Spire Missouri 10-K 26 Nov 13 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Sep. 30, 2013	Mar. 31, 2013	Nov. 15, 2012
Document and Entity Information [Abstract]	'	'	'
Entity Registrant Name	'LACLEDE GAS COMPANY	'	'
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 Public Float	'	$0	'
Entity Common Stock, Shares Outstanding	'	'	25,549
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	30-Sep-13	'	'

STATEMENTS_OF_INCOME_UNAUDITED

STATEMENTS OF INCOME (UNAUDITED) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Operating Revenues:	'	'	'
Utility	$857,762	$764,651	$913,190
Other	1,603	2,976	19,138
Total Operating Revenues	859,365	767,627	932,328
Utility	'	'	'
Natural and propane gas	469,098	414,846	549,947
Other operation and maintenance expenses	180,703	167,351	172,938
Depreciation and amortization	48,283	40,739	39,214
Taxes, other than income taxes	60,079	53,672	60,752
Total Utility Operating Expenses	758,163	676,608	822,851
Other	13,658	209	7,985
Total Operating Expenses	771,821	676,817	830,836
Operating Income	87,544	90,810	101,492
Other Income and (Income Deductions) - Net	2,009	2,705	825
Interest Charges:	'	'	'
Interest on long-term debt	24,884	22,958	23,161
Other interest charges	1,253	2,198	2,383
Total Interest Charges	26,137	25,156	25,544
Income Before Income Taxes	63,416	68,359	76,773
Income Tax Expense	14,651	18,460	22,996
Net Income	$48,765	$49,899	$53,777

STATEMENTS_OF_COMPREHENSIVE_IN

STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Statement of Comprehensive Income [Abstract]	'	'	'
Net Income	$48,765	$49,899	$53,777
Net gains (losses) on cash flow hedging derivative instruments:	'	'	'
Net hedging gains arising during the period	123	297	355
Reclassification adjustment for gains included in net income	-211	0	-466
Net unrealized gains (losses) on cash flow hedging derivative instruments	-88	297	-111
Defined benefit pension and other postretirement benefit plans:	'	'	'
Net acturial (loss) gain arising during the period	120	3,397	-339
Amortization of acturial loss included in net periodic pension and other postretirement benefit cost	195	3,706	426
Net defined benefit pension and other postretirement benefit plans	75	309	765
Other Comprehensive Income (Loss), Before Tax	-13	606	654
Income Tax Expense (Benefit) Related to Items of Other Comprehensive Income (Loss)	-8	234	252
Other Comprehensive Income (Loss), Net of Tax	-5	372	402
Comprehensive Income	$48,760	$50,271	$54,179

BALANCE_SHEETS

BALANCE SHEETS (USD $)	Sep. 30, 2013	Sep. 30, 2012
In Thousands, unless otherwise specified
ASSETS	'	'
Utility Plant	$2,271,189	$1,497,419
Less - Accumulated depreciation and amortization	494,559	478,120
Net Utility Plant	1,776,630	1,019,299
Goodwill	247,078	0
Other Property and Investments	54,016	46,358
Current Assets:	'	'
Cash and cash equivalents	23,916	2,402
Accounts receivable:	'	'
Utility	101,118	64,027
Non-utility	967	1,244
Associated companies	1,111	4,315
Other	14,148	17,288
Allowance for doubtful accounts	-7,942	-7,601
Inventories:	'	'
Natural gas stored underground	164,740	89,852
Propane gas at FIFO cost	8,962	8,963
Materials and supplies at average cost	8,027	3,418
Unamortized purchased gas adjustments	17,533	40,674
Prepayments and other	11,255	9,011
Total Current Assets	343,835	233,593
Deferred Charges:	'	'
Regulatory assets	545,937	456,047
Other	13,520	4,855
Total Deferred Charges	559,457	460,902
Total Assets	2,981,016	1,760,152
Capitalization:	'	'
Common stock equity	973,930	491,328
Long-term debt (less current portion)	887,712	339,416
Total Capitalization	1,861,642	830,744
Current Liabilities:	'	'
Notes payable	74,000	40,100
Notes payable - associated companies	46,729	37,125
Accounts payable	66,582	38,391
Accounts payable - associated companies	6,081	2,576
Advance customer billings	23,736	25,146
Current portion of long-term debt	0	25,000
Wages and compensation accrued	20,807	13,908
Dividends payable	13,912	9,354
Customer deposits	15,062	8,565
Interest accrued	8,096	8,590
Taxes accrued	32,592	13,822
Deferred income taxes	1,692	10,146
Other	17,611	10,068
Total Current Liabilities	326,900	242,791
Deferred Credits and Other Liabilities:	'	'
Deferred income taxes	380,113	355,458
Unamortized investment tax credits	2,900	3,113
Noncurrent liabilities	228,653	196,558
Asset retirement obligations	74,302	40,126
Regulatory liabilities	61,943	56,319
Other	44,563	35,043
Total Deferred Credits and Other Liabilities	792,474	686,617
Total Capitalization and Liabilities	$2,981,016	$1,760,152

STATEMENTS_OF_CAPITALIZATION

STATEMENTS OF CAPITALIZATION (USD $)	Sep. 30, 2013	Sep. 30, 2012
In Thousands, unless otherwise specified
Common Stock Equity:	'	'
Common stock, par value $1 per share and Paid-in Capital: Authorized - 2012 and 2011, 50,000,000 shares; Issued - 2012, 12,804 shares; and 2011, 11,717 shares	$738,233	$257,415
Retained earnings	237,803	236,014
Accumulated other comprehensive loss	-2,106	-2,101
Total Common Stock Equity	973,930	491,328
Long-Term Debt:	'	'
Debt instrument, principal outstanding	890,000	340,000
Unamortized discount, net of premium, on long-term debt	-2,288	-584
Total Long-Term Debt	887,712	339,416
Total Capitalization	1,861,642	830,744
First Mortgage Bonds Series, due May 1, 2019 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	50,000
First Mortgage Bonds Series, due June 1, 2029 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	25,000
First Mortgage Bonds Series, due September 15, 2030 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	30,000
First Mortgage Bonds Series, due May 1, 2034 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	100,000
First Mortgage Bonds Series, due June 1, 2036 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	55,000
First Mortgage Bonds Series, due October 15, 2038 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	80,000
Three Percent Series Due March 15, 2023 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	0
Three Point Four Zero Percent Series Due March 15, 2028 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	0
Two Percent Series Due August 15, 2018 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	0
Three Point Four Zero Percent Series Due August 15, 2023 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	0
Four Point Six Two Five Series Due August 15, 2043 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	'	0
Laclede Gas [Member] | First Mortgage Bonds Series, due May 1, 2019 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	50,000	'
Laclede Gas [Member] | First Mortgage Bonds Series, due June 1, 2029 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	25,000	'
Laclede Gas [Member] | First Mortgage Bonds Series, due September 15, 2030 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	30,000	'
Laclede Gas [Member] | First Mortgage Bonds Series, due May 1, 2034 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	100,000	'
Laclede Gas [Member] | First Mortgage Bonds Series, due June 1, 2036 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	55,000	'
Laclede Gas [Member] | First Mortgage Bonds Series, due October 15, 2038 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	80,000	'
Laclede Gas [Member] | Three Percent Series Due March 15, 2023 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	55,000	'
Laclede Gas [Member] | Three Point Four Zero Percent Series Due March 15, 2028 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	45,000	'
Laclede Gas [Member] | Two Percent Series Due August 15, 2018 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	100,000	'
Laclede Gas [Member] | Three Point Four Zero Percent Series Due August 15, 2023 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	250,000	'
Laclede Gas [Member] | Four Point Six Two Five Series Due August 15, 2043 [Member]	'	'
Long-Term Debt:	'	'
Debt instrument, principal outstanding	$100,000	'

STATEMENTS_OF_CAPITALIZATION_P

STATEMENTS OF CAPITALIZATION (Parenthetical) (USD $)	Sep. 30, 2013	Sep. 30, 2012
Common Stock Equity:	'	'
Common stock, par value (in dollars per share)	$1	$1
Common stock, authorized (in shares)	50,000,000	50,000,000
Common stock, issued (in shares)	24,549	12,804
Long-Term Debt:	'	'
Stated interest rate on debt issued	'	6.50%
Laclede Gas [Member] | First Mortgage Bonds Series, due May 1, 2019 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	5.50%	'
Laclede Gas [Member] | First Mortgage Bonds Series, due June 1, 2029 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	7.00%	'
Laclede Gas [Member] | First Mortgage Bonds Series, due September 15, 2030 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	7.90%	'
Laclede Gas [Member] | First Mortgage Bonds Series, due May 1, 2034 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	6.00%	'
Laclede Gas [Member] | First Mortgage Bonds Series, due June 1, 2036 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	6.15%	'
Laclede Gas [Member] | First Mortgage Bonds Series, due October 15, 2038 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	6.35%	'
Laclede Gas [Member] | Three Percent Series Due March 15, 2023 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	3.00%	'
Laclede Gas [Member] | Three Point Four Zero Percent Series Due March 15, 2028 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	3.40%	'
Laclede Gas [Member] | Two Percent Series Due August 15, 2018 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	2.00%	'
Laclede Gas [Member] | Three Point Four Zero Percent Series Due August 15, 2023 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	3.40%	'
Laclede Gas [Member] | Four Point Six Two Five Series Due August 15, 2043 [Member]	'	'
Long-Term Debt:	'	'
Stated interest rate on debt issued	4.63%	'

STATEMENTS_OF_COMMON_SHAREHOLD

STATEMENTS OF COMMON SHAREHOLDER'S EQUITY (USD $)	Total	Common Stock Issued	Paid-in Capital	Retained Earnings	Accum. Other Comp. Income
In Thousands, except Share data, unless otherwise specified
BALANCE at Sep. 30, 2010	$411,259	$12	$208,142	$205,980	($2,875)
BALANCE (in shares) at Sep. 30, 2010	'	11,674	'	'	'
Net Income (Loss)	53,777	0	0	53,777	0
Stock-based compensation costs	2,946	0	2,946	0	0
Tax benefit - stock compensation	278	0	278	0	0
Issuance of common stock to Laclede Group	1,592	0	1,592	0	0
Issuance of common stock to Laclede Group (in shares)	'	43	'	'	'
Dividends declared:	'	'	'	'	'
Common stock	-36,297	0	0	-36,297	0
Other comprehensive income (loss), net of tax	402	0	0	0	402
BALANCE at Sep. 30, 2011	433,957	12	212,958	223,460	-2,473
BALANCE (in shares) at Sep. 30, 2011	'	11,717	'	'	'
Net Income (Loss)	49,899	0	0	49,899	0
Stock-based compensation costs	1,972	0	1,972	0	0
Tax benefit - stock compensation	-199	0	-199	0	0
Issuance of common stock to Laclede Group	42,672	1	42,671	0	0
Issuance of common stock to Laclede Group (in shares)	'	1,087	'	'	'
Dividends declared:	'	'	'	'	'
Common stock	-37,345	0	0	-37,345	0
Other comprehensive income (loss), net of tax	372	0	0	0	372
BALANCE at Sep. 30, 2012	491,328	13	257,402	236,014	-2,101
BALANCE (in shares) at Sep. 30, 2012	'	12,804	'	'	'
Net Income (Loss)	48,765	0	0	48,765	0
Stock-based compensation costs	3,055	0	3,055	0	0
Tax benefit - stock compensation	549	0	549	0	0
Issuance of common stock to Laclede Group	477,214	12	477,202	0	0
Issuance of common stock to Laclede Group (in shares)	'	11,745	'	'	'
Dividends declared:	'	'	'	'	'
Common stock	-46,976	0	0	-46,976	0
Other comprehensive income (loss), net of tax	-5	0	0	0	-5
BALANCE at Sep. 30, 2013	$973,930	$25	$738,208	$237,803	($2,106)
BALANCE (in shares) at Sep. 30, 2013	'	24,549	'	'	'

STATEMENTS_OF_CASH_FLOWS

STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Operating Activities:	'	'	'
Net Income (Loss)	$48,765	$49,899	$53,777
Adjustments to reconcile net income to net cash provided by (used in) operating activities:	'	'	'
Depreciation, amortization, and accretion	48,299	40,784	39,234
Deferred income taxes and investment tax credits	22,174	31,573	23,015
Other - net	-411	-582	1,992
Changes in assets and liabilities:	'	'	'
Accounts receivable - net	6,654	-9,444	-1,517
Unamortized purchased gas adjustments	23,141	-14,955	-2,001
Deferred purchased gas costs	13,300	11,090	44,565
Accounts payable	16,410	-8,130	4,182
Advance customer billings - net	-8,248	9,916	-1,579
Taxes accrued	999	3,286	1,347
Natural gas stored underground	-16,209	25,318	-1,594
Other assets and liabilities	-29,388	-19,788	-4,446
Net cash provided by operating activities	125,486	118,967	156,975
Investing Activities:	'	'	'
Capital expenditures	-128,496	-106,700	-67,300
Other investments	-1,328	3,607	742
Payments to Acquire Businesses, Gross	-975,000	0	0
Net cash used in investing activities	-1,104,824	-103,127	-66,562
Financing Activities:	'	'	'
Proceeds from Issuance of First Mortgage Bond	550,000	0	0
Maturity of first mortgage bonds	-25,000	0	-25,000
Repayment of short-term debt - net	33,900	-5,900	-83,650
Borrowings from Laclede Group	171,958	203,955	252,530
Repayment of borrowings from Laclede Group	-162,355	-219,709	-199,651
Changes in book overdrafts	-1,255	1,455	-545
Dividends paid	-42,420	-37,076	-36,018
Issuance of common stock to Laclede Group	477,225	42,672	1,592
Excess tax benefits from stock-based compensation	1,545	299	291
Other	-2,746	-57	-48
Net cash used in financing activities	1,000,852	-14,361	-90,499
Net Increase (Decrease) in Cash and Cash Equivalents	21,514	1,479	-86
Cash and Cash Equivalents at Beginning of Year	2,402	923	1,009
Cash and Cash Equivalents at End of Year	23,916	2,402	923
Supplemental Disclosure of Cash Paid (Refunded) During the Year for:	'	'	'
Interest	25,743	24,768	25,460
Income taxes	($7,573)	($6,588)	($846)

