other	0	0.2	0.1	1.6	'
Net Economic Earnings	13.2	6.7	93.7	63	'
Assets	2,976.50	'	2,976.50	'	2,981
Laclede Gas Company | Gas Utility	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Gas utility	214.2	131.5	1,288.10	746.2	'
Net Economic Earnings	'	6.8	'	62.3	'
Assets	2,976.50	'	2,976.50	'	2,981
Laclede Gas Company | Other	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Other	0	0.2	0.1	1.6	'
Net Economic Earnings	-0.1	-0.1	-0.1	0.7	'
Assets	0	'	0	'	0
Laclede Gas Company | Intersegment Eliminations	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'
Total Operating Revenues	0	0	0	0	'
Net Economic Earnings	$0	$0	$0	$0	'

INFORMATION_BY_OPERATING_SEGME4

INFORMATION BY OPERATING SEGMENT - Net Economic Earnings (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting [Abstract]	'	'	'	'
Net Income	$11.70	$6.60	$99.50	$62.40
Unrealized (gain) loss on energy-related derivative contracts	-1	-0.3	-2.3	0.6
Lower of cost or market inventory adjustments	-0.1	0.5	-0.7	0.6
Realized (gain) loss on economic hedges prior to sale of the physical commodity	0	0	-0.1	0
Acquisition, divestiture and restructuring activities	3.9	1.4	6.1	5.3
Net Economic Earnings (Non-GAAP)	$14.50	$8.20	$102.50	$68.90

INFORMATION_BY_OPERATING_SEGME5

INFORMATION BY OPERATING SEGMENT - Laclede Gas Net Economic Earnings (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Segment Reporting Information [Line Items]	'	'	'	'
Net Income	$11.70	$6.60	$99.50	$62.40
Unrealized (gain) loss on energy-related derivative contracts	-1	-0.3	-2.3	0.6
Acquisition, divestiture and restructuring activities	3.9	1.4	6.1	5.3
Net Economic Earnings (Non-GAAP)	14.5	8.2	102.5	68.9
Laclede Gas	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Net Income	12	3.8	91.5	59.3
Unrealized (gain) loss on energy-related derivative contracts	0	0	0	0.1
Acquisition, divestiture and restructuring activities	1.2	2.9	2.2	3.6
Net Economic Earnings (Non-GAAP)	$13.20	$6.70	$93.70	$63

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Sep. 30, 2005
	site
Contingencies and Indemnifications [Abstract]	'	'
Minimum total payments required for natural gas contracts	$1,150	'
Number Of Former Manufactured Gas Plant Sites In Missouri	3	'
Number of former manufactured gas plant (MGP) sites in Shrewsbury, Missouri	1	'
Number of former manufactured gas plant (MGP) sites in the City of St. Louis	2	'
Minimum cost estimate for a one-time contractual transfer of risk	'	5.8
Maximum cost estimate for a one-time contractual transfer of risk	'	36.3
Laclede Gas	'	'
Contingencies and Indemnifications [Abstract]	'	'
Minimum total payments required for natural gas contracts	$695	'