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	BASIS OF PRESENTATION - In compliance with generally accepted accounting principles (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 financial statements. Transactions with associated companies include sales of natural gas from the Utility to Laclede Energy Resources, Inc. (LER), sales of natural gas from LER to the Utility, and transportation services provided by Laclede Pipeline Company to the Utility. For fiscal years 2013, 2012, and 2011, sales of natural gas from the Utility to LER were $10.5 million, $1.2 million, and $1.6 million, respectively. Sales of natural gas from LER to the Utility during fiscal years 2013, 2012, and 2011 were $24.2 million, $16.5 million, and $24.3 million, respectively. Other services provided by Laclede Group's other subsidiaries to the Utility during fiscal years 2013, 2012, and 2011 were $1.6 million, $1.0 million, $1.0 million, respectively.
	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 $46.7 million and $37.1 million, at September 30, 2013 and 2012, respectively. The interest rate on these borrowings was 0.3% and 0.2% at September 30, 2013 and 2012, respectively. Advances under this note are due and payable on demand.
	NATURE OF OPERATIONS - The Utility serves St. Louis and eastern Missouri through Laclede Gas and serves Kansas City and western Missouri through Missouri Gas Energy. Together they provide more than 1.13 million residential, commercial and industrial customers with safe and reliable natural gas service. As an adjunct to its gas distribution business, the Utility operates an underground natural gas storage field. The non-regulated activities of the Utility are described in Note 12, Information by Operating Segment, and are included in the Other column.
	USE OF ESTIMATES - The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.
	SYSTEM OF ACCOUNTS - The accounts of the Utility are maintained in accordance with the Uniform System of Accounts prescribed by the Missouri Public Service Commission (MoPSC or Commission), which system substantially conforms to that prescribed by the Federal Energy Regulatory Commission (FERC).
	UTILITY PLANT, DEPRECIATION AND AMORTIZATION - Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct labor and materials, allocable overheads, and an allowance for funds used during construction. The costs of units of property retired, replaced, or renewed are removed from utility plant and are charged to accumulated depreciation. Maintenance and repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expenses.
	Utility plant is depreciated on a straight-line basis at rates based on estimated service lives of the various classes of property. In fiscal year 2013, annual depreciation and amortization expense averaged 3.2% of the original cost of depreciable and amortizable property, compared to 3.1% in both fiscal years 2012 and 2011.
	The Utility’s capital expenditures were $128.5 million, $106.7 million, and $67.3 million for fiscal years 2013, 2012, and 2011, respectively. Additionally, the Utility had recorded accruals for capital expenditures totaling $4.7 million at September 30, 2013, $9.7 million at September 30, 2012, and $8.2 million at September 30, 2011. Accrued capital expenditures are excluded from the Statements of Cash Flows.
	ASSET RETIREMENT OBLIGATIONS - The Utility records legal obligations associated with the retirement of long-lived assets in the period in which the obligations are incurred, if sufficient information exists to reasonably estimate the fair value of the obligations. Obligations are recorded as both a cost of the related long-lived asset and as a corresponding liability. Subsequently, the asset retirement costs are depreciated over the life of the asset and the asset retirement obligations are accreted to the expected settlement amounts. The Utility has recorded asset retirement obligations associated with certain safety requirements to purge and seal gas distribution mains upon retirement, the plugging and abandonment of storage wells and other storage facilities, specific service line obligations, and certain removal and disposal obligations related to components of the Utility's distribution system and general plant. As authorized by the MoPSC, the Utility accrues future asset removal costs associated with its property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities. When the Utility retires depreciable utility plant and equipment, it charges the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities. In the rate setting process, the regulatory liability is deducted from the rate base upon which the Utility has the opportunity to earn its allowed rate of return.
	As part of the MGE acquisition, the Utility has estimated the asset retirement obligation of MGE’s long-lived assets as of the acquisition date of September 1, 2013. This estimate is preliminary and will be finalized upon completion of a detailed fair value analysis that is being performed by the Company in the first quarter of fiscal 2014.
	The following table presents a reconciliation of the beginning and ending balances of Asset retirement obligations at September 30 as reported in the Balance Sheets:
	(Thousands)	2013			2012
	Asset retirement obligations, beginning of year	$	40,126		$	27,486
	Liabilities incurred during the period	801			619
	Liabilities settled during the period	(1,089		)	(601		)
	Accretion	2,312			1,636
	Revisions in estimated cash flows	—			10,986
	MGE's asset retirement obligation	32,152			—
	Asset retirement obligations, end of year	$	74,302		$	40,126
	REGULATED OPERATIONS - The Utility accounts for its regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (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 Balance Sheets as of September 30:
	(Thousands)	2013			2012
	Regulatory Assets:
	Future income taxes due from customers	$	112,902		$	118,997
	Pension and postretirement benefit costs	381,395			304,446
	Unamortized purchased gas adjustments	17,533			40,674
	Purchased gas costs	18,249			18,386
	Compensated absences	8,004			7,836
	Cold weather rule	—			—
	Other	25,387			6,382
	Total Regulatory Assets	$	563,470		$	496,721
	Regulatory Liabilities:
	Unamortized investment tax credits	$	2,900		$	3,113
	Accrued cost of removal	59,066			55,103
	Other	2,877			1,216
	Total Regulatory Liabilities	$	64,843		$	59,432
	The regulatory assets are expected to be recovered in rates charged to customers. A portion of the Company's regulatory assets are not earning a return; however, these regulatory assets are expected to be recovered from customers in future rates. Excluding deferred income taxes and purchased gas adjustment items, as of September 30, 2013 and 2012, approximately $17.2 million and $7.8 million, respectively, of regulatory assets were not earning a rate of return. The Company expects these items to be recovered over a period not to exceed 15 years consistent with precedent set by the Commission. The portion of the regulatory asset related to pensions and other postemployment benefits that relates to unfunded differences between the projected benefit obligation and plan assets also does not earn a rate of return.
	As authorized by the MoPSC, the Utility discontinued deferring certain costs for future recovery, as expenses associated with those specific areas were included in approved rates effective December 27, 1999. Previously deferred costs of $10.5 million are being recovered and amortized on a straight-line basis over a fifteen-year period, without return on investment. Amortization of these costs totaled $9.7 million from December 27, 1999 through September 30, 2013.
	NATURAL GAS STORED UNDERGROUND - For Laclede Gas, inventory of natural gas in storage is priced on a last-in, first-out (LIFO) basis and inventory of propane gas in storage is priced on a first-in, first-out (FIFO) basis. For MGE, inventory of natural gas in storage is priced on a weighted average cost basis. The replacement cost of natural gas stored underground for current use at September 30, 2013 and September 30, 2012 was less than the LIFO cost by $13.3 million and $24.3 million, respectively. The carrying value of the Utility inventory is not adjusted to the lower of cost or market prices because, pursuant to both Laclede Gas' and MGE's Purchased Gas Adjustment (PGA) Clauses, actual gas costs are recovered in customer rates.
	BUSINESS COMBINATIONS - The Company's acquisition of MGE was accounted for by the Company using business combination accounting. Under this method, the purchase price paid by the acquirer is allocated to the assets acquired and liabilities assumed as of the acquisition date based on their fair value. For additional information on the Company's acquisition of MGE, refer to Note 2, Acquisition of MGE.
	GOODWILL - Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. Laclede Group recorded $247.1 million of goodwill as part of the MGE acquisition. which has been assigned to the Utility within the company’s Gas Utility segment.
	REVENUE RECOGNITION - The Utility reads meters and bills its customers on monthly cycles. The Utility records its utility operating revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at September 30, 2013 and 2012, for the Utility, were $25.2 million and $11.6 million, respectively.
	PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT – As authorized by the MoPSC, the PGA Clause allows the Utility to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. To better match customer billings with market natural gas prices, the Utility is allowed to file to modify, on a periodic basis, the level of gas costs in its PGA. Certain provisions of the PGA Clause are included below:
	•	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. The MoPSC clarified that costs, cost reductions, and carrying costs associated with the Utility’s use of natural gas derivative instruments are gas costs recoverable through the PGA mechanism.
	•	The tariffs allow the Utility flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months.
	•	The Utility is authorized to recover gas inventory carrying costs through its PGA rates to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The Utility is also authorized to apply carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, including cash payments for margin deposits.
	•	The MoPSC approved a plan applicable to Laclede Gas’ gas supply commodity costs under which it retains a portion of cost savings associated with the acquisition of natural gas below an established benchmark level. This gas supply cost management program allows Laclede Gas to retain 10% of cost savings, up to a maximum of $3.0 million annually. Laclede Gas did not record any income under the plan during the three fiscal years reported. Income recorded under the plan, if any, is included in Utility Operating Revenues on the Statements of Income.
	Pursuant to the provisions of the PGA Clause, the difference between actual costs incurred and costs recovered through the application of the PGA are reflected as a deferred charge or credit at the end of the fiscal year. These costs include costs and cost reductions associated with the use of derivative instruments and gas inventory carrying costs, amounts due to or from customers related to operation of the gas supply cost management program, refunds received from the Utility’s suppliers in connection with gas supply, transportation, and storage services, and carrying costs on such over- or under-recoveries. At that time, the balance is classified as a current asset or current liability and recovered from, or credited to, customers over an annual period commencing in November. The balance in the current account is amortized as amounts are reflected in customer billings. The PGA Clause also provides for the treatment of income from off-system sales and capacity release revenues. Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November. The customer share of such income is determined in accordance with the tables below, which is shown for each legacy company (the Utility and MGE) under which the PGA Clauses were approved by the MoPSC.
	Laclede Gas
	Pre-tax Income	Customer Share	Company Share
	First $2 million	100%	—%
	Next $2 million	80%	20%
	Next $2 million	75%	25%
	Amounts exceeding $6 million	70%	30%
	MGE
	Pre-tax Income	Customer Share	Company Share
	First $1.2 million	85%	15%
	Next $1.2 million	80%	20%
	Next $1.2 million	75%	25%
	Amounts exceeding $3.6 million	70%	30%
	See the Regulatory and Other Matters section on page 28 of this report for additional information on Laclede Gas' off-system sales.
	INCOME TAXES - The Utility has elected, for tax purposes only, various accelerated depreciation provisions of the Internal Revenue Code. In addition, certain other costs are expensed currently for tax purposes while being deferred for book purposes. GAAP permits the benefit from a tax position to be recognized only if, and to the extent that, it is more likely than not that the tax position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Unrecognized tax benefits and related interest and penalties, if any, are recorded as liabilities or as a reduction to deferred tax assets. The Utility records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the tax basis and the related carrying amounts of assets and liabilities in the financial statements. Changes in enacted tax rates, if any, and certain property basis differences are reflected by entries to regulatory asset or regulatory liability accounts.
The Utility's investment tax credits utilized prior to 1986 have been deferred and are being amortized in accordance with regulatory treatment over the useful life of the related property.
Laclede Group files a consolidated federal income tax return and allocates income taxes to the Utility and its other subsidiaries as if each entity were a separate taxpayer.
CASH AND CASH EQUIVALENTS - All highly liquid debt instruments purchased with original maturities of three months or less are considered to be cash equivalents. Such instruments are carried at cost, which approximates market value. Outstanding checks on the Utility’s controlled disbursement bank accounts in excess of funds on deposit create book overdrafts (which are funded at the time checks are presented for payment) and are classified as Other in the Current Liabilities section of the Balance Sheets. Changes in book overdrafts between periods are reflected as Financing Activities in the Statements of Cash Flows.
GROSS RECEIPTS AND SALES 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 Income. Amounts recorded in Utility Operating Revenues were $40.8 million, $35.9 million, and $43.5 million for fiscal years 2013, 2012, and 2011, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
Sales taxes imposed on applicable Utility sales are billed to customers. These amounts are not recorded in the Statements of Income, but are recorded as tax collections payable and included in the Other line of the Current Liabilities section of the Balance Sheets.
ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. The Utility’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses, as approved by the MoPSC.
GROUP MEDICAL AND WORKERS’ COMPENSATION RESERVES - The Utility self-insures its group medical and workers’ compensation costs and carries stop-loss coverage in relation to medical claims and workers’ compensation claims. Reserves for amounts incurred but not reported are established based on historical cost levels and lags between occurrences and reporting.
FAIR VALUE MEASUREMENTS – Certain assets and liabilities are recognized or disclosed at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The levels of the hierarchy are described below:
•	Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities.
•	Level 2 – Pricing inputs other than quoted prices included within Level 1, which are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data.
•	Level 3 – Pricing that is based upon inputs that are generally unobservable that are based on the best information available and reflect management’s assumptions about how market participants would price the asset or liability.
Assessment of the significance of a particular input to the fair value measurements may require judgment and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. Additional information about fair value measurements is provided in Note 3, Pension Plans and Other Postretirement Benefits, Note 7, Fair Value of Financial Instruments, and Note 8, Fair Value Measurements.
STOCK-BASED COMPENSATION - Officers and employees of the Utility, as determined by the Compensation Committee of Laclede Group’s Board of Directors, are eligible to be selected for awards under the Laclede Group 2006 Equity Incentive Plan (2006 Plan). Grants of awards may be earned by achieving performance objectives and/or other criteria as determined by the Compensation Committee. Awards may include restricted stock, restricted stock units, qualified and non-qualified stock options, stock appreciation rights, and performance shares payable in stock, cash, or a combination of both. The 2006 Plan generally provides a minimum vesting period of at least three years for each type of award.
For Laclede Group’s non-employee directors, shares were awarded under the Restricted Stock Plan for Non-Employee Directors (Plan) prior to February 1, 2012, but any future awards will be granted under the 2006 Plan, as a result of plan amendments approved by Laclede Group’s shareholders. Awards previously granted under the Plan vest depending upon the participant’s age upon entering the plan and years of service as a director. Shares of the Utility common stock, which are 100% owned by Laclede Group, are not transacted under the plans.
Laclede Group accounts for awards under these plans in accordance with GAAP, and allocates applicable compensation costs to its subsidiaries. For awards made to its employees, the Utility records its allocation of compensation cost from Laclede Group with a corresponding increase to additional paid-in capital.
The amounts of compensation cost allocated to the Utility for share-based compensation arrangements are presented below:
(Thousands)	2013			2012			2011
Total equity compensation cost	$	3,843		$	2,303		$	3,383
Compensation cost capitalized	(1,366		)	(808		)	(924		)
Compensation cost recognized in net income	2,477			1,495			2,459
Income tax benefit recognized in net income	(948		)	(577		)	(948		)
Compensation cost recognized in net income, net of income tax	$	1,529		$	918		$	1,511
As of September 30, 2013, there was $4.2 million in unrecognized compensation cost related to nonvested share-based compensation arrangements that is expected to be allocated to the Utility over a weighted average period of 2.0 years.
NEW ACCOUNTING STANDARDS – In December 2011, the FASB issued ASU No. 2011-11, “Disclosures about Offsetting Assets and Liabilities,” to amend ASC Topic 210, “Balance Sheet,” to require additional disclosures about financial instruments and derivative instruments that have been presented on a net basis (offset) in the balance sheet. Additionally, information about financial instruments and derivative instruments that are subject to enforceable master netting arrangements or similar agreements, irrespective of whether they are presented net in the balance sheet, is required to be disclosed. The ASU impacts disclosures only and will not require any changes to financial statement presentation. The Company will present the new disclosures retrospectively beginning in the first quarter of fiscal year 2014.
In February 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” by requiring entities to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to provide information on significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. The Company will present the new disclosures prospectively beginning in the first quarter of fiscal year 2014.

ACQUISITION_OF_MGE

ACQUISITION OF MGE	12 Months Ended
	Sep. 30, 2013
Business Combinations [Abstract]	'
ACQUISITION OF MGE	'
	Acquisition of MGE
	Effective September 1, 2013, Laclede Group completed the purchase of substantially all of the assets and liabilities of Missouri Gas Energy (MGE), a utility engaged in the distribution of natural gas on a regulated basis in western Missouri, from Southern Union Company (SUG), an affiliate of Energy Transfer Equity, L.P. and Energy Transfer Partners, L.P. The purchase was completed pursuant to the purchase agreement dated December 14, 2012. Under the terms of the purchase agreement, Laclede Group acquired MGE for a purchase price of $975 million. The acquisition was supported through a combination of the issuance of 10.0 million shares of Laclede Group common stock, completed on May 29, 2013, the issuance by Laclede Gas of $450.0 million of first mortgage bonds, completed on August 13, 2013, short-term borrowings, and available cash.
	The acquisition was accounted for under the acquisition method of accounting 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. Laclede Group recorded $247.1 million of goodwill as an asset in the consolidated balance sheet, which has been assigned to the Utility within the Company’s Gas Utility segment.
	As part of the MGE acquisition, the Utility 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 in the first quarter of fiscal 2014.
	Under Topic 805, merger-related transaction costs (such as advisory, legal, valuation and other professional fees) are not included as components of consideration transferred but are accounted for as expenses in the periods in which the costs are incurred. During the years ended September 30, 2013 and 2012, Laclede Group incurred $17.0 million and $0.2 million, respectively, of third party pre-tax expenses associated with the transaction. These expenses are included in the Statement of Consolidated Income, with $15.1 million included in Other Operating Expenses and $1.9 million included in Interest on Long-term Debt.
	On November 13, 2013, in accordance with Section 3.2 of the purchase agreement for MGE, the Utility provided to SUG a reconciliation of certain balance sheet accounts as of August 31, 2013, the date immediately prior to the closing of the acquisition to the initial valuation date of September 30, 2012. The resulting difference adjusts for changes in the actual net assets transferred to the Utility at closing from the level at September 30, 2012. Section 3.2 also contains a process to resolve any disagreements among the parties, and the Utility plans to adjust cash and goodwill for any change as a result of this process upon final settlement, which is anticipated to be in the first quarter of fiscal 2014.
	The amount of revenue and earnings of MGE included in our Statements of Consolidated Income subsequent to the September 1, 2013 acquisition date are as follows:
	(Thousands)	September 1, 2013 - September 30, 2013
	Total net revenues	$	21,985
	Net Income	1,795
	The following table summarizes the preliminary fair value of assets acquired and liabilities assumed at the date of the acquisition:
	(Thousands)
	Assets:
	Utility plant	$	671,793
	Non-utility property	238
	Other investments	3,096
	Goodwill	247,078
	Other Property and Investments	922,205
	Accounts receivable:
	Utility	19,963
	Other	6,119
	Delayed customer billings	10,701
	Inventories:
	Natural gas stored underground	58,679
	Materials and supplies at average cost	3,988
	Prepayments and other	487
	Total Current Assets	99,937
	Deferred Charges:
	Regulatory assets	84,014
	Other	4,928
	Total Deferred Charges	88,942
	Total Assets Acquired	$	1,111,084
	Liabilities:
	Accounts payable	$	20,154
	Wages and compensation accrued	5,088
	Customer deposits	8,362
	Interest accrued	183
	Taxes accrued	17,197
	Other	12,620
	Total Current Liabilities	63,604
	Pension and postretirement benefit costs	24,466
	Asset retirement obligations	32,056
	Regulatory liabilities	2,249
	Other	13,709
	Total Deferred Credits and Other Liabilities	72,480
	Total Liabilities Assumed	$	136,084
	Net Assets Acquired	$	975,000
	The following unaudited pro forma financial information presents the combined results of operations as if the acquisition had occurred on October 1, 2011. The pro forma financial information does not reflect the costs of any integration activities. The pro forma results include estimates and assumptions, which management believes are reasonable. The unaudited pro forma financial information below is not necessarily indicative of either future results of operations or results that might have been achieved had MGE been part of the Utility as of the beginning of fiscal year 2012.
		Twelve Months Ended September 30,
	(Thousands)	2013		2012
	Total net revenues	$	1,518,201	$	1,581,425
	Net Income	83,642		81,722

PENSION_PLANS_AND_OTHER_POSTRE

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS	12 Months Ended
	Sep. 30, 2013
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS	'
	PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS
	This footnote includes all pension plans of the Company whether historical plans or those acquired as part of the purchase of certain assets and liabilities of MGE on September 1, 2013. The net pension and postretirement obligations were remeasured at that time as well as at the fiscal year end.
	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.
	Pension costs in 2013, 2012, and 2011 amounted to $17.5 million, $20.1 million, and $14.3 million, respectively, including amounts charged to construction.
	The net periodic pension costs include the following components:
	(Thousands)	2013				2012				2011
	Service cost – benefits earned during the period	$	9,209			$	9,203			$	9,553
	Interest cost on projected benefit obligation	16,959				19,358				18,819
	Expected return on plan assets	(19,358		)		(19,595		)		(18,849		)
	Amortization of prior service cost	544				592				642
	Amortization of actuarial loss	10,724				9,040				10,228
	Loss on lump-sum settlements	26,996				20,051				943
	Sub-total	45,074				38,649				21,336
	Regulatory adjustment	(27,532		)		(18,579		)		(7,066		)
	Net pension cost	$	17,542			$	20,070			$	14,270
	Other changes in plan assets and pension benefit obligations recognized in other comprehensive income include the following:
	(Thousands)	2013				2012				2011
	Current year actuarial loss (gain)	$	17,030			$	32,884			$	(13,485	)
	Amortization of actuarial loss	(10,724		)		(29,091		)		(11,171		)
	Acceleration of loss recognized due to settlement	(26,996		)		—				—
	Amortization of prior service cost	(544		)		(592		)		(642		)
	Sub-total	(21,234		)		3,201				(25,298		)
	Regulatory adjustment	21,159				(3,510		)		24,533
	Total recognized in other comprehensive income	$	(75	)		$	(309	)		$	(765	)
	Pursuant to the provisions of the Utility 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. Lump-sum payments recognized as settlements during fiscal year 2013, 2012 and 2011 were $79.5 million, $60.1 million, and $2.3 million, respectively.
	Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains or losses not yet includible in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants.
	The recovery in rates for Laclede Gas' qualified pension plan is based on an annual allowance of $4.8 million effective August 1, 2007 and $15.5 million effective January 1, 2011. The recovery in rates for MGE's qualified pension plan is based on an annual allowance of $10.0 million effective February 20, 2010. The difference between these amounts and pension expense as calculated pursuant to the above and that otherwise would be included in the Statements of Income and Statements of Comprehensive Income is deferred as a regulatory asset or regulatory liability.
	The following table sets forth the reconciliation of the beginning and ending balances of the pension benefit obligation at September 30:
	(Thousands)	2013				2012
	Benefit obligation at beginning of year	$	412,171			$	384,163
	Service cost	9,209				9,203
	Interest cost	16,959				19,358
	Actuarial loss (gain)	(23,921		)		52,161
	MGE acquisition	151,424				—
	Settlement loss	24,999				14,348
	Gross benefits paid *	(87,023		)		(67,062		)
	Benefit obligation at end of year	$	503,818			$	412,171
	Accumulated benefit obligation at end of year	$	444,129			$	353,061
	*	Includes $79,484 and $60,085 lump-sum payments recognized as settlements in fiscal years 2013 and 2012, respectively.
	The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:
	(Thousands)	2013				2012
	Fair value of plan assets at beginning of year	$	274,130			$	247,959
	Actual return on plan assets	3,387				53,220
	Employer contributions	27,991				40,013
	MGE acquisition	126,958				—
	Gross benefits paid *	(87,023		)		(67,062		)
	Fair value of plan assets at end of year	$	345,443			$	274,130
	Funded status of plans, end of year	$	(158,375	)		$	(138,041	)
	*	Includes $79,484 and $60,085 lump-sum payments recognized as settlements in fiscal years 2013 and 2012, respectively.
	The following table sets forth the amounts recognized in the Balance Sheets at September 30:
	(Thousands)	2013				2012
	Current liabilities	$	(442	)		$	(468	)
	Noncurrent liabilities	(157,933		)		(137,573		)
	Total	$	(158,375	)		$	(138,041	)
	Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of:
	Net actuarial loss	$	115,775			$	136,464
	Prior service costs	4,467				5,011
	Sub-total	120,242				141,475
	Adjustments for amounts included in Regulatory Assets	(116,686		)		(137,845		)
	Total	$	3,556			$	3,630
	At September 30, 2013, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic pension cost during fiscal year 2014:
	(Thousands)
Amortization of net actuarial loss	$	7,088
Amortization of prior service cost	497
Sub-total	7,585
Regulatory adjustment	(7,196		)
Total	$	389
The assumptions used to calculate net periodic pension costs are as follows:
	2013		2012		2011
Weighted average discount rate *	3.95%		5.10%		4.75%
Weighted average rate of future compensation increase	3.00%		3.00%		3.00%
Expected long-term rate of return on plan assets	7.75%		7.75%		8.00%
*	Weighted average discount rate assumption for the MGE pension plan is 5.05%.
The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The expected return is a long-term assumption that generally does not change annually. However, in 2012 and 2011, the expected return assumption was adjusted to reflect capital market volatility in recent years.
The assumptions used to calculate the benefit obligations are as follows:
	2013		2012
Weighted average discount rate *	4.70%		3.95%
Weighted average rate of future compensation increase	3.00%		3.00%
*	Weighted average discount rate assumption for the MGE pension plan is 5.00%.
Following are the projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have a projected benefit obligation and an accumulated benefit obligation in excess of plan assets:
(Thousands)	2013				2012
Projected benefit obligation	$	503,818			$	412,171
Accumulated benefit obligation	444,129				353,061
Fair value of plan assets	345,443				274,130
Following are the targeted and actual plan assets by category as of September 30 of each year:
	2014			2013			2012
	Target			Actual			Actual
Growth Strategy
Equity Markets	42.5	%		45.9	%		37.3	%
Commodities	2.5	%		1.6	%		2.2	%
Real Estate	2.5	%		3	%		2.2	%
Inflation-Indexed Securities	2.5	%		1.4	%		2.2	%
Debt Securities	50	%		43.3	%		41.1	%
Other*	—	%		4.8	%		15	%
Total	100	%		100	%		100	%
* Other investments in 2013 consist of cash equivalents. The relatively large cash position at September 30, 2012 was
due to a transition taking place between investment managers and was invested in debt securities in a matter of days.
The Utility's investment policy is designed to maximize, to the extent possible, the funded status of the plan over time, and minimize volatility of funding and costs. The policy seeks to maximize investment returns consistent with these objectives and the Utility's tolerance for risk. The duration of plan liabilities and the impact of potential changes in asset values on the funded status are fundamental considerations in the selection of plan assets. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with the policy. The policy seeks to avoid significant concentrations of risk by investing in a diversified portfolio of assets. Investments in corporate, U. S. government and agencies, and, to a lesser extent, international debt securities seek to provide duration matching with plan liabilities, and typically have investment grade ratings and reflect allocations across various entities and industries. During 2012, exposures to additional asset types were added to the target portfolio: commodities, real estate and inflation-indexed securities. The investment policy permits the use of derivative instruments, which may be used to achieve the desired market exposure of an index, adjust portfolio duration, or rebalance the total portfolio to the target asset allocation. The Growth Strategy utilizes a combination of derivative instruments and debt securities to achieve diversified exposure to equity and other markets while generating returns from the fixed-income investments and providing further duration matching with the liabilities. Performance and compliance with the guidelines is regularly monitored. The policy calls for increased allocations to debt securities as the funded status improves.
Following are expected pension benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:
				Pensions from
(Millions)	Pensions from			Laclede Gas
	Qualified Trust			Funds
2014	22.9			0.4
2015	25.3			0.5
2016	27.2			0.5
2017	30.8			0.6
2018	34.2			0.6
2019 – 2023	227.2			4.5
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. Contributions to the pension plans in fiscal year 2014 are anticipated to be $24.0 million into the qualified trusts, and $0.4 million into the non-qualified plans.
Postretirement Benefits
The Utility provides certain life insurance benefits at retirement. Medical insurance is available after early retirement until age 65. The transition obligation not yet includible in postretirement benefit cost is being amortized over 20 years. Postretirement benefit costs in 2013, 2012, and 2011 amounted to $9.5 million, $9.5 million, and $9.1 million, respectively, including amounts charged to construction.
Net periodic postretirement benefit costs consisted of the following components:
(Thousands)	2013				2012				2011
Service cost – benefits earned during the period	$	10,162			$	8,060			$	7,676
Interest cost on accumulated postretirement benefit obligation	5,234				5,521				4,843
Expected return on plan assets	(4,447		)		(3,965		)		(3,646		)
Amortization of transition obligation	93				136				136
Amortization of prior service credit	3				(2,072		)		(2,328		)
Amortization of actuarial loss	5,300				4,261				4,443
Sub-total	16,345				11,941				11,124
Regulatory adjustment	(6,821		)		(2,417		)		(2,071		)
Net postretirement benefit cost	$	9,524			$	9,524			$	9,053
Other changes in plan assets and postretirement benefit obligations recognized in other comprehensive income include the following:
(Thousands)	2013				2012				2011
Current year actuarial loss	$	16,300			$	10,138			$	1,696
Amortization of actuarial loss	(5,300		)		(4,261		)		(4,443		)
Amortization of prior service credit	(3		)		2,072				2,328
Amortization of transition obligation	(93		)		(136		)		(136		)
Sub-total	10,904				7,813				(555		)
Regulatory adjustment	(10,904		)		(7,813		)		555
Total recognized in other comprehensive income	$	—			$	—			$	—
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains and losses not yet includible in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s postretirement benefit plans is based on an annual allowance of $7.6 million effective August 1, 2007 and $9.5 million effective January 1, 2011. The difference between these amounts and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Income and Statements of Comprehensive Income is deferred as a regulatory asset or regulatory liability.
The following table sets forth the reconciliation of the beginning and ending balances of the postretirement benefit obligation at September 30:
(Thousands)	2013				2012
Benefit obligation at beginning of year	$	127,217			$	103,991
Service cost	10,162				8,060
Interest cost	5,234				5,521
Actuarial loss (gain)	17,514				15,895
MGE acquisition	28,444				—
Gross benefits paid	(8,449		)		(6,250		)
Benefit obligation at end of year	$	180,122			$	127,217
The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:
(Thousands)	2013				2012
Fair value of plan assets at beginning of year	$	67,442			$	51,744
Actual return on plan assets	5,660				9,722
Employer contributions	16,596				12,226
MGE acquisition	30,396				—
Gross benefits paid	(8,449		)		(6,250		)
Fair value of plan assets at end of year	$	111,645			$	67,442
Funded status of plans, end of year	$	(68,477	)		$	(59,775	)
The following table sets forth the amounts recognized in the Balance Sheets at September 30:
(Thousands)	2013				2012
Noncurrent assets	$	2,543			$	—
Current liabilities	(300		)		(790		)
Noncurrent liabilities	(70,720		)		(58,985		)
Total	$	(68,477	)		$	(59,775	)
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic postretirement benefit cost consist of:
Net actuarial loss	$	63,573			$	52,573
Prior service credit	(27		)		(24		)
Transition obligation	—				93
Sub-total	63,546				52,642
Adjustments for amounts included in Regulatory Assets	(63,546		)		(52,642		)
Total	$	—			$	—
At September 30, 2013, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic postretirement benefit cost during fiscal year 2014:
(Thousands)
Amortization of net actuarial loss	$	6,021
Amortization of prior service cost	(4		)
Sub-total	6,017
Regulatory adjustment	(6,017		)
Total	$	—
The assumptions used to calculate net periodic postretirement benefit costs are as follows:
	2013			2012			2011
Weighted average discount rate *	3.8	%		5.05	%		4.7	%
Weighted average rate of future compensation increase	3	%		3	%		3	%
Expected long-term rate of return on plan assets **	7.75	%		7.75	%		8	%
*	Weighted average discount rate assumption for the MGE postretirement plan is 5.05%.
**	Expected long-term rate of return on plan assets assumption for the MGE postretirement plan is 5.75%.
The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The expected return is a long-term assumption that generally does not change annually. However, in 2012 and 2011, the expected return assumption was adjusted to reflect capital market volatility in recent years.
The assumptions used to calculate the accumulated postretirement benefit obligations are as follows:
	2013		2012
Weighted average discount rate *	4.60%		3.80%
Weighted average rate of future compensation increase	3.00%		3.00%
*	Weighted average discount rate assumption for the MGE postretirement plan is 4.95%.
The assumed medical cost trend rates at September 30 for the Utility's postretirement plans are as follows:
	2013		2012
Medical cost trend assumed for next year	7.50%		7.00%
Rate to which the medical cost trend rate is assumed to decline (the ultimate medical cost trend rate)	5.00%		5.00%
Year the rate reaches the ultimate trend	2020		2017
The following table presents the effect of an assumed 1% change in the assumed medical cost trend rate:
(Thousands)	1% Increase				1% Decrease
Effect on net periodic postretirement benefit cost	$	1,520			$	(1,390	)
Effect on accumulated postretirement benefit obligation	7,060				(6,580		)
Following are the targeted and actual plan assets by category as of September 30 of each year:
	2014			2013			2012
	Target			Actual			Actual
Equity Securities	60	%		59	%		59	%
Debt Securities	40	%		39	%		39	%
Other	—	%		2	%		2	%
Total	100	%		100	%		100	%
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 and Rabbi trusts as its external funding mechanisms. The Utility's investment policy seeks to maximize investment returns consistent with the Utility's tolerance for risk. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with policy. Performance and compliance with the guidelines is regularly monitored. The Utility's current investment policy targets an asset allocation of 60% to equity securities and 40% to debt securities, excluding cash held in short-term debt securities for the purpose of making benefit payments. The Utility currently invests in a mutual fund which is rebalanced on an ongoing basis to the target allocation. The mutual fund is diversified across U.S. stock and bond markets.
Following are expected postretirement benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:
(Millions)	Benefits Paid				Benefits Paid
	from				from Laclede Gas
	Qualified Trust				Funds
2014	$	9.5			$	0.3
2015	9.9				0.3
2016	10.7				0.3
2017	11.7				0.4
2018	12.8				0.4
2019 – 2023	84.1				2.2
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. Contributions to the postretirement plans in fiscal year 2013 are anticipated to be $19.2 million to the qualified trusts, and $0.3 million paid directly to participants from the Utility funds.
Other Plans
The Utility sponsors 401(k) plans that cover substantially all employees. The plans allow employees to contribute a portion of their base pay in accordance with specific guidelines. The Utility provides a match of such contributions within specific limits. The cost of the defined contribution plans of the Utility amounted to $5.0 million, $3.8 million, and $3.6 million for fiscal years 2013, 2012, and 2011, respectively.
Fair Value Measurements of Pension and Other Postretirement Plan Assets
The table below categorizes the fair value measurements of the Utility's pension plan assets:
(Thousands)	Quoted Prices in Active Markets (Level 1)				Significant				Significant Unobservable Inputs			Total
					Observable Inputs				(Level 3)
					(Level 2)
As of September 30, 2013
Cash and cash equivalents	$	18,177			$	—			$	—		$	18,177
Stock/Bond mutual fund	—				115,817				—			115,817
Debt Securities
U.S. bond mutual funds	17,682				—				—			17,682
U.S. government	—				55,743				—			55,743
U.S. corporate	—				110,925				—			110,925
U.S. municipal	—				6,799				—			6,799
International	—				21,594				—			21,594
Derivative instruments (a)	—				(1,294		)		—			(1,294		)
Total	$	35,859			$	309,584			$	—		$	345,443
As of September 30, 2012
Cash and cash equivalents	$	57,614			$	—			$	—		$	57,614
Debt Securities
U.S. bond mutual funds	36,767				—				—			36,767
U.S. government	—				57,925				—			57,925
U.S. corporate	—				93,169				—			93,169
U.S. municipal	—				9,493				—			9,493
International	—				18,885				—			18,885
Derivative instruments (b)	—				277				—			277
Total	$	94,381			$	179,749			$	—		$	274,130
(a)   Derivative assets of $4,186 net of cash margin payable of $5,480.
(b)   Derivative assets of $3,027 net of cash margin receivable of $2,750.
The table below categorizes the fair value measurements of the Utility's postretirement plan assets:
(Thousands)	Quoted Prices in Active Markets (Level 1)				Significant Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)			Total
As of September 30, 2013
Cash and cash equivalents	$	1,411			$	—			$	—		$	1,411
U.S. stock/bond mutual fund	110,234				—				—			110,234
Total	$	111,645			$	—			$	—		$	111,645
As of September 30, 2012
Cash and cash equivalents	$	1,106			$	—			$	—		$	1,106
U.S. stock/bond mutual fund	66,336				—				—			66,336
Total	$	67,442			$	—			$	—		$	67,442
Cash and cash equivalents include money market mutual funds valued based on quoted market prices. Fair values of derivative instruments are calculated by investment managers who use valuation models that incorporate observable market inputs. Debt securities are valued based on broker/dealer quotations or by using observable market inputs. The stock and bond mutual funds are valued at the quoted market price of the identical securities.

STOCKHOLDERS_EQUITY

STOCKHOLDER'S EQUITY	12 Months Ended
	Sep. 30, 2013
Stockholders' Equity Note [Abstract]	'
STOCKHOLDER'S EQUITY	'
	STOCKHOLDER’S EQUITY
	Total shares of common stock outstanding were 24,549 and 12,804 at September 30, 2013 and 2012, respectively. Common stock and paid-in capital increased $480.8 million and $44.4 million in 2013 and 2012, respectively. These increases were primarily due to the issuance of common stock to Laclede Group and stock-based compensation costs allocated to the Utility from Laclede Group in both periods.
	The Utility periodically sold shares of its stock to Laclede Group at prices per share equal to book value on the last day of the quarter preceding each sale. The Utility sold 11,745 shares to Laclede Group for $476.5 million during fiscal 2013 and 1,087 shares to Laclede Group for $42.7 million during fiscal 2012. During fiscal 2013, $475 million of the stock sale proceeds were used to fund a portion of the MGE acquisition. The proceeds from other sales were used to reduce short-term borrowings. Exemption from registration for all of the sales was claimed under Section 4(2) of the Securities Act of 1933.
	Substantially all of the utility plant of the Utility is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on the Utility's ability to pay cash dividends on its common stock. These provisions are applicable regardless of whether the stock is publicly held or, as has been the case since the formation of Laclede Group, held solely by the Utility’s parent company. Under the most restrictive of these provisions, no cash dividend may be declared or paid if, after the dividend, the aggregate net amount spent for all dividends after September 30, 1953, would exceed a maximum amount determined by a formula set out in the mortgage. Under that formula, the maximum amount is the sum of $8 million plus earnings applicable to common stock (adjusted for stock repurchases and issuances) for the period from September 30, 1953, to the last day of the quarter before the declaration or payment date for the dividends. As of September 30, 2013 and 2012, the amount under the mortgage’s formula that was available to pay dividends was $833 million and $355 million, respectively. Thus, all of the Utility’s retained earnings were free from such restrictions as of those dates. The substantial increase in 2013 was primarily due to the issuance of stock to Laclede Group to fund a portion of the MGE acquisition.
	The components of accumulated other comprehensive income (loss), net of income taxes, recognized in the Balance Sheets at September 30 were as follows:
	(Thousands)				Defined Benefit Pension and Other			Total
		Net Unrealized Gains (Losses) on Cash Flow Hedges			Postretirement
					Benefit Plans
	Balance, September 30, 2011	$	(53	)	$	(2,420	)	$	(2,473	)
	Current-period change	182			190			372
	Balance, September 30, 2012	129			(2,230		)	(2,101		)
	Current-period change	(53		)	48			(5		)
	Balance, September 30, 2013	$	76		$	(2,182	)	$	(2,106	)
	Income tax expense (benefit) recorded for items of other comprehensive income reported in the Statements of Comprehensive Income is calculated by applying statutory federal, state, and local income tax rates applicable to ordinary income. The tax rates applied to individual items of other comprehensive income are similar within each reporting period.

LONGTERM_DEBT

LONG-TERM DEBT	12 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	LONG-TERM DEBT
	Maturities on long-term debt for the five fiscal years subsequent to September 30, 2013 are as follows:
	2014	—
	2015	—
	2016	—
	2017	—
	2018	$	100	million
	On October 15, 2012, the Utility paid at maturity $25 million principal amount of 6 1/2% first mortgage bonds. This maturity was funded through short-term borrowings. The Utility issued $100 million of first mortgage bonds in a private placement on March 15, 2013, that had been committed to in August 2012. Of this $100 million, $55 million were issued at 3.00% for a 10-year term, maturing in March 2023, and $45 million were issued at 3.40% for a 15-year term, maturing in March 2028. The proceeds were used for the repayment of short-term debt and general corporate purposes. The Utility issued $450 million of first mortgage bonds on August 13, 2013. Of this $450 million, $100 million was issued at 2.00% maturing in August 2018, $250 million was issued at 3.40% maturing in August 2023, and $100 million was issued at 4.625% maturing in August 2043. The proceeds were used to fund a portion of the MGE acquisition.
	At September 30, 2013, the Utility had fixed-rate long-term debt, including the current portion, totaling $890 million. While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. Of the Utility’s $890 million in long-term debt, $50 million have no call options, $410 million have make-whole call options, $350 million are callable at par three to six months prior to maturity, and $80 million are callable at par beginning in October 2013. None of the debt has any put options.
	On August 6, 2013, Laclede Group and the Utility filed with the SEC a joint shelf registration statement on Form S-3 for issuance of first mortgage bonds, unsecured debt, and preferred stock, which expires August 5, 2016. Bonds totaling $450 million were issued by the Utility from this registration statement on August 13, 2013. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions.
	The Utility has authority from the MoPSC to issue up to $518 million in debt securities and preferred stock, including on a private placement basis, as well as to enter into capital leases, issue common stock and receive paid-in capital. This authorization was originally effective through June 30, 2013. In August 2012, the Utility filed a request with the MoPSC to extend this authority for an additional two years, to June 30, 2015. This extension was approved October 24, 2012, to be effective on November 23, 2012. At November 26, 2013, $370.8 million remained under this authorization. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions.
	Substantially all of the Utility plant is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on the Utility's ability to pay cash dividends on its common stock, which are described more fully in Note 4, Stockholders’ Equity.
	At September 30, 2013 and 2012, the Utility had authorized 1,480,000 shares of preferred stock but none were issued and outstanding.
	For information on additional financing commitments, refer to Note 13, Commitments and Contingencies.

DERIVATIVE_INSTRUMENTS_AND_HED

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES	12 Months Ended
	Sep. 30, 2013
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 PGA Clause, through which the 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 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 September 30, 2013, the Utility held 0.3 million gallons of gasoline futures contracts at an average price of $2.23 per gallon. Most of these contracts, the longest of which extends to April 2014, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815, “Derivatives and Hedging.” The gains or losses on these derivative instruments are not subject to the Utility’s PGA Clause.
	Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the Balance Sheets at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in other comprehensive income (OCI). Accumulated other comprehensive income (AOCI) is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at September 30, 2013, it is expected that approximately $0.1 million in pre-tax gains will be reclassified into the Statements of Income during fiscal year 2014. 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 Cash Flows.
	The Utility’s derivative instruments consist primarily of NYMEX and OTCBB positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX and OTCBB natural gas futures positions at September 30, 2013 were as follows:
		MMBtu			Avg. Price
		(millions)			Per
					MMBtu
	NYMEX open long futures positions
	Fiscal 2014	7.26			$	3.99
	Fiscal 2015	0.94			3.84
	OTCBB open long futures positions
	Fiscal 2014	16.81			3.97
	Fiscal 2015	7.58			4.22
	At September 30, 2013, the Utility also had 23.6 million MMBtu of other price mitigation in place through the use of NYMEX and OTCBB natural gas option-based strategies.
	The Effect of Derivative Instruments on the Statements of Income and Statements of Comprehensive Income
		Location of Gain (Loss)
	(Thousands)	Recorded in Income	2013				2012		2011
	Derivatives in Cash Flow Hedging Relationships
	NYMEX gasoline and heating oil contracts:
	Effective portion of gain recognized in		$	123			$	297	$	355
	OCI on derivatives
	Effective portion of gain reclassified from	Utility – Other Operation Expenses	211				—		466
	AOCI to income
	Ineffective portion of gain (loss) on derivatives	Utility – Other Operation Expenses	(127		)		175		12
	recognized in income
	Derivatives Not Designated as Hedging Instruments *
	NYMEX gasoline and heating oil contracts:
	Gain (loss) recognized in income on derivative	Other Income and (Income Deductions) - Net	$	41			$	19	$	37
	*	Gains and losses on the Utility's 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 Income. Such amounts are recognized in the Statements of Income as a component of Utility Natural and Propane Gas operating expenses when they are recovered through the PGA Clause and reflected in customer billings.
	Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2013
		Asset Derivatives				Liability Derivatives
	(Thousands)	Balance Sheet Location	Fair Value*			Balance Sheet Location	Fair Value*
	Derivatives designated as hedging instruments
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	$	105		Accounts Receivable - Other	$	—
	Derivatives not designated as hedging instruments
	NYMEX natural gas contracts	Accounts Receivable – Other	1,434			Accounts Receivable – Other	3,455
		Other Deferred Charges	32			Other Deferred Charges	—
	OTCBB natural gas contracts	Other Current Liabilities	228			Current Liabilities - Other	4,045
		Other Deferred Credits	4			Deferred Credits - Other	1,398
	Sub-total		1,698				8,898
	Total derivatives		$	1,803			$	8,898
	Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2012
		Asset Derivatives				Liability Derivatives
	(Thousands)	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Derivatives designated as hedging instruments
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	$	334		Accounts Receivable - Other	$	—
	Derivatives not designated as hedging instruments
	NYMEX natural gas contracts	Accounts Receivable - Other	7,338			Accounts Receivable - Other	9,563
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	10			Accounts Receivable - Other	—
	Sub-total		7,348				9,563
	Total derivatives		$	7,682			$	9,563
	*	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 Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Utility’s net economic exposure. Refer to Note 8, 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 Balance Sheets:
	(Thousands)	2013				2012
	Fair value of asset derivatives presented above	1,803				7,682
	Fair value of cash margin receivables offset with derivatives	1,890				1,964
	Netting of assets and liabilities with the same counterparty	(3,693		)		(9,646		)
	Total	$	—			$	—
	Derivative Instrument Assets, per Balance Sheets:
	Derivative instrument assets	—				—
	Other deferred charges	—				—
Total	$	—			$	—
Fair value of liability derivatives presented above	8,898				9,563
Fair Value of cash margin payables offset with derivatives	6				83
Netting of assets and liabilities with the same counterparty	(3,693		)		(9,646		)
Derivative instrument liabilities, per Balance Sheets*	$	5,211			$	—
Derivative Instrument Assets, per Balance Sheets:
Other current liabilities	3,817				—
Other deferred credits	1,394				—
Total	$	5,211			$	—
Additionally, at September 30, 2013 and September 30, 2012, the Utility had $2.9 million and $8.0 million, respectively, in cash margin receivables not offset with derivatives, that are presented in Accounts Receivable – Other. There was no such amount at September 30, 2011.

NOTES_PAYABLE_AND_CREDIT_AGREE

NOTES PAYABLE AND CREDIT AGREEMENTS	12 Months Ended
	Sep. 30, 2013
Short-term Debt [Abstract]	'
NOTES PAYABLE AND CREDIT AGREEMENTS	'
	NOTES PAYABLE AND CREDIT AGREEMENTS
	The Company’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. On September 3, 2013, the Utility entered into a new syndicated line of credit for $450 million with nine banks, which will expire in September 2018. The largest portion provided by a single bank is 15.6%. The previous syndicated line of credit agreement was terminated at that time.
	The Utility's line of credit includes a covenant limiting total debt, including short-term debt, to no more than 70% of total capitalization. On September 30, 2013, total debt was 51% of total capitalization.
	Due to lower yields available to Laclede Group on its short-term investments, Laclede Group elected to provide a portion of the Utility's short-term funding through intercompany lending during the fiscal year. Information about the Utility’s internal and external short-term borrowings during the 12 months ended September 30, and as of September 30, is presented below for 2013 and 2012:
		Commercial Paper Borrowings	Borrowings from Laclede Group	Total Short-Term Borrowings
	Twelve Months Ended September 30, 2013
	Weighted average borrowings outstanding	$34.2 million	$29.2 million	$63.4 million
	Weighted average interest rate	0.30%	0.30%	0.30%
	Range of borrowings outstanding	$0 – $99.4 million	$0 – $91.7 million	$0 – $160.5 million
	As of September 30, 2013
	Borrowings outstanding at end of period	$74.0 million	$46.7 million	$120.7 million
	Weighted average interest rate	0.30%	0.30%	0.30%
	Twelve Months Ended September 30, 2012
	Weighted average borrowings outstanding	$43.8 million	$78.2 million	$122.0 million
	Weighted average interest rate	0.30%	0.30%	0.30%
	Range of borrowings outstanding	$0 – $133.5 million	$13.0 - $107.5 million	$59.6 - $200.1 million
	As of September 30, 2012
	Borrowings outstanding at end of period	$40.1 million	$37.1 million	$77.2 million
	Weighted average interest rate	0.20%	0.20%	0.20%

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	12 Months Ended
	Sep. 30, 2013
Financial Instruments, Owned, at Fair Value [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	FAIR VALUE OF FINANCIAL INSTRUMENTS
	The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis at September 30, 2013 and 2012 are as follows:
						Classification of Estimated Fair Value (a)
	(Thousands)	Carrying		Fair		Quoted		Significant Observable Inputs		Significant Unobservable Inputs
		Amount		Value		Prices in Active Markets		(Level 2)		(Level 3)
						(Level 1)
	As of September 30, 2013
	Cash and cash equivalents	$	23,916	$	23,916	$	23,892	$	24	$	—
	Short-term debt	120,729		120,729		—		120,729		—
	Long-term debt, including current portion	887,712		930,369		—		930,369		—
	As of September 30, 2012
	Cash and cash equivalents	$	2,402	$	2,402	$	2,378	$	24	$	—
	Short-term debt	77,225		77,225		—		77,225		—
	Long-term debt	364,416		452,768		—		452,768		—
	(a) The Utility adopted the provisions of ASU 2011-04 (ASC Topic 820) in the second quarter of fiscal year 2012 on a prospective basis. Accordingly, disclosures for prior periods are not required to be presented.
	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 8, Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
FAIR VALUE MEASUREMENTS	'
	FAIR VALUE MEASUREMENTS
	The following table categorizes the assets and liabilities in the Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.
	(Thousands)	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 September 30, 2013
	Assets
	U. S. Stock/Bond Mutual Funds	$	14,500	$	—	$	—	$	—		$	14,500
	NYMEX natural gas contracts	1,466		—		—		(1,466		)	—
	OTCBB natural gas contracts	—		232		—		(232		)	—
	NYMEX gasoline and heating oil contracts	105		—		—		(105		)	—
	Total	$	16,071	$	232	$	—	$	(1,803	)	$	14,500
	Liabilities
	NYMEX natural gas contracts	$	3,455	$	—	$	—	$	(3,455	)	$	—
	OTCBB natural gas contracts	$	—	$	5,443	$	—	$	(232	)	$	5,211
	As of September 30, 2012
	U. S. Stock/Bond Mutual Funds	$	13,187	$	—	$	—	$	—		$	13,187
	NYMEX natural gas contracts	7,338		—		—		(7,338		)	—
	NYMEX gasoline and heating	344		—		—		(344		)	—
	oil contracts
	Total	$	20,869	$	—	$	—	$	(7,682	)	$	13,187
	Liabilities
	NYMEX natural gas contracts	$	9,563	$	—	$	—	$	(9,563	)	$	—
	The mutual funds included in Level 1 are valued based on exchange-quoted market prices of identical securities. Derivative instruments included in Level 1 are valued using quoted market prices on the New York Mercantile Exchange (NYMEX). Derivative instruments classified in Level 2 include physical commodity derivatives that are valued using Over The Counter Bulletin Board (OTCBB), broker, or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. The 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. The mutual funds are included in the Other Property and Investments line of the Balance Sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the Balance Sheets when a legally enforceable netting agreement exists between the Utility and the counterparty to a derivative contract. For additional information on derivative instruments, see Note 9, Derivative Instruments and Hedging Activities.

INCOME_TAXES

INCOME TAXES	12 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
INCOME TAXES	'
	INCOME TAXES
	The net provisions for income taxes charged during the fiscal years ended September 30, 2013, 2012, and 2011 are as follows:
	(Thousands)	2013				2012				2011
	Included in Statements of Income:
	Federal
	Current	$	(6,539	)		$	(11,288	)		$	133
	Deferred	20,103				27,186				19,848
	Investment tax credits	(213		)		(213		)		(213		)
	State and local
	Current	(984		)		(1,825		)		(152		)
	Deferred	2,284				4,600				3,380
	Total Income Tax Expense	$	14,651			$	18,460			$	22,996
	The effective income tax rate varied from the federal statutory income tax rate for each year due to the following:
		2013			2012			2011
	Federal income tax statutory rate	35	%		35	%		35	%
	State and local income taxes, net of federal
	income tax benefits	3.3			2.6			2.7
	Certain expenses capitalized on books and
	deducted on tax return	(10.8	)		(8.9	)		(6.1	)
	Taxes related to prior years	(1.6	)		(0.6	)		(0.8	)
	Other items – net	(2.8	)		(1.1	)		(0.8	)
	Effective income tax rate	23.1	%		27	%		30	%
	The significant items comprising the net deferred tax liability recognized in the Balance Sheets as of September 30 are as follows:
	(Thousands)	2013				2012
	Deferred tax assets:
	Reserves not currently deductible	$	13,933			$	16,400
	Pension and other postretirement benefits	71,367				73,480
	Unamortized investment tax credits	1,799				1,955
	Other*	10,450				14,513
	Total deferred tax assets	97,549				106,348
	Deferred tax liabilities:
	Relating to utility property	341,975				303,332
	Regulatory pension and other postretirement benefits	124,871				121,554
	Deferred gas costs	7,112				20,652
	Other	5,396				26,414
	Total deferred tax liabilities	479,354				471,952
	Net deferred tax liability	381,805				365,604
	Net deferred tax liability – current*	(1,692		)		(10,146		)
	Net deferred tax liability – non-current*	$	380,113			$	355,458
	* The Utility periodically invests in tax credits. As of September 30, 2013, $6.6 million of state tax credits are included in Other and Net deferred tax liability. $4.3 million of state tax credits were classified as current. $2.3 million of state tax credits were classified as non-current.
	Laclede Group files a consolidated federal and state income tax return and allocates income taxes to the Utility and its other subsidiaries as if each entity were a separate taxpayer. Pursuant to GAAP, the Utility may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The Utility records potential interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are included in the Other line of the Deferred Credits and Other Liabilities section of the Balance Sheets.
	The following table presents a reconciliation of the beginning and ending balances of unrecognized tax benefits at September 30 as reported in the Balance Sheets:
	(Thousands)	2013				2012
	Unrecognized tax benefits, beginning of year	$	5,615			$	5,536
	Increases related to tax positions taken in current year	1,420				490
	Reductions due to lapse of applicable statute of limitations	(5,018		)		(411		)
	Unrecognized tax benefits, end of year	$	2,017			$	5,615
	The amount of unrecognized tax benefits, which, if recognized, would affect the Utility’s effective tax rate were $1.5 million and $1.2 million as of September 30, 2013 and 2012, respectively. It is reasonably possible that events will occur in the next 12 months that could increase or decrease the amount of the Utility’s unrecognized tax benefits. The Utility does not expect that any such change will be significant to the Utility's Balance Sheets.
	Interest accrued associated with the Utility’s uncertain tax positions as of September 30, 2013 and 2012 were $0.1 million and $0.5 million, respectively, and no penalties were accrued as of those dates. Interest expense accrued during fiscal year 2013 was $0.1 million, $0.2 million for fiscal year 2012, and $0.2 million for fiscal year 2011. During fiscal year 2013, the Utility reversed $0.6 million of accrued interest expense in the Statements of Income.
	Laclede Group and/or the Utility are subject to U.S. federal income tax as well as income tax of state and local jurisdictions. These companies are no longer subject to examination for fiscal years prior to 2010.
	In September 2013, the Internal Revenue Service and U.S. Treasury Department released final regulations on the deduction and capitalization of expenditures related to tangible property. The regulations do not address the tax treatment for network assets such as natural gas pipelines. These regulations apply to tax years beginning on or after January 1, 2014. Laclede is evaluating the effects of the regulations, but does not believe that they will have a significant impact on its consolidated financial statements.

OTHER_INCOME_AND_INCOME_DEDUCT

OTHER INCOME AND INCOME (DEDUCTIONS) NET	12 Months Ended
	Sep. 30, 2013
Other Nonoperating Income (Expense) [Abstract]	'
OTHER INCOME AND (INCOME DEDUCTIONS) - NET	'
	OTHER INCOME AND (INCOME DEDUCTIONS) – NET
	(Thousands)	2013			2012			2011
	Interest income	$	947		$	1,230		$	1,057
	Net investment gain (loss)	2,544			2,626			(73		)
	Other income	377			804			53
	Other income deductions	(1,859		)	(1,955		)	(212		)
	Other Income and (Income Deductions) – Net	$	2,009		$	2,705		$	825

INFORMATION_BY_OPERATING_SEGME

INFORMATION BY OPERATING SEGMENT	12 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
INFORMATION BY OPERATING SEGMENT	'
	INFORMATION BY OPERATING SEGMENT
	The Gas Utility segment consists of the regulated operations of 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.
	The Other segment includes the Utility's non-regulated business activities, which are comprised of its non-regulated propane sales transactions and its propane storage and related services. Accounting policies are described in Note 1. There are no material intersegment revenues.
	Management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impacts of net unrealized gains and losses and other timing differences associated with energy-related transactions. Net economic earnings will also exclude, if applicable, the after-tax impact of costs related to acquisition, divestiture, and restructuring activities.
							Adjustments &
	(Thousands)	Gas Utility		Other			Eliminations		Total
	FISCAL 2013
	Operating revenues	$	857,762	$	1,603		$	—	$	859,365
	Depreciation and amortization	48,283		—			—		48,283
	Interest income	947		—			—		947
	Interest charges	26,137		—			—		26,137
	Income tax expense	19,243		(4,592		)	—		14,651
	Net economic earnings	56,635		574			—		57,209
	Total assets	2,981,016		—			—		2,981,016
	Capital expenditures	128,496		—			—		128,496
	FISCAL 2012
	Operating revenues	$	764,651	$	2,976		$	—	$	767,627
	Depreciation and amortization	40,739		—			—		40,739
	Interest income	1,230		—			—		1,230
	Interest charges	25,156		—			—		25,156
	Income tax expense	17,393		1,067			—		18,460
	Net economic earnings	48,089		1,700			—		49,789
	Total assets	1,758,952		1,200			—		1,760,152
	Capital expenditures	106,734		—			—		106,734
	FISCAL 2011
	Operating revenues	$	913,190	$	19,138		$	—	$	932,328
	Depreciation and amortization	39,214		—			—		39,214
	Interest income	1,057		—			—		1,057
	Interest charges	25,544		—			—		25,544
	Income tax expense	18,694		4,302			—		22,996
	Net economic earnings	46,952		6,851		*	—		53,803
	Total assets	1,641,386		1,660			—		1,643,046
	Capital expenditures	67,304		—			—		67,304
	*	Net economic earnings include income realized by the Utility from separate non-regulated sales of propane inventory no longer needed to serve utility customers, of which occurred in fiscal year 2011. These transactions resulted in after-tax earnings totaling $6.1 million.
	Reconciliation of Net Income to Net Economic Earnings
	(Thousands)	2013		2012			2011
	Net Income (GAAP)	$	48,765	$	49,899		$	53,777
	Unrealized loss (gain) on energy-related	100		(110		)	26
	derivative contracts, net of tax
	Acquisition, divestiture and restructuring activities	8,344		—			—
	Net Economic Earnings (Non-GAAP)	$	57,209	$	49,789		$	53,803

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	COMMITMENTS AND CONTINGENCIES
	Commitments
	The Utility estimates total Utility capital expenditures for fiscal 2014 at approximately $175 million. In fiscal 2011, the Utility initiated a multi-year project to replace its existing customer relationship and work management, financial, and supply chain software applications to enhance its technology, customer service, and business processes. At September 30, 2013, the Utility was contractually committed to costs of approximately $1.5 million related to this project, with additional expenditures to be incurred throughout the project’s life.
	The Utility has entered into various contracts, expiring on dates through 2019, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at September 30, 2013 are estimated at approximately $793 million. The Utility recovers its costs from customers in accordance with the PGA Clause.
	Laclede Pipeline Company (Pipeline), a wholly owned subsidiary of Laclede Group, is providing liquid propane transportation service to the Utility pursuant to an approved FERC tariff and a contractual arrangement between Pipeline and the Utility. In accordance with the terms of that agreement, the Utility is obligated to pay Pipeline approximately $1.0 million annually, at current rates. The agreement renews at the end of each contract year, unless terminated by either party upon provision of at least six months’ notice.
	Leases
	The lease agreement covering the main office space of the Utility extends through February 2015 with the option to renew for five additional years. The aggregate rental expense for fiscal years 2013, 2012, and 2011 was approximately $1.0 million, $0.9 million, and $0.9 million, respectively. The annual minimum rental payment for fiscal year 2014 is anticipated to be approximately $1.0 million through fiscal year 2015. The annual rental amount for the lease agreement covering MGE's main office space is approximately $0.6 million, and the lease term extends through November 30, 2015.
	The Utility has entered into various operating lease agreements for the rental of vehicles and power operated equipment. The rental costs will be approximately $2.7 million in fiscal year 2014, $1.8 million in fiscal year 2015, $1.0 million in fiscal year 2016, $0.4 million in fiscal year 2017, and $0.1 million in fiscal year 2018. The Utility has other relatively minor rental arrangements that provide for minimum rental payments.
	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 Utility's financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, the Utility may be required to incur additional costs.
	Similar to other natural gas utility companies, Laclede Gas Company 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 former manufactured gas plant sites in the BVCP.
	With regard to the former MGP site located in Shrewsbury, Missouri, the Utility 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, the Utility 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, the Utility 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 the Utility and the other former site owner from certain liabilities related to the past and current environmental condition of the site and requires the developer and the environmental consultant to maintain certain insurance coverages, including remediation cost containment, premises pollution liability, and professional liability. The operative provisions of the Remediation Agreement were triggered on December 20, 2010, on which date the Utility 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 the Utility did not materially impact its financial condition, results of operations, or cash flows.
	The Utility 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 the Utility that the Missouri Department of Natural Resources had completed an investigation of the site. The Attorney General requested that the Utility participate in the follow up investigations of the site. In a letter dated January 10, 2012, the Utility 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.
	To date, amounts required for remediation at these sites have not been material. However, the amount of costs relative to future remedial actions at these and other sites is unknown and may be material. Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the MGP sites. While some of the insurers have denied coverage and reserved their rights, Laclede Gas continues to discuss potential reimbursements with them. In 2005, the Utility’s outside consultant completed an analysis of the MGP sites to determine cost estimates for a one-time contractual transfer of risk from each of the Utility’s insurers of environmental coverage for the MGP sites. That analysis demonstrated a range of possible future expenditures to investigate, monitor, and remediate these MGP sites from $5.8 million to $36.3 million based upon then currently available facts, technology, and laws and regulations. The actual costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remedial actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and governmental regulations, the ultimate ability of other potentially responsible parties to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries.
	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.
	The MoPSC Staff proposed disallowances related to Laclede Gas' recovery of its gas costs totaling $6.0 million pertaining to Laclede Gas' purchase of gas from a marketing affiliate, LER, applicable to fiscal years 2005 through 2007. The MoPSC staff also proposed a number of non-monetary recommendations, based on its review of gas costs for fiscal years 2008 through 2011. In a related matter, on October 6, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that Laclede Gas' affiliate transactions and its Cost Allocation Manual (CAM) violated the MoPSC's affiliate transaction rules. Laclede Gas responded with a counterclaim that the MoPSC Staff had failed to adhere to the affiliate transaction rules and the Company's CAM.
	On July 16, 2013, Laclede Gas, the MoPSC Staff and the Office of the Public Counsel requested MoPSC approval of a unanimous stipulation and agreement resolving the affiliate transaction matters for fiscal years 2005 through 2011, resolving the October 6, 2010 complaint, resolving Laclede Gas' counterclaim, presenting a revised CAM for MoPSC approval, and establishing standards of conduct for gas purchase and sales. While the PSC Staff's disallowances were withdrawn as part of the stipulation, Laclede Gas agreed to a minor adjustment to the off-system sales and capacity release sharing mechanism. For a three-year period ending September 30, 2016, Laclede Gas' share of the first $2 million in net margin is reduced from 15% to 0%. None of the other sharing percentages are affected, and beginning October 1, 2016, Laclede's sharing percentage of the first $2 million in net margins returns to 15%. The Stipulation and agreement was approved by the MoPSC in an order issued on August 14, 2013.
	On July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order authorizing the holding company structure (2001 Order). Laclede Gas counterclaimed stating the Staff failed to adhere to pricing provisions of the MoPSC's affiliate transaction rules and Laclede Gas' Cost Allocation Manual. By orders dated November 3, 2010 and February 4, 2011, respectively, the MoPSC dismissed Laclede's counterclaim and granted summary judgment to Staff, finding that Laclede Gas violated the terms of the 2001 Order and authorizing its General Counsel to seek penalties in court against Laclede Gas. On May 19, 2011, the MoPSC's General Counsel filed a petition seeking penalties against Laclede Gas for violation of the 2001 Order. The MoPSC and Laclede Gas agreed to hold the penalty case in abeyance pending the outcome of Laclede's appeal of the November 3, 2010 and February 4, 2011 orders. These Orders were reversed by the Cole County Circuit Court, but later upheld by the Western District Court of Appeals. On March 19, 2013, the Missouri Supreme Court declined Laclede Gas' request to review the opinion of the Western District Court of Appeals. As a result, Laclede Gas produced certain LER documentation that had been requested by the MoPSC Staff and, pursuant to agreement between the MoPSC and Laclede Gas, the MoPSC’s May 2011 penalty case was dismissed.
	On June 29, 2010, the Office of Federal Contract Compliance Programs (OFCCP) issued a Notice of Violations to Laclede Gas alleging lapses in certain employment selection procedures during a two-year period ending in February 2006. On July 2, 2013, Laclede Gas executed a Conciliation Agreement with the OFCCP in which the Company did not admit to liability, but agreed to provide make whole relief of back pay and interest to the impacted individuals from 2004-2006. The Company's agreement to provide make whole relief will not have a material effect on the consolidated financial position and results of operations, or cash flows of the Company.
	As discussed in Note 9, Derivative Instruments and Hedging Activities, the Utility enters into NYMEX exchange-traded 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 the Utility 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. As of November 26, 2013, the Utility had $0.2 million on deposit with MF Global that remains unavailable to the Utility pending final resolution by the bankruptcy trustee. As the Company has recovered 98% of the amount at issue in the MF Global bankruptcy, the total remaining exposure is not considered material.
	On February 19, 2013, Heartland Midwest, LLC, a contractor for Time Warner Cable, hit a MGE natural gas line causing a gas leak while directionally boring during underground cable installation. The natural gas leak resulted in an explosion and fire which killed one person, injured approximately seventeen (including three MGE employees who were at the scene), caused major damage to JJ's restaurant, and caused property damage to adjacent buildings. Several lawsuits have been filed in state court in Jackson County, Missouri, alleging wrongful death, personal injury, property damage, and business interruption. The lawsuits are in the early stages of discovery. While the Company's total exposure is not considered material at this time, management plans to vigorously defend the matter and will continue to evaluate its exposure as discovery proceeds. Management believes, after discussion with counsel, that the final outcome of this matter will not have a material effect on the consolidated financial position, results of operations, or cash flows of the Company.
	The Utility is involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome will not have a material effect on the financial position, results of operations, or cash flows of the Utility.

INTERIM_FINANCIAL_INFORMATION_

INTERIM FINANCIAL INFORMATION (UNAUDITED)	12 Months Ended
	Sep. 30, 2013
Quarterly Financial Information Disclosure [Abstract]	'
INTERIM FINANCIAL INFORMATION	'
	INTERIM FINANCIAL INFORMATION (UNAUDITED)
	In the opinion of the Utility, the quarterly information presented below for fiscal years 2013 and 2012 includes all adjustments (consisting of only normal recurring accruals) necessary for a fair statement of the results of operations for such periods. Variations in operations reported on a quarterly basis primarily reflect the seasonal nature of the business of the Utility.
	(Thousands)
	Three Months Ended	Dec. 31		31-Mar		30-Jun		Sept. 30
	Fiscal Year 2013
	Total Operating Revenues	$	251,934	$	364,145	$	131,757	$	111,529
	Operating Income (Loss)	42,052		50,691		7,154		(12,353		)
	Net Income (Loss)	25,743		29,775		3,765		(10,518		)
	Three Months Ended	Dec. 31		31-Mar		30-Jun		Sept. 30
	Fiscal Year 2012
	Total Operating Revenues	$	251,983	$	298,897	$	117,771	$	98,976
	Operating Income (Loss)	37,522		44,553		9,708		(973		)
	Net Income (Loss)	21,697		25,925		4,630		(2,353		)
	All quarters of 2013 reflect transaction costs incurred associated with the acquisition of MGE. The fourth quarter of 2013 includes one month of activity of the operations of MGE, significant transaction costs incurred in the quarter and the interest impact of the debt issued in the quarter. Total impact of all of these during the quarter was a decrease in net income of $5.5 million.

SCHEDULE_II

SCHEDULE II	12 Months Ended
	Sep. 30, 2013
Valuation and Qualifying Accounts [Abstract]	'
SCHEDULE II	'
	SCHEDULE II
	LACLEDE GAS COMPANY
	RESERVES
	FOR THE YEARS ENDED SEPTEMBER 30, 2013, 2012, AND 2011
	COLUMN A	COLUMN B		COLUMN C						COLUMN D			COLUMN E
		BALANCE AT		ADDITIONS			CHARGED			DEDUCTIONS			BALANCE
		BEGINNING		TO			TO OTHER			FROM			AT CLOSE
	DESCRIPTION	OF PERIOD		INCOME			ACCOUNTS			RESERVES			OF PERIOD
	(Thousands of Dollars)
	YEAR ENDED SEPTEMBER 30, 2013:
	DOUBTFUL ACCOUNTS	$	7,601	$	5,584		$	8,234	(b)	$	13,477	(c)	$	7,942
	MISCELLANEOUS:
	Injuries and property damage	$	4,540	$	1,934		$	—		$	2,135	(d)	$	4,339
	Deferred compensation	14,205		1,781			—			1,306			14,680
	Group medical claims incurred but not reported	1,560		17,205			—			16,116		(d)	2,649
	TOTAL	$	20,305	$	20,920	(a)	$	—	(a)	$	19,557	(a)	$	21,668
	YEAR ENDED SEPTEMBER 30, 2012:
	DOUBTFUL ACCOUNTS	$	9,969	$	6,011		$	10,145	(b)	$	18,524	(c)	$	7,601
	MISCELLANEOUS:
	Injuries and property damage	$	3,603	$	3,150		$	—		$	2,213	(d)	$	4,540
	Deferred compensation	13,474		1,756			—			1,025			14,205
	Group medical claims incurred but not reported	1,300		15,381			—			15,121		(d)	1,560
	TOTAL	$	18,377	$	20,287		$	—		$	18,359		$	20,305
	YEAR ENDED SEPTEMBER 30, 2011:
	DOUBTFUL ACCOUNTS	$	10,176	$	7,257		$	11,340	(b)	$	18,804	(c)	$	9,969
	MISCELLANEOUS:
	Injuries and property damage	$	3,228	$	2,416		$	—		$	2,041	(d)	$	3,603
	Deferred compensation	12,571		1,893			—			990			13,474
	Group medical claims incurred but not reported	1,450		14,171			—			14,321		(d)	1,300
	TOTAL	$	17,249	$	18,480		$	—		$	17,352		$	18,377
	(a)	Totals for the year ended September 30, 2013 includes one month of MGE activity.
	(b)	Accounts reinstated, cash recoveries, etc.
	(c)	Accounts written off.
	(d)	Claims settled, less reimbursements from insurance companies.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Business Combinations Policy [Policy Text Block]	'
	BUSINESS COMBINATIONS - The Company's acquisition of MGE was accounted for by the Company using business combination accounting. Under this method, the purchase price paid by the acquirer is allocated to the assets acquired and liabilities assumed as of the acquisition date based on their fair value. For additional information on the Company's acquisition of MGE, refer to Note 2, Acquisition of MGE.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	'
	GOODWILL - Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. Laclede Group recorded $247.1 million of goodwill as part of the MGE acquisition. which has been assigned to the Utility within the company’s Gas Utility segment.
BASIS OF PRESENTATION	'
	BASIS OF PRESENTATION - In compliance with generally accepted accounting principles (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 financial statements. Transactions with associated companies include sales of natural gas from the Utility to Laclede Energy Resources, Inc. (LER), sales of natural gas from LER to the Utility, and transportation services provided by Laclede Pipeline Company to the Utility. For fiscal years 2013, 2012, and 2011, sales of natural gas from the Utility to LER were $10.5 million, $1.2 million, and $1.6 million, respectively. Sales of natural gas from LER to the Utility during fiscal years 2013, 2012, and 2011 were $24.2 million, $16.5 million, and $24.3 million, respectively. Other services provided by Laclede Group's other subsidiaries to the Utility during fiscal years 2013, 2012, and 2011 were $1.6 million, $1.0 million, $1.0 million, respectively.
	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 $46.7 million and $37.1 million, at September 30, 2013 and 2012, respectively. The interest rate on these borrowings was 0.3% and 0.2% at September 30, 2013 and 2012, respectively. Advances under this note are due and payable on demand.
NATURE OF OPERATIONS	'
	NATURE OF OPERATIONS - The Utility serves St. Louis and eastern Missouri through Laclede Gas and serves Kansas City and western Missouri through Missouri Gas Energy. Together they provide more than 1.13 million residential, commercial and industrial customers with safe and reliable natural gas service. As an adjunct to its gas distribution business, the Utility operates an underground natural gas storage field. The non-regulated activities of the Utility are described in Note 12, Information by Operating Segment, and are included in the Other column.
USE OF ESTIMATES	'
	USE OF ESTIMATES - The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.
SYSTEM OF ACCOUNTS	'
	SYSTEM OF ACCOUNTS - The accounts of the Utility are maintained in accordance with the Uniform System of Accounts prescribed by the Missouri Public Service Commission (MoPSC or Commission), which system substantially conforms to that prescribed by the Federal Energy Regulatory Commission (FERC).
UTILITY PLANT, DEPRECIATION AND AMORTIZATION	'
	UTILITY PLANT, DEPRECIATION AND AMORTIZATION - Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct labor and materials, allocable overheads, and an allowance for funds used during construction. The costs of units of property retired, replaced, or renewed are removed from utility plant and are charged to accumulated depreciation. Maintenance and repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expenses.
	Utility plant is depreciated on a straight-line basis at rates based on estimated service lives of the various classes of property. In fiscal year 2013, annual depreciation and amortization expense averaged 3.2% of the original cost of depreciable and amortizable property, compared to 3.1% in both fiscal years 2012 and 2011.
	The Utility’s capital expenditures were $128.5 million, $106.7 million, and $67.3 million for fiscal years 2013, 2012, and 2011, respectively. Additionally, the Utility had recorded accruals for capital expenditures totaling $4.7 million at September 30, 2013, $9.7 million at September 30, 2012, and $8.2 million at September 30, 2011. Accrued capital expenditures are excluded from the Statements of Cash Flows.
ASSET RETIREMENT OBLIGATIONS	'
	ASSET RETIREMENT OBLIGATIONS - The Utility records legal obligations associated with the retirement of long-lived assets in the period in which the obligations are incurred, if sufficient information exists to reasonably estimate the fair value of the obligations. Obligations are recorded as both a cost of the related long-lived asset and as a corresponding liability. Subsequently, the asset retirement costs are depreciated over the life of the asset and the asset retirement obligations are accreted to the expected settlement amounts. The Utility has recorded asset retirement obligations associated with certain safety requirements to purge and seal gas distribution mains upon retirement, the plugging and abandonment of storage wells and other storage facilities, specific service line obligations, and certain removal and disposal obligations related to components of the Utility's distribution system and general plant. As authorized by the MoPSC, the Utility accrues future asset removal costs associated with its property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities. When the Utility retires depreciable utility plant and equipment, it charges the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities. In the rate setting process, the regulatory liability is deducted from the rate base upon which the Utility has the opportunity to earn its allowed rate of return.
	As part of the MGE acquisition, the Utility has estimated the asset retirement obligation of MGE’s long-lived assets as of the acquisition date of September 1, 2013. This estimate is preliminary and will be finalized upon completion of a detailed fair value analysis that is being performed by the Company in the first quarter of fiscal 2014.
	The following table presents a reconciliation of the beginning and ending balances of Asset retirement obligations at September 30 as reported in the Balance Sheets:
	(Thousands)	2013			2012
	Asset retirement obligations, beginning of year	$	40,126		$	27,486
	Liabilities incurred during the period	801			619
	Liabilities settled during the period	(1,089		)	(601		)
	Accretion	2,312			1,636
	Revisions in estimated cash flows	—			10,986
	MGE's asset retirement obligation	32,152			—
	Asset retirement obligations, end of year	$	74,302		$	40,126
REGULATED OPERATIONS	'
	REGULATED OPERATIONS - The Utility accounts for its regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (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 Balance Sheets as of September 30:
	(Thousands)	2013			2012
	Regulatory Assets:
	Future income taxes due from customers	$	112,902		$	118,997
	Pension and postretirement benefit costs	381,395			304,446
	Unamortized purchased gas adjustments	17,533			40,674
	Purchased gas costs	18,249			18,386
	Compensated absences	8,004			7,836
	Cold weather rule	—			—
	Other	25,387			6,382
	Total Regulatory Assets	$	563,470		$	496,721
	Regulatory Liabilities:
	Unamortized investment tax credits	$	2,900		$	3,113
	Accrued cost of removal	59,066			55,103
	Other	2,877			1,216
	Total Regulatory Liabilities	$	64,843		$	59,432
	The regulatory assets are expected to be recovered in rates charged to customers. A portion of the Company's regulatory assets are not earning a return; however, these regulatory assets are expected to be recovered from customers in future rates. Excluding deferred income taxes and purchased gas adjustment items, as of September 30, 2013 and 2012, approximately $17.2 million and $7.8 million, respectively, of regulatory assets were not earning a rate of return. The Company expects these items to be recovered over a period not to exceed 15 years consistent with precedent set by the Commission. The portion of the regulatory asset related to pensions and other postemployment benefits that relates to unfunded differences between the projected benefit obligation and plan assets also does not earn a rate of return.
	As authorized by the MoPSC, the Utility discontinued deferring certain costs for future recovery, as expenses associated with those specific areas were included in approved rates effective December 27, 1999. Previously deferred costs of $10.5 million are being recovered and amortized on a straight-line basis over a fifteen-year period, without return on investment. Amortization of these costs totaled $9.7 million from December 27, 1999 through September 30, 2013.
NATURAL GAS STORED UNDERGROUND	'
	NATURAL GAS STORED UNDERGROUND - For Laclede Gas, inventory of natural gas in storage is priced on a last-in, first-out (LIFO) basis and inventory of propane gas in storage is priced on a first-in, first-out (FIFO) basis. For MGE, inventory of natural gas in storage is priced on a weighted average cost basis. The replacement cost of natural gas stored underground for current use at September 30, 2013 and September 30, 2012 was less than the LIFO cost by $13.3 million and $24.3 million, respectively. The carrying value of the Utility inventory is not adjusted to the lower of cost or market prices because, pursuant to both Laclede Gas' and MGE's Purchased Gas Adjustment (PGA) Clauses, actual gas costs are recovered in customer rates.
REVENUE RECOGNITION	'
	REVENUE RECOGNITION - The Utility reads meters and bills its customers on monthly cycles. The Utility records its utility operating revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at September 30, 2013 and 2012, for the Utility, were $25.2 million and $11.6 million, respectively.
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT	'
	PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT – As authorized by the MoPSC, the PGA Clause allows the Utility to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. To better match customer billings with market natural gas prices, the Utility is allowed to file to modify, on a periodic basis, the level of gas costs in its PGA. Certain provisions of the PGA Clause are included below:
	•	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. The MoPSC clarified that costs, cost reductions, and carrying costs associated with the Utility’s use of natural gas derivative instruments are gas costs recoverable through the PGA mechanism.
	•	The tariffs allow the Utility flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months.
	•	The Utility is authorized to recover gas inventory carrying costs through its PGA rates to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The Utility is also authorized to apply carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, including cash payments for margin deposits.
	•	The MoPSC approved a plan applicable to Laclede Gas’ gas supply commodity costs under which it retains a portion of cost savings associated with the acquisition of natural gas below an established benchmark level. This gas supply cost management program allows Laclede Gas to retain 10% of cost savings, up to a maximum of $3.0 million annually. Laclede Gas did not record any income under the plan during the three fiscal years reported. Income recorded under the plan, if any, is included in Utility Operating Revenues on the Statements of Income.
	Pursuant to the provisions of the PGA Clause, the difference between actual costs incurred and costs recovered through the application of the PGA are reflected as a deferred charge or credit at the end of the fiscal year. These costs include costs and cost reductions associated with the use of derivative instruments and gas inventory carrying costs, amounts due to or from customers related to operation of the gas supply cost management program, refunds received from the Utility’s suppliers in connection with gas supply, transportation, and storage services, and carrying costs on such over- or under-recoveries. At that time, the balance is classified as a current asset or current liability and recovered from, or credited to, customers over an annual period commencing in November. The balance in the current account is amortized as amounts are reflected in customer billings. The PGA Clause also provides for the treatment of income from off-system sales and capacity release revenues. Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November. The customer share of such income is determined in accordance with the tables below, which is shown for each legacy company (the Utility and MGE) under which the PGA Clauses were approved by the MoPSC.
	Laclede Gas
	Pre-tax Income	Customer Share	Company Share
	First $2 million	100%	—%
	Next $2 million	80%	20%
	Next $2 million	75%	25%
	Amounts exceeding $6 million	70%	30%
	MGE
	Pre-tax Income	Customer Share	Company Share
	First $1.2 million	85%	15%
	Next $1.2 million	80%	20%
	Next $1.2 million	75%	25%
	Amounts exceeding $3.6 million	70%	30%
INCOME TAXES	'
	INCOME TAXES - The Utility has elected, for tax purposes only, various accelerated depreciation provisions of the Internal Revenue Code. In addition, certain other costs are expensed currently for tax purposes while being deferred for book purposes. GAAP permits the benefit from a tax position to be recognized only if, and to the extent that, it is more likely than not that the tax position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Unrecognized tax benefits and related interest and penalties, if any, are recorded as liabilities or as a reduction to deferred tax assets. The Utility records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the tax basis and the related carrying amounts of assets and liabilities in the financial statements. Changes in enacted tax rates, if any, and certain property basis differences are reflected by entries to regulatory asset or regulatory liability accounts.
	The Utility's investment tax credits utilized prior to 1986 have been deferred and are being amortized in accordance with regulatory treatment over the useful life of the related property.
	Laclede Group files a consolidated federal income tax return and allocates income taxes to the Utility and its other subsidiaries as if each entity were a separate taxpayer.
CASH AND CASH EQUIVALENTS	'
	CASH AND CASH EQUIVALENTS - All highly liquid debt instruments purchased with original maturities of three months or less are considered to be cash equivalents. Such instruments are carried at cost, which approximates market value. Outstanding checks on the Utility’s controlled disbursement bank accounts in excess of funds on deposit create book overdrafts (which are funded at the time checks are presented for payment) and are classified as Other in the Current Liabilities section of the Balance Sheets. Changes in book overdrafts between periods are reflected as Financing Activities in the Statements of Cash Flows.
GROSS RECEIPTS AND SALES TAXES	'
	GROSS RECEIPTS AND SALES 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 Income. Amounts recorded in Utility Operating Revenues were $40.8 million, $35.9 million, and $43.5 million for fiscal years 2013, 2012, and 2011, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
	Sales taxes imposed on applicable Utility sales are billed to customers. These amounts are not recorded in the Statements of Income, but are recorded as tax collections payable and included in the Other line of the Current Liabilities section of the Balance Sheets.
ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS	'
	ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. The Utility’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses, as approved by the MoPSC.
GROUP MEDICAL AND WORKERS' COMPENSATION RESERVES	'
	GROUP MEDICAL AND WORKERS’ COMPENSATION RESERVES - The Utility self-insures its group medical and workers’ compensation costs and carries stop-loss coverage in relation to medical claims and workers’ compensation claims. Reserves for amounts incurred but not reported are established based on historical cost levels and lags between occurrences and reporting.
FAIR VALUE MEASUREMENTS	'
	FAIR VALUE MEASUREMENTS – Certain assets and liabilities are recognized or disclosed at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The levels of the hierarchy are described below:
	•	Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities.
	•	Level 2 – Pricing inputs other than quoted prices included within Level 1, which are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data.
	•	Level 3 – Pricing that is based upon inputs that are generally unobservable that are based on the best information available and reflect management’s assumptions about how market participants would price the asset or liability.
	Assessment of the significance of a particular input to the fair value measurements may require judgment and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. Additional information about fair value measurements is provided in Note 3, Pension Plans and Other Postretirement Benefits, Note 7, Fair Value of Financial Instruments, and Note 8, Fair Value Measurements.
STOCK-BASED COMPENSATION	'
	STOCK-BASED COMPENSATION - Officers and employees of the Utility, as determined by the Compensation Committee of Laclede Group’s Board of Directors, are eligible to be selected for awards under the Laclede Group 2006 Equity Incentive Plan (2006 Plan). Grants of awards may be earned by achieving performance objectives and/or other criteria as determined by the Compensation Committee. Awards may include restricted stock, restricted stock units, qualified and non-qualified stock options, stock appreciation rights, and performance shares payable in stock, cash, or a combination of both. The 2006 Plan generally provides a minimum vesting period of at least three years for each type of award.
	For Laclede Group’s non-employee directors, shares were awarded under the Restricted Stock Plan for Non-Employee Directors (Plan) prior to February 1, 2012, but any future awards will be granted under the 2006 Plan, as a result of plan amendments approved by Laclede Group’s shareholders. Awards previously granted under the Plan vest depending upon the participant’s age upon entering the plan and years of service as a director. Shares of the Utility common stock, which are 100% owned by Laclede Group, are not transacted under the plans.
	Laclede Group accounts for awards under these plans in accordance with GAAP, and allocates applicable compensation costs to its subsidiaries. For awards made to its employees, the Utility records its allocation of compensation cost from Laclede Group with a corresponding increase to additional paid-in capital.
	The amounts of compensation cost allocated to the Utility for share-based compensation arrangements are presented below:
	(Thousands)	2013			2012			2011
	Total equity compensation cost	$	3,843		$	2,303		$	3,383
	Compensation cost capitalized	(1,366		)	(808		)	(924		)
	Compensation cost recognized in net income	2,477			1,495			2,459
	Income tax benefit recognized in net income	(948		)	(577		)	(948		)
	Compensation cost recognized in net income, net of income tax	$	1,529		$	918		$	1,511
	As of September 30, 2013, there was $4.2 million in unrecognized compensation cost related to nonvested share-based compensation arrangements that is expected to be allocated to the Utility over a weighted average period of 2.0 years.
New Accounting Pronouncements, Policy [Policy Text Block]	'
	NEW ACCOUNTING STANDARDS – In December 2011, the FASB issued ASU No. 2011-11, “Disclosures about Offsetting Assets and Liabilities,” to amend ASC Topic 210, “Balance Sheet,” to require additional disclosures about financial instruments and derivative instruments that have been presented on a net basis (offset) in the balance sheet. Additionally, information about financial instruments and derivative instruments that are subject to enforceable master netting arrangements or similar agreements, irrespective of whether they are presented net in the balance sheet, is required to be disclosed. The ASU impacts disclosures only and will not require any changes to financial statement presentation. The Company will present the new disclosures retrospectively beginning in the first quarter of fiscal year 2014.
	In February 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” by requiring entities to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to provide information on significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. The Company will present the new disclosures prospectively beginning in the first quarter of fiscal year 2014.

ACQUISITION_OF_MGE_Tables

ACQUISITION OF MGE (Tables)	12 Months Ended
	Sep. 30, 2013
Business Acquisition [Line Items]	'
Schedule of pro forma information, revenues and earnings of acquiree since acquisition date, actual	'
	The amount of revenue and earnings of MGE included in our Statements of Consolidated Income subsequent to the September 1, 2013 acquisition date are as follows:
	(Thousands)	September 1, 2013 - September 30, 2013
	Total net revenues	$	21,985
	Net Income	1,795
Schedule of Pro Forma Information	'
	The following unaudited pro forma financial information presents the combined results of operations as if the acquisition had occurred on October 1, 2011. The pro forma financial information does not reflect the costs of any integration activities. The pro forma results include estimates and assumptions, which management believes are reasonable. The unaudited pro forma financial information below is not necessarily indicative of either future results of operations or results that might have been achieved had MGE been part of the Utility as of the beginning of fiscal year 2012.
		Twelve Months Ended September 30,
	(Thousands)	2013		2012
	Total net revenues	$	1,518,201	$	1,581,425
	Net Income	83,642		81,722
Missouri Gas Energy (MGE) [Member]	'
Business Acquisition [Line Items]	'
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 the acquisition:
	(Thousands)
	Assets:
	Utility plant	$	671,793
	Non-utility property	238
	Other investments	3,096
	Goodwill	247,078
	Other Property and Investments	922,205
	Accounts receivable:
	Utility	19,963
	Other	6,119
	Delayed customer billings	10,701
	Inventories:
	Natural gas stored underground	58,679
	Materials and supplies at average cost	3,988
	Prepayments and other	487
	Total Current Assets	99,937
	Deferred Charges:
	Regulatory assets	84,014
	Other	4,928
	Total Deferred Charges	88,942
	Total Assets Acquired	$	1,111,084
	Liabilities:
	Accounts payable	$	20,154
	Wages and compensation accrued	5,088
	Customer deposits	8,362
	Interest accrued	183
	Taxes accrued	17,197
	Other	12,620
	Total Current Liabilities	63,604
	Pension and postretirement benefit costs	24,466
	Asset retirement obligations	32,056
	Regulatory liabilities	2,249
	Other	13,709
	Total Deferred Credits and Other Liabilities	72,480
	Total Liabilities Assumed	$	136,084
	Net Assets Acquired	$	975,000

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Asset Retirement Obligations	'
	The following table presents a reconciliation of the beginning and ending balances of Asset retirement obligations at September 30 as reported in the Balance Sheets:
	(Thousands)	2013			2012
	Asset retirement obligations, beginning of year	$	40,126		$	27,486
	Liabilities incurred during the period	801			619
	Liabilities settled during the period	(1,089		)	(601		)
	Accretion	2,312			1,636
	Revisions in estimated cash flows	—			10,986
	MGE's asset retirement obligation	32,152			—
	Asset retirement obligations, end of year	$	74,302		$	40,126
Regulatory Assets and Liabilities	'
	The following regulatory assets and regulatory liabilities were reflected in the Balance Sheets as of September 30:
	(Thousands)	2013			2012
	Regulatory Assets:
	Future income taxes due from customers	$	112,902		$	118,997
	Pension and postretirement benefit costs	381,395			304,446
	Unamortized purchased gas adjustments	17,533			40,674
	Purchased gas costs	18,249			18,386
	Compensated absences	8,004			7,836
	Cold weather rule	—			—
	Other	25,387			6,382
	Total Regulatory Assets	$	563,470		$	496,721
	Regulatory Liabilities:
	Unamortized investment tax credits	$	2,900		$	3,113
	Accrued cost of removal	59,066			55,103
	Other	2,877			1,216
	Total Regulatory Liabilities	$	64,843		$	59,432
Off-System Sales	'
	Laclede Gas
	Pre-tax Income	Customer Share	Company Share
	First $2 million	100%	—%
	Next $2 million	80%	20%
	Next $2 million	75%	25%
	Amounts exceeding $6 million	70%	30%
	MGE
	Pre-tax Income	Customer Share	Company Share
	First $1.2 million	85%	15%
	Next $1.2 million	80%	20%
	Next $1.2 million	75%	25%
	Amounts exceeding $3.6 million	70%	30%
	See the Regulatory and Other Matters section on page 28 of this report for additional information on Laclede Gas' off-system sales.
Compensation cost allocated to the Utility for share-based compensation arrangements	'
	The amounts of compensation cost allocated to the Utility for share-based compensation arrangements are presented below:
	(Thousands)	2013			2012			2011
	Total equity compensation cost	$	3,843		$	2,303		$	3,383
	Compensation cost capitalized	(1,366		)	(808		)	(924		)
	Compensation cost recognized in net income	2,477			1,495			2,459
	Income tax benefit recognized in net income	(948		)	(577		)	(948		)
	Compensation cost recognized in net income, net of income tax	$	1,529		$	918		$	1,511

PENSION_PLANS_AND_OTHER_POSTRE1

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS (Tables)	12 Months Ended
	Sep. 30, 2013
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'
Net Periodic Cost	'
	Net periodic postretirement benefit costs consisted of the following components:
	(Thousands)	2013				2012				2011
	Service cost – benefits earned during the period	$	10,162			$	8,060			$	7,676
	Interest cost on accumulated postretirement benefit obligation	5,234				5,521				4,843
	Expected return on plan assets	(4,447		)		(3,965		)		(3,646		)
	Amortization of transition obligation	93				136				136
	Amortization of prior service credit	3				(2,072		)		(2,328		)
	Amortization of actuarial loss	5,300				4,261				4,443
	Sub-total	16,345				11,941				11,124
	Regulatory adjustment	(6,821		)		(2,417		)		(2,071		)
	Net postretirement benefit cost	$	9,524			$	9,524			$	9,053
	The net periodic pension costs include the following components:
	(Thousands)	2013				2012				2011
	Service cost – benefits earned during the period	$	9,209			$	9,203			$	9,553
	Interest cost on projected benefit obligation	16,959				19,358				18,819
	Expected return on plan assets	(19,358		)		(19,595		)		(18,849		)
	Amortization of prior service cost	544				592				642
	Amortization of actuarial loss	10,724				9,040				10,228
	Loss on lump-sum settlements	26,996				20,051				943
	Sub-total	45,074				38,649				21,336
	Regulatory adjustment	(27,532		)		(18,579		)		(7,066		)
	Net pension cost	$	17,542			$	20,070			$	14,270
Other changes in plan assets and benefit obligations recognized in other comprehensive income	'
	Other changes in plan assets and postretirement benefit obligations recognized in other comprehensive income include the following:
	(Thousands)	2013				2012				2011
	Current year actuarial loss	$	16,300			$	10,138			$	1,696
	Amortization of actuarial loss	(5,300		)		(4,261		)		(4,443		)
	Amortization of prior service credit	(3		)		2,072				2,328
	Amortization of transition obligation	(93		)		(136		)		(136		)
	Sub-total	10,904				7,813				(555		)
	Regulatory adjustment	(10,904		)		(7,813		)		555
	Total recognized in other comprehensive income	$	—			$	—			$	—
	Other changes in plan assets and pension benefit obligations recognized in other comprehensive income include the following:
	(Thousands)	2013				2012				2011
	Current year actuarial loss (gain)	$	17,030			$	32,884			$	(13,485	)
	Amortization of actuarial loss	(10,724		)		(29,091		)		(11,171		)
	Acceleration of loss recognized due to settlement	(26,996		)		—				—
	Amortization of prior service cost	(544		)		(592		)		(642		)
	Sub-total	(21,234		)		3,201				(25,298		)
	Regulatory adjustment	21,159				(3,510		)		24,533
	Total recognized in other comprehensive income	$	(75	)		$	(309	)		$	(765	)
Reconciliation of the beginning and Ending Balances of Benefit Obligation	'
	The following table sets forth the reconciliation of the beginning and ending balances of the pension benefit obligation at September 30:
	(Thousands)	2013				2012
	Benefit obligation at beginning of year	$	412,171			$	384,163
	Service cost	9,209				9,203
	Interest cost	16,959				19,358
	Actuarial loss (gain)	(23,921		)		52,161
	MGE acquisition	151,424				—
	Settlement loss	24,999				14,348
	Gross benefits paid *	(87,023		)		(67,062		)
	Benefit obligation at end of year	$	503,818			$	412,171
	Accumulated benefit obligation at end of year	$	444,129			$	353,061
	*	Includes $79,484 and $60,085 lump-sum payments recognized as settlements in fiscal years 2013 and 2012, respectively.
	The following table sets forth the reconciliation of the beginning and ending balances of the postretirement benefit obligation at September 30:
	(Thousands)	2013				2012
	Benefit obligation at beginning of year	$	127,217			$	103,991
	Service cost	10,162				8,060
	Interest cost	5,234				5,521
	Actuarial loss (gain)	17,514				15,895
	MGE acquisition	28,444				—
	Gross benefits paid	(8,449		)		(6,250		)
	Benefit obligation at end of year	$	180,122			$	127,217
Fair Value of Plan Assets	'
	The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:
	(Thousands)	2013				2012
	Fair value of plan assets at beginning of year	$	274,130			$	247,959
	Actual return on plan assets	3,387				53,220
	Employer contributions	27,991				40,013
	MGE acquisition	126,958				—
	Gross benefits paid *	(87,023		)		(67,062		)
	Fair value of plan assets at end of year	$	345,443			$	274,130
	Funded status of plans, end of year	$	(158,375	)		$	(138,041	)
	*
	The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:
	(Thousands)	2013				2012
	Fair value of plan assets at beginning of year	$	67,442			$	51,744
	Actual return on plan assets	5,660				9,722
	Employer contributions	16,596				12,226
	MGE acquisition	30,396				—
	Gross benefits paid	(8,449		)		(6,250		)
	Fair value of plan assets at end of year	$	111,645			$	67,442
	Funded status of plans, end of year	$	(68,477	)		$	(59,775	)
Amounts recognized in balance sheets	'
	The following table sets forth the amounts recognized in the Balance Sheets at September 30:
	(Thousands)	2013				2012
	Current liabilities	$	(442	)		$	(468	)
	Noncurrent liabilities	(157,933		)		(137,573		)
	Total	$	(158,375	)		$	(138,041	)
	Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of:
	Net actuarial loss	$	115,775			$	136,464
	Prior service costs	4,467				5,011
	Sub-total	120,242				141,475
	Adjustments for amounts included in Regulatory Assets	(116,686		)		(137,845		)
	Total	$	3,556			$	3,630
	The following table sets forth the amounts recognized in the Balance Sheets at September 30:
	(Thousands)	2013				2012
	Noncurrent assets	$	2,543			$	—
	Current liabilities	(300		)		(790		)
	Noncurrent liabilities	(70,720		)		(58,985		)
	Total	$	(68,477	)		$	(59,775	)
	Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic postretirement benefit cost consist of:
	Net actuarial loss	$	63,573			$	52,573
	Prior service credit	(27		)		(24		)
	Transition obligation	—				93
	Sub-total	63,546				52,642
	Adjustments for amounts included in Regulatory Assets	(63,546		)		(52,642		)
	Total	$	—			$	—
Pre-tax amounts amortized from accumulated other comprehensive income into net periodic cost	'
	At September 30, 2013, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic postretirement benefit cost during fiscal year 2014:
	(Thousands)
	Amortization of net actuarial loss	$	6,021
	Amortization of prior service cost	(4		)
	Sub-total	6,017
	Regulatory adjustment	(6,017		)
	Total	$	—
	At September 30, 2013, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic pension cost during fiscal year 2014:
	(Thousands)
	Amortization of net actuarial loss	$	7,088
	Amortization of prior service cost	497
	Sub-total	7,585
	Regulatory adjustment	(7,196		)
	Total	$	389
Assumptions used to calculate net periodic cost and benefit obligations.	'
	The assumptions used to calculate net periodic pension costs are as follows:
		2013		2012		2011
	Weighted average discount rate *	3.95%		5.10%		4.75%
	Weighted average rate of future compensation increase	3.00%		3.00%		3.00%
	Expected long-term rate of return on plan assets	7.75%		7.75%		8.00%
	The assumptions used to calculate net periodic postretirement benefit costs are as follows:
		2013			2012			2011
	Weighted average discount rate *	3.8	%		5.05	%		4.7	%
	Weighted average rate of future compensation increase	3	%		3	%		3	%
	Expected long-term rate of return on plan assets **	7.75	%		7.75	%		8	%
	The assumptions used to calculate the accumulated postretirement benefit obligations are as follows:
		2013		2012
	Weighted average discount rate *	4.60%		3.80%
	Weighted average rate of future compensation increase	3.00%		3.00%
	The assumptions used to calculate the benefit obligations are as follows:
		2013		2012
	Weighted average discount rate *	4.70%		3.95%
	Weighted average rate of future compensation increase	3.00%		3.00%
Projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have projected benefit obligation and accumulated benefit obligation in excess of plan assets	'
	Following are the projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have a projected benefit obligation and an accumulated benefit obligation in excess of plan assets:
	(Thousands)	2013				2012
	Projected benefit obligation	$	503,818			$	412,171
	Accumulated benefit obligation	444,129				353,061
	Fair value of plan assets	345,443				274,130
Targeted and actual plan assets by category	'
	Following are the targeted and actual plan assets by category as of September 30 of each year:
		2014			2013			2012
		Target			Actual			Actual
	Equity Securities	60	%		59	%		59	%
	Debt Securities	40	%		39	%		39	%
	Other	—	%		2	%		2	%
	Total	100	%		100	%		100	%
	Following are the targeted and actual plan assets by category as of September 30 of each year:
		2014			2013			2012
		Target			Actual			Actual
	Growth Strategy
	Equity Markets	42.5	%		45.9	%		37.3	%
	Commodities	2.5	%		1.6	%		2.2	%
	Real Estate	2.5	%		3	%		2.2	%
	Inflation-Indexed Securities	2.5	%		1.4	%		2.2	%
	Debt Securities	50	%		43.3	%		41.1	%
	Other*	—	%		4.8	%		15	%
	Total	100	%		100	%		100	%
Expected benefit payments for the succeeding five fiscal years	'
	Following are expected postretirement benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:
	(Millions)	Benefits Paid				Benefits Paid
		from				from Laclede Gas
		Qualified Trust				Funds
	2014	$	9.5			$	0.3
	2015	9.9				0.3
	2016	10.7				0.3
	2017	11.7				0.4
	2018	12.8				0.4
	2019 – 2023	84.1				2.2
	Following are expected pension benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:
					Pensions from
	(Millions)	Pensions from			Laclede Gas
		Qualified Trust			Funds
	2014	22.9			0.4
	2015	25.3			0.5
	2016	27.2			0.5
	2017	30.8			0.6
	2018	34.2			0.6
	2019 – 2023	227.2			4.5
Assumed medical cost trend rates and effect of an assumed 1% changed in assumed medical cost trend.	'
	The assumed medical cost trend rates at September 30 for the Utility's postretirement plans are as follows:
		2013		2012
	Medical cost trend assumed for next year	7.50%		7.00%
	Rate to which the medical cost trend rate is assumed to decline (the ultimate medical cost trend rate)	5.00%		5.00%
	Year the rate reaches the ultimate trend	2020		2017
	The following table presents the effect of an assumed 1% change in the assumed medical cost trend rate:
	(Thousands)	1% Increase				1% Decrease
	Effect on net periodic postretirement benefit cost	$	1,520			$	(1,390	)
	Effect on accumulated postretirement benefit obligation	7,060				(6,580		)
Fair value measurements of plan assets	'
	The table below categorizes the fair value measurements of the Utility's pension plan assets:
	(Thousands)	Quoted Prices in Active Markets (Level 1)				Significant				Significant Unobservable Inputs			Total
						Observable Inputs				(Level 3)
						(Level 2)
	As of September 30, 2013
	Cash and cash equivalents	$	18,177			$	—			$	—		$	18,177
	Stock/Bond mutual fund	—				115,817				—			115,817
	Debt Securities
	U.S. bond mutual funds	17,682				—				—			17,682
	U.S. government	—				55,743				—			55,743
	U.S. corporate	—				110,925				—			110,925
	U.S. municipal	—				6,799				—			6,799
	International	—				21,594				—			21,594
	Derivative instruments (a)	—				(1,294		)		—			(1,294		)
	Total	$	35,859			$	309,584			$	—		$	345,443
	As of September 30, 2012
	Cash and cash equivalents	$	57,614			$	—			$	—		$	57,614
	Debt Securities
	U.S. bond mutual funds	36,767				—				—			36,767
	U.S. government	—				57,925				—			57,925
	U.S. corporate	—				93,169				—			93,169
	U.S. municipal	—				9,493				—			9,493
	International	—				18,885				—			18,885
	Derivative instruments (b)	—				277				—			277
	Total	$	94,381			$	179,749			$	—		$	274,130
	(a)   Derivative assets of $4,186 net of cash margin payable of $5,480.
	(b)   Derivative assets of $3,027 net of cash margin receivable of $2,750.
	The table below categorizes the fair value measurements of the Utility's postretirement plan assets:
	(Thousands)	Quoted Prices in Active Markets (Level 1)				Significant Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)			Total
	As of September 30, 2013
	Cash and cash equivalents	$	1,411			$	—			$	—		$	1,411
	U.S. stock/bond mutual fund	110,234				—				—			110,234
	Total	$	111,645			$	—			$	—		$	111,645
	As of September 30, 2012
	Cash and cash equivalents	$	1,106			$	—			$	—		$	1,106
	U.S. stock/bond mutual fund	66,336				—				—			66,336
	Total	$	67,442			$	—			$	—		$	67,442

STOCKHOLDERS_EQUITY_Tables

STOCKHOLDER'S EQUITY (Tables)	12 Months Ended
	Sep. 30, 2013
Stockholders' Equity Note [Abstract]	'
Accumulated other comprehensive income (loss), net of taxes	'
	The components of accumulated other comprehensive income (loss), net of income taxes, recognized in the Balance Sheets at September 30 were as follows:
	(Thousands)				Defined Benefit Pension and Other			Total
		Net Unrealized Gains (Losses) on Cash Flow Hedges			Postretirement
					Benefit Plans
	Balance, September 30, 2011	$	(53	)	$	(2,420	)	$	(2,473	)
	Current-period change	182			190			372
	Balance, September 30, 2012	129			(2,230		)	(2,101		)
	Current-period change	(53		)	48			(5		)
	Balance, September 30, 2013	$	76		$	(2,182	)	$	(2,106	)

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	12 Months Ended
	Sep. 30, 2013
Debt Disclosure [Abstract]	'
Maturities of long-term debt by fiscal year	'
	Maturities on long-term debt for the five fiscal years subsequent to September 30, 2013 are as follows:
	2014	—
	2015	—
	2016	—
	2017	—
	2018	$	100	million

DERIVATIVE_INSTRUMENTS_AND_HED1

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)	12 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivative Instruments and Hedging Activities	'
	The Utility’s derivative instruments consist primarily of NYMEX and OTCBB positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX and OTCBB natural gas futures positions at September 30, 2013 were as follows:
		MMBtu			Avg. Price
		(millions)			Per
					MMBtu
	NYMEX open long futures positions
	Fiscal 2014	7.26			$	3.99
	Fiscal 2015	0.94			3.84
	OTCBB open long futures positions
	Fiscal 2014	16.81			3.97
	Fiscal 2015	7.58			4.22
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 Income and Statements of Comprehensive Income
		Location of Gain (Loss)
	(Thousands)	Recorded in Income	2013				2012		2011
	Derivatives in Cash Flow Hedging Relationships
	NYMEX gasoline and heating oil contracts:
	Effective portion of gain recognized in		$	123			$	297	$	355
	OCI on derivatives
	Effective portion of gain reclassified from	Utility – Other Operation Expenses	211				—		466
	AOCI to income
	Ineffective portion of gain (loss) on derivatives	Utility – Other Operation Expenses	(127		)		175		12
	recognized in income
	Derivatives Not Designated as Hedging Instruments *
	NYMEX gasoline and heating oil contracts:
	Gain (loss) recognized in income on derivative	Other Income and (Income Deductions) - Net	$	41			$	19	$	37
	*	Gains and losses on the Utility's 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 Income. Such amounts are recognized in the Statements of Income as a component of Utility Natural and Propane Gas operating expenses when they are recovered through the PGA Clause and reflected in customer billings.
	Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2013
		Asset Derivatives				Liability Derivatives
	(Thousands)	Balance Sheet Location	Fair Value*			Balance Sheet Location	Fair Value*
	Derivatives designated as hedging instruments
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	$	105		Accounts Receivable - Other	$	—
	Derivatives not designated as hedging instruments
	NYMEX natural gas contracts	Accounts Receivable – Other	1,434			Accounts Receivable – Other	3,455
		Other Deferred Charges	32			Other Deferred Charges	—
	OTCBB natural gas contracts	Other Current Liabilities	228			Current Liabilities - Other	4,045
		Other Deferred Credits	4			Deferred Credits - Other	1,398
	Sub-total		1,698				8,898
	Total derivatives		$	1,803			$	8,898
	Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2012
		Asset Derivatives				Liability Derivatives
	(Thousands)	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Derivatives designated as hedging instruments
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	$	334		Accounts Receivable - Other	$	—
	Derivatives not designated as hedging instruments
	NYMEX natural gas contracts	Accounts Receivable - Other	7,338			Accounts Receivable - Other	9,563
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	10			Accounts Receivable - Other	—
	Sub-total		7,348				9,563
	Total derivatives		$	7,682			$	9,563
Fair Value of Derivative Instruments in the Consolidated Balance Sheet	'
	Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2013
		Asset Derivatives				Liability Derivatives
	(Thousands)	Balance Sheet Location	Fair Value*			Balance Sheet Location	Fair Value*
	Derivatives designated as hedging instruments
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	$	105		Accounts Receivable - Other	$	—
	Derivatives not designated as hedging instruments
	NYMEX natural gas contracts	Accounts Receivable – Other	1,434			Accounts Receivable – Other	3,455
		Other Deferred Charges	32			Other Deferred Charges	—
	OTCBB natural gas contracts	Other Current Liabilities	228			Current Liabilities - Other	4,045
		Other Deferred Credits	4			Deferred Credits - Other	1,398
	Sub-total		1,698				8,898
	Total derivatives		$	1,803			$	8,898
	Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2012
		Asset Derivatives				Liability Derivatives
	(Thousands)	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
	Derivatives designated as hedging instruments
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	$	334		Accounts Receivable - Other	$	—
	Derivatives not designated as hedging instruments
	NYMEX natural gas contracts	Accounts Receivable - Other	7,338			Accounts Receivable - Other	9,563
	NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	10			Accounts Receivable - Other	—
	Sub-total		7,348				9,563
	Total derivatives		$	7,682			$	9,563
	*	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 Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Utility’s net economic exposure. Refer to Note 8, 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 Balance Sheets:
	(Thousands)	2013				2012
	Fair value of asset derivatives presented above	1,803				7,682
	Fair value of cash margin receivables offset with derivatives	1,890				1,964
	Netting of assets and liabilities with the same counterparty	(3,693		)		(9,646		)
	Total	$	—			$	—
	Derivative Instrument Assets, per Balance Sheets:
	Derivative instrument assets	—				—
	Other deferred charges	—				—
	Total	$	—			$	—
	Fair value of liability derivatives presented above	8,898				9,563
	Fair Value of cash margin payables offset with derivatives	6				83
	Netting of assets and liabilities with the same counterparty	(3,693		)		(9,646		)
	Derivative instrument liabilities, per Balance Sheets*	$	5,211			$	—
	Derivative Instrument Assets, per Balance Sheets:
	Other current liabilities	3,817				—
	Other deferred credits	1,394				—
	Total	$	5,211			$	—

NOTES_PAYABLE_AND_CREDIT_AGREE1

NOTES PAYABLE AND CREDIT AGREEMENTS (Tables)	12 Months Ended
	Sep. 30, 2013
Short-term Debt [Abstract]	'
Short-term borrowings	'
	Information about the Utility’s internal and external short-term borrowings during the 12 months ended September 30, and as of September 30, is presented below for 2013 and 2012:
		Commercial Paper Borrowings	Borrowings from Laclede Group	Total Short-Term Borrowings
	Twelve Months Ended September 30, 2013
	Weighted average borrowings outstanding	$34.2 million	$29.2 million	$63.4 million
	Weighted average interest rate	0.30%	0.30%	0.30%
	Range of borrowings outstanding	$0 – $99.4 million	$0 – $91.7 million	$0 – $160.5 million
	As of September 30, 2013
	Borrowings outstanding at end of period	$74.0 million	$46.7 million	$120.7 million
	Weighted average interest rate	0.30%	0.30%	0.30%
	Twelve Months Ended September 30, 2012
	Weighted average borrowings outstanding	$43.8 million	$78.2 million	$122.0 million
	Weighted average interest rate	0.30%	0.30%	0.30%
	Range of borrowings outstanding	$0 – $133.5 million	$13.0 - $107.5 million	$59.6 - $200.1 million
	As of September 30, 2012
	Borrowings outstanding at end of period	$40.1 million	$37.1 million	$77.2 million
	Weighted average interest rate	0.20%	0.20%	0.20%

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Sep. 30, 2013
Financial Instruments, Owned, at Fair Value [Abstract]	'
Fair value - financial instruments	'
	The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis at September 30, 2013 and 2012 are as follows:
						Classification of Estimated Fair Value (a)
	(Thousands)	Carrying		Fair		Quoted		Significant Observable Inputs		Significant Unobservable Inputs
		Amount		Value		Prices in Active Markets		(Level 2)		(Level 3)
						(Level 1)
	As of September 30, 2013
	Cash and cash equivalents	$	23,916	$	23,916	$	23,892	$	24	$	—
	Short-term debt	120,729		120,729		—		120,729		—
	Long-term debt, including current portion	887,712		930,369		—		930,369		—
	As of September 30, 2012
	Cash and cash equivalents	$	2,402	$	2,402	$	2,378	$	24	$	—
	Short-term debt	77,225		77,225		—		77,225		—
	Long-term debt	364,416		452,768		—		452,768		—
	(a) The Utility adopted the provisions of ASU 2011-04 (ASC Topic 820) in the second quarter of fiscal year 2012 on a prospective basis. Accordingly, disclosures for prior periods are not required to be presented.

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements, Measured on Recurring Basis	'
	The following table categorizes the assets and liabilities in the Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.
	(Thousands)	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 September 30, 2013
	Assets
	U. S. Stock/Bond Mutual Funds	$	14,500	$	—	$	—	$	—		$	14,500
	NYMEX natural gas contracts	1,466		—		—		(1,466		)	—
	OTCBB natural gas contracts	—		232		—		(232		)	—
	NYMEX gasoline and heating oil contracts	105		—		—		(105		)	—
	Total	$	16,071	$	232	$	—	$	(1,803	)	$	14,500
	Liabilities
	NYMEX natural gas contracts	$	3,455	$	—	$	—	$	(3,455	)	$	—
	OTCBB natural gas contracts	$	—	$	5,443	$	—	$	(232	)	$	5,211
	As of September 30, 2012
	U. S. Stock/Bond Mutual Funds	$	13,187	$	—	$	—	$	—		$	13,187
	NYMEX natural gas contracts	7,338		—		—		(7,338		)	—
	NYMEX gasoline and heating	344		—		—		(344		)	—
	oil contracts
	Total	$	20,869	$	—	$	—	$	(7,682	)	$	13,187
	Liabilities
	NYMEX natural gas contracts	$	9,563	$	—	$	—	$	(9,563	)	$	—

INCOME_TAXES_Tables

INCOME TAXES (Tables)	12 Months Ended
	Sep. 30, 2013
Income Tax Disclosure [Abstract]	'
Net Provision For Income Tax	'
	The net provisions for income taxes charged during the fiscal years ended September 30, 2013, 2012, and 2011 are as follows:
	(Thousands)	2013				2012				2011
	Included in Statements of Income:
	Federal
	Current	$	(6,539	)		$	(11,288	)		$	133
	Deferred	20,103				27,186				19,848
	Investment tax credits	(213		)		(213		)		(213		)
	State and local
	Current	(984		)		(1,825		)		(152		)
	Deferred	2,284				4,600				3,380
	Total Income Tax Expense	$	14,651			$	18,460			$	22,996
Effective income tax rate variation from stated tax rate	'
	The effective income tax rate varied from the federal statutory income tax rate for each year due to the following:
		2013			2012			2011
	Federal income tax statutory rate	35	%		35	%		35	%
	State and local income taxes, net of federal
	income tax benefits	3.3			2.6			2.7
	Certain expenses capitalized on books and
	deducted on tax return	(10.8	)		(8.9	)		(6.1	)
	Taxes related to prior years	(1.6	)		(0.6	)		(0.8	)
	Other items – net	(2.8	)		(1.1	)		(0.8	)
	Effective income tax rate	23.1	%		27	%		30	%
Significant Items in Net Deferred Tax Liability	'
	The significant items comprising the net deferred tax liability recognized in the Balance Sheets as of September 30 are as follows:
	(Thousands)	2013				2012
	Deferred tax assets:
	Reserves not currently deductible	$	13,933			$	16,400
	Pension and other postretirement benefits	71,367				73,480
	Unamortized investment tax credits	1,799				1,955
	Other*	10,450				14,513
	Total deferred tax assets	97,549				106,348
	Deferred tax liabilities:
	Relating to utility property	341,975				303,332
	Regulatory pension and other postretirement benefits	124,871				121,554
	Deferred gas costs	7,112				20,652
	Other	5,396				26,414
	Total deferred tax liabilities	479,354				471,952
	Net deferred tax liability	381,805				365,604
	Net deferred tax liability – current*	(1,692		)		(10,146		)
	Net deferred tax liability – non-current*	$	380,113			$	355,458
Unrecognized Tax Benefit Reconciliation	'
	The following table presents a reconciliation of the beginning and ending balances of unrecognized tax benefits at September 30 as reported in the Balance Sheets:
	(Thousands)	2013				2012
	Unrecognized tax benefits, beginning of year	$	5,615			$	5,536
	Increases related to tax positions taken in current year	1,420				490
	Reductions due to lapse of applicable statute of limitations	(5,018		)		(411		)
	Unrecognized tax benefits, end of year	$	2,017			$	5,615

OTHER_INCOME_AND_INCOME_DEDUCT1

OTHER INCOME AND INCOME (DEDUCTIONS) NET (Tables)	12 Months Ended
	Sep. 30, 2013
Other Nonoperating Income (Expense) [Abstract]	'
Other Income and (Income Deductions) by Component	'
	(Thousands)	2013			2012			2011
	Interest income	$	947		$	1,230		$	1,057
	Net investment gain (loss)	2,544			2,626			(73		)
	Other income	377			804			53
	Other income deductions	(1,859		)	(1,955		)	(212		)
	Other Income and (Income Deductions) – Net	$	2,009		$	2,705		$	825

INFORMATION_BY_OPERATING_SEGME1

INFORMATION BY OPERATING SEGMENT (Tables)	12 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Schedule of operating segment information	'
							Adjustments &
	(Thousands)	Gas Utility		Other			Eliminations		Total
	FISCAL 2013
	Operating revenues	$	857,762	$	1,603		$	—	$	859,365
	Depreciation and amortization	48,283		—			—		48,283
	Interest income	947		—			—		947
	Interest charges	26,137		—			—		26,137
	Income tax expense	19,243		(4,592		)	—		14,651
	Net economic earnings	56,635		574			—		57,209
	Total assets	2,981,016		—			—		2,981,016
	Capital expenditures	128,496		—			—		128,496
	FISCAL 2012
	Operating revenues	$	764,651	$	2,976		$	—	$	767,627
	Depreciation and amortization	40,739		—			—		40,739
	Interest income	1,230		—			—		1,230
	Interest charges	25,156		—			—		25,156
	Income tax expense	17,393		1,067			—		18,460
	Net economic earnings	48,089		1,700			—		49,789
	Total assets	1,758,952		1,200			—		1,760,152
	Capital expenditures	106,734		—			—		106,734
	FISCAL 2011
	Operating revenues	$	913,190	$	19,138		$	—	$	932,328
	Depreciation and amortization	39,214		—			—		39,214
	Interest income	1,057		—			—		1,057
	Interest charges	25,544		—			—		25,544
	Income tax expense	18,694		4,302			—		22,996
	Net economic earnings	46,952		6,851		*	—		53,803
	Total assets	1,641,386		1,660			—		1,643,046
	Capital expenditures	67,304		—			—		67,304
	*	Net economic earnings include income realized by the Utility from separate non-regulated sales of propane inventory no longer needed to serve utility customers, of which occurred in fiscal year 2011. These transactions resulted in after-tax earnings totaling $6.1 million.
Schedule of the reconciliation of net economic earnings to net income	'
	Reconciliation of Net Income to Net Economic Earnings
	(Thousands)	2013		2012			2011
	Net Income (GAAP)	$	48,765	$	49,899		$	53,777
	Unrealized loss (gain) on energy-related	100		(110		)	26
	derivative contracts, net of tax
	Acquisition, divestiture and restructuring activities	8,344		—			—
	Net Economic Earnings (Non-GAAP)	$	57,209	$	49,789		$	53,803

INTERIM_FINANCIAL_INFORMATION_1

INTERIM FINANCIAL INFORMATION (UNAUDITED) (Unaudited) (Tables)	12 Months Ended
	Sep. 30, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information Table	'
	(Thousands)
	Three Months Ended	Dec. 31		31-Mar		30-Jun		Sept. 30
	Fiscal Year 2013
	Total Operating Revenues	$	251,934	$	364,145	$	131,757	$	111,529
	Operating Income (Loss)	42,052		50,691		7,154		(12,353		)
	Net Income (Loss)	25,743		29,775		3,765		(10,518		)
	Three Months Ended	Dec. 31		31-Mar		30-Jun		Sept. 30
	Fiscal Year 2012
	Total Operating Revenues	$	251,983	$	298,897	$	117,771	$	98,976
	Operating Income (Loss)	37,522		44,553		9,708		(973		)
	Net Income (Loss)	21,697		25,925		4,630		(2,353		)

ACQUISITION_OF_MGE_Part_1_Narr

ACQUISITION OF MGE Part 1 - Narrative (Details) (USD $)

12 Months Ended

24 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

Share data in Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Aug. 13, 2013

Sep. 01, 2013

Sep. 01, 2013

Sep. 01, 2013

Sep. 01, 2013

Sep. 01, 2013

Laclede Group [Member]

Laclede Group [Member]

Laclede Group [Member]

Laclede Group [Member]

Laclede Gas [Member]

Missouri Gas Energy (MGE) [Member]

Missouri Gas Energy (MGE) [Member]

Missouri Gas Energy (MGE) [Member]

Missouri Gas Energy (MGE) [Member]

Missouri Gas Energy (MGE) [Member]

Other Operating Expense [Member]

Interest on Long-term Debt [Member]

Laclede Group [Member]

Laclede Group [Member]

Laclede Group [Member]

Laclede Gas [Member]

Gas Utility [Member]

Common Stock Issued

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition purchase price

$975,000,000

$0

$0

'

'

'

'

'

'

$975,000,000

'

'

'

Stock issued to finance acquisition

'

'

'

'

'

'

'

'

'

'

'

10

'

First mortgage bonds issued to finance acquisition

550,000,000

0

0

'

'

'

'

450,000,000

'

'

'

'

450,000,000

Goodwill

247,078,000

0

'

'

'

'

'

'

247,078,000

247,100,000

247,100,000

'

'

Merger-related transaction costs

'

'

'

$17,000,000

$200,000

$15,100,000

$1,900,000

'

'

'

'

'

'

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Part 1 (Details) (USD $)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
	customer
Nature of operations [Abstract]	'	'	'
Population (approximate) of service area	1,100,000	'	'
Utility Plant, Depreciation and Amortization [Abstract]	'	'	'
Average annual depreciation and amortization expense percentage	3.20%	3.10%	3.10%
Payments to Acquire Property, Plant, and Equipment	($128,496,000)	($106,734,000)	($67,304,000)
Accruals for capital expenditures	$4,700,000	$9,700,000	$8,200,000

ACQUISITION_OF_MGE_Part_2_Pro_

ACQUISITION OF MGE Part 2 - Pro Forma Information, Revenues and Earnings of Acquiree (Details) (Missouri Gas Energy (MGE) [Member], USD $)	1 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Missouri Gas Energy (MGE) [Member]	'
Pro Forma Information of Acquiree since Acquisition Date	'
Total net revenues	$21,985
Net Income	$1,795

SUMMARY_OF_SIGNIFICANT_ACCOUNT4

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Part 2 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Asset retirement obligations [Roll forward]	'	'
Asset retirement obligations, beginning of year	$40,126	$27,486
Liabilities incurred during the period	801	619
Liabilities settled during the period	-1,089	-601
Accretion	2,312	1,636
Revisions in estimated cash flows	0	10,986
MGE's asset retirement obligation	32,152	0
Asset retirement obligations, end of year	$74,302	$40,126

ACQUISITION_OF_MGE_Part_3_Prel

ACQUISITION OF MGE Part 3 - Preliminary Fair Value of Assets Acquired and Liabilities Assumed (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2012	Sep. 01, 2013
In Thousands, unless otherwise specified			Missouri Gas Energy (MGE) [Member]
Assets:	'	'	'
Utility plant	'	'	$671,793
Non-utility property	'	'	238
Other investments	'	'	3,096
Goodwill	247,078	0	247,078
Other Property and Investments	'	'	922,205
Accounts receivable:	'	'	'
Utility	'	'	19,963
Other	'	'	6,119
Delayed customer billings	'	'	10,701
Inventories:	'	'	'
Natural gas stored underground	'	'	58,679
Materials and supplies at average cost	'	'	3,988
Prepayments and other	'	'	487
Total Current Assets	'	'	99,937
Deferred Charges:	'	'	'
Regulatory assets	'	'	84,014
Other	'	'	4,928
Total Deferred Charges	'	'	88,942
Total Assets Acquired	'	'	1,111,084
Liabilities:	'	'	'
Accounts payable	'	'	20,154
Wages and compensation accrued	'	'	5,088
Customer deposits	'	'	8,362
Interest accrued	'	'	183
Taxes accrued	'	'	17,197
Other	'	'	12,620
Total Current Liabilities	'	'	63,604
Pension and postretirement benefit costs	'	'	24,466
Asset retirement obligations	'	'	32,056
Regulatory liabilities	'	'	2,249
Regulatory liabilities	'	'	13,709
Total Deferred Credits and Other Liabilities	'	'	72,480
Total Liabilities Assumed	'	'	136,084
Net Assets Acquired	'	'	$975,000

SUMMARY_OF_SIGNIFICANT_ACCOUNT5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Part 3 (Details) (USD $)

12 Months Ended

12 Months Ended

165 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 01, 2013

Sep. 01, 2013

Unamortized Investment Tax Credits [Member]

Unamortized Investment Tax Credits [Member]

Accrued cost of removal [Member]

Accrued cost of removal [Member]

Other Regulatory Liabilities [Member]

Other Regulatory Liabilities [Member]

Future Income Taxes Due From Customers [Member]

Future Income Taxes Due From Customers [Member]

Pension And Postretirement Cost [Member]

Pension And Postretirement Cost [Member]

Unamortized Purchased Gas Adjustments Asset [Member]

Unamortized Purchased Gas Adjustments Asset [Member]

Purchased Gas Costs [Member]

Purchased Gas Costs [Member]

Compensated Absences Cost [Member]

Compensated Absences Cost [Member]

Cold Weather Rule [Member]

Cold Weather Rule [Member]

Other Regulatory Assets [Member]

Other Regulatory Assets [Member]

Deferred Costs Incurred Prior to YE 1999 [Member]

Deferred Costs Incurred Prior to YE 1999 [Member]

Missouri Gas Energy (MGE) [Member]

Laclede Group [Member]

Missouri Gas Energy (MGE) [Member]

Schedule of Regulatory Assets and Liabilities[Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill

$247,078,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$247,078,000

$247,100,000

Regulatory Assets, Portion not Earning a Rate of Return

17,200,000

7,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

REGULATED OPERATIONS [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets

563,470,000

496,721,000

'

'

'

'

'

'

112,902,000

118,997,000

381,395,000

304,446,000

17,533,000

40,674,000

18,249,000

18,386,000

8,004,000

7,836,000

0

0

25,387,000

6,382,000

'

'

'

'

Regulatory Liabilities

64,843,000

59,432,000

2,900,000

3,113,000

59,066,000

55,103,000

2,877,000

1,216,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets, Portion not Earning a Rate of Return, Amortization Period

'15 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Regulatory Assets - Non-current

545,937,000

456,047,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10,500,000

10,500,000

'

'

Amortization period of deferred costs (in years)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'15 years

'

'

'

Amortization of deferred costs recognized to date - total

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,700,000

'

'

NATURAL GAS STORED UNDERGROUND [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

The amount by which the replacement cost is less than the cost basis value of stored gas inventories

13,300,000

24,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenue Recognition [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued Unbilled Revenue

$25,200,000

$11,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

ACQUISITION_OF_MGE_Part_4_Pro_

ACQUISITION OF MGE Part 4 - Pro Forma Information (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Business Acquisition, Pro Forma Information [Abstract]	'	'
Total net revenues	$1,518,201	$1,581,425
Net Income	$83,642	$81,722

SUMMARY_OF_SIGNIFICANT_ACCOUNT6

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Part 4 (Details) (USD $)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
	change
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Number of PGA Discretionary Changes	3	'	'
Months between PGA Discretionary Changes	'2 months	'	'
Cost savings retention percentage	10.00%	'	'
Cost savings retention amount, maximum	$3,000,000	'	'
CASH AND CASH EQUIVALENTS [Abstract]	'	'	'
Number of Months of the Original Maturity of Debt Instruments Purchased	'3 months	'	'
GROSS RECEIPT TAXES [Abstract]	'	'	'
Gross Receipts taxes recorded in utility operating revenues	40,800,000	35,900,000	43,500,000
RELATED PARTY TRANSACTIONS [Abstract]	'	'	'
Outstanding borrowings from Laclede Group under a revolving credit note	46,729,000	37,125,000	'
Interest rate on the borrowings	0.30%	0.20%	'
STOCK-BASED COMPENSATION [Abstract]	'	'	'
Minimum vesting period for each type of award (in years)	'3 years	'	'
Ownership percentage by parent (in hundredths)	100.00%	'	'
Total equity compensation cost	3,843,000	2,303,000	3,383,000
Compensation cost capitalized	-1,366,000	-808,000	-924,000
Compensation cost recognized in net income	2,477,000	1,495,000	2,459,000
Income tax benefit recognized in net income	-948,000	-577,000	-948,000
Compensation cost recognized in net income, net of income tax	1,529,000	918,000	1,511,000
Total unrecognized compensation cost	4,200,000	'	'
Weighted average period allocation (in years)	'2 years 0 months 0 days	'	'
Laclede Energy Resources, Inc. [Member]	'	'	'
RELATED PARTY TRANSACTIONS [Abstract]	'	'	'
Description of transaction	'Sales of natural gas	'	'
Purchases from related parties	24,200,000	16,500,000	24,300,000
Revenue from related Parties	10,500,000	1,200,000	1,600,000
Laclede Pipeline Company [Member]	'	'	'
RELATED PARTY TRANSACTIONS [Abstract]	'	'	'
Purchases from related parties	$1,600,000	$1,000,000	$1,000,000
Laclede Gas Company [Member] | First $2 million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	100.00%	'	'
Company Share	0.00%	'	'
Laclede Gas Company [Member] | From $2 to $4 million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	80.00%	'	'
Company Share	20.00%	'	'
Laclede Gas Company [Member] | From $4 to $6 million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	75.00%	'	'
Company Share	25.00%	'	'
Laclede Gas Company [Member] | Greater Than $6 million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	70.00%	'	'
Company Share	30.00%	'	'
Missouri Gas Energy (MGE) [Member] | First 1.2 Million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	85.00%	'	'
Company Share	15.00%	'	'
Missouri Gas Energy (MGE) [Member] | From 1.2 Million to 2.4 Million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	80.00%	'	'
Company Share	20.00%	'	'
Missouri Gas Energy (MGE) [Member] | From 2.4 Million to 3.6 Million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	75.00%	'	'
Company Share	25.00%	'	'
Missouri Gas Energy (MGE) [Member] | Great than 3.6 Million [Member]	'	'	'
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT [Abstract]	'	'	'
Customer Share	70.00%	'	'
Company Share	30.00%	'	'

PENSION_PLANS_AND_OTHER_POSTRE2

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 1 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Pension Plans [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Service cost - benefits earned during the period	$9,209	$9,203	$9,553
Interest cost on projected benefit obligation	16,959	19,358	18,819
Expected return on plan assets	-19,358	-19,595	-18,849
Amortization of prior service cost	544	592	642
Amortization of actuarial loss	10,724	9,040	10,228
Loss on lump-sum settlement	26,996	20,051	943
Sub-total	45,074	38,649	21,336
Regulatory adjustment	-27,532	-18,579	-7,066
Net benefit cost	17,542	20,070	14,270
Postretirement Plans [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Service cost - benefits earned during the period	10,162	8,060	7,676
Interest cost on projected benefit obligation	5,234	5,521	4,843
Expected return on plan assets	-4,447	-3,965	-3,646
Amortization of transition obligation	93	136	136
Amortization of prior service cost	3	-2,072	-2,328
Amortization of actuarial loss	5,300	4,261	4,443
Sub-total	16,345	11,941	11,124
Regulatory adjustment	-6,821	-2,417	-2,071
Net benefit cost	$9,524	$9,524	$9,053

PENSION_PLANS_AND_OTHER_POSTRE3

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 2 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Pension Plans [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Current year actuarial loss (gain)	$17,030	$32,884	($13,485)
Amortization of actuarial loss	-10,724	-29,091	-11,171
Acceleration of loss recognized due to settlement	-26,996	0	0
Amortization of prior service cost	-544	-592	-642
Sub-total	-21,234	3,201	-25,298
Regulatory adjustment	21,159	-3,510	24,533
Total recognized in other comprehensive income	-75	-309	-765
Postretirement Plans [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Current year actuarial loss (gain)	16,300	10,138	1,696
Amortization of actuarial loss	-5,300	-4,261	-4,443
Amortization of prior service cost	-3	2,072	2,328
Amortization of transition obligation	93	136	136
Sub-total	10,904	7,813	-555
Regulatory adjustment	-10,904	-7,813	555
Total recognized in other comprehensive income	$0	$0	$0

PENSION_PLANS_AND_OTHER_POSTRE4

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 3 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Pension Plans [Member]	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'
Benefit obligation at beginning of year	$412,171	$384,163	'
Service cost	9,209	9,203	9,553
Interest cost	16,959	19,358	18,819
Actuarial loss (gain)	23,921	-52,161	'
MGE acquisition	151,424	0	'
Settlement loss	24,999	14,348	'
Gross benefits paid	-87,023	-67,062	'
Benefit obligation at end of year	503,818	412,171	384,163
Accumulated benefit obligation at end of year	444,129	353,061	'
Postretirement Plans [Member]	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'
Benefit obligation at beginning of year	127,217	103,991	'
Service cost	10,162	8,060	7,676
Interest cost	5,234	5,521	4,843
Actuarial loss (gain)	17,514	15,895	'
MGE acquisition	28,444	0	'
Gross benefits paid	-8,449	-6,250	'
Benefit obligation at end of year	$180,122	$127,217	$103,991

PENSION_PLANS_AND_OTHER_POSTRE5

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 4 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Pension Plans [Member]	'	'
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'
Fair value of plan assets at beginning of year	$274,130	$247,959
Actual return on plan assets	3,387	53,220
Employer contributions	27,991	40,013
MGE acquisition	126,958	0
Gross benefits paid	-87,023	-67,062
Fair value of plan assets at end of year	345,443	274,130
Funded status of plans, end of year	-158,375	-138,041
Postretirement Plans [Member]	'	'
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'
Fair value of plan assets at beginning of year	67,442	51,744
Actual return on plan assets	5,660	9,722
Employer contributions	16,596	12,226
MGE acquisition	30,396	0
Gross benefits paid	-8,449	-6,250
Fair value of plan assets at end of year	111,645	67,442
Funded status of plans, end of year	($68,477)	($59,775)

PENSION_PLANS_AND_OTHER_POSTRE6

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 5 (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2012
In Thousands, unless otherwise specified
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'
Noncurrent liabilities	($228,653)	($196,558)
Pension Plans [Member]	'	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'
Current liabilities	-442	-468
Noncurrent liabilities	-157,933	-137,573
Total	158,375	138,041
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of [Abstract]	'	'
Net actuarial loss	115,775	136,464
Prior service costs (credit)	4,467	5,011
Sub-total	120,242	141,475
Adjustments for amounts included in Regulatory Assets	-116,686	-137,845
Total	3,556	3,630
Postretirement Plans [Member]	'	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'
Noncurrent assets	2,543	0
Current liabilities	-300	-790
Noncurrent liabilities	-70,720	-58,985
Total	68,477	59,775
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of [Abstract]	'	'
Net actuarial loss	63,573	52,573
Prior service costs (credit)	-27	-24
Transition obligation	0	93
Sub-total	63,546	52,642
Adjustments for amounts included in Regulatory Assets	-63,546	-52,642
Total	$0	$0

PENSION_PLANS_AND_OTHER_POSTRE7

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 6 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013
Pension Plans [Member]	'
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract]	'
Amortization of net actuarial loss	$7,088
Amortization of prior service cost	-497
Sub-total	-7,585
Regulatory adjustment	-7,196
Total Expected to be Amortized	389
Postretirement Plans [Member]	'
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract]	'
Amortization of net actuarial loss	6,021
Amortization of prior service cost	4
Sub-total	-6,017
Regulatory adjustment	-6,017
Total Expected to be Amortized	$0

PENSION_PLANS_AND_OTHER_POSTRE8

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 7 (Details)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Pension Plans [Member]	'	'	'
Assumptions used to calculate net periodic cost [Abstract]	'	'	'
Weighted average discount rate	3.95%	5.10%	4.75%
Weighted average rate of future compensation increase	3.00%	3.00%	3.00%
Expected long-term rate of return on plan assets	7.75%	7.75%	8.00%
Assumptions used to calculate benefit obligations [Abstract]	'	'	'
Weighted average discount rate	4.70%	3.95%	'
Weighted average rate of future compensation increase	3.00%	3.00%	'
Pension Plans [Member] | Missouri Gas Energy (MGE) [Member]	'	'	'
Assumptions used to calculate net periodic cost [Abstract]	'	'	'
Weighted average discount rate	5.05%	'	'
Assumptions used to calculate benefit obligations [Abstract]	'	'	'
Weighted average discount rate	5.00%	'	'
Postretirement Plans [Member]	'	'	'
Assumptions used to calculate net periodic cost [Abstract]	'	'	'
Weighted average discount rate	3.80%	5.05%	4.70%
Weighted average rate of future compensation increase	3.00%	3.00%	3.00%
Expected long-term rate of return on plan assets	7.75%	7.75%	8.00%
Assumptions used to calculate benefit obligations [Abstract]	'	'	'
Weighted average discount rate	4.60%	3.80%	'
Weighted average rate of future compensation increase	3.00%	3.00%	'

PENSION_PLANS_AND_OTHER_POSTRE9

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 8 (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2012
In Thousands, unless otherwise specified
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'	'
Projected benefit obligation	$503,818	$412,171
Accumulated benefit obligation	444,129	353,061
Fair value of plan assets	$345,443	$274,130

Recovered_Sheet1

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 9 (Details)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Pension Plans [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	100.00%	'
Actual allocation of plan assets	100.00%	100.00%
Pension Plans [Member] | Equity Markets [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	42.50%	'
Actual allocation of plan assets	45.90%	37.30%
Pension Plans [Member] | Commodities [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	2.50%	'
Actual allocation of plan assets	1.60%	2.20%
Pension Plans [Member] | Real Estate [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	2.50%	'
Actual allocation of plan assets	3.00%	2.20%
Pension Plans [Member] | Inflation-Indexed Securities [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	2.50%	'
Actual allocation of plan assets	1.40%	2.20%
Pension Plans [Member] | Debt Securities [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	50.00%	'
Actual allocation of plan assets	43.30%	41.10%
Pension Plans [Member] | Other	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	0.00%	'
Actual allocation of plan assets	4.80%	15.00%
Postretirement Plans [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Investment policy targets asset allocation to debt securities	40.00%	'
Current investment policy targets an asset allocation to equity securities	60.00%	'
Postretirement Plans [Member] | Equity Markets [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Actual allocation of plan assets	59.00%	59.00%
Postretirement Plans [Member] | Debt Securities [Member]	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Actual allocation of plan assets	39.00%	39.00%
Postretirement Plans [Member] | Other	'	'
Targeted and actual plan assets by category [Abstract]	'	'
Targeted allocation of plan assets	0.00%	'
Actual allocation of plan assets	2.00%	2.00%

Recovered_Sheet2

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 10 (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Pension Plans [Member] | Paid From Qualified Trust [Member]	'
Expected benefit payments [Abstract]	'
2014	$22.90
2015	25.3
2016	27.2
2017	30.8
2018	34.2
2019 - 2023	227.2
Pension Plans [Member] | Paid From Laclede Gas Funds [Member]	'
Expected benefit payments [Abstract]	'
2014	0.4
2015	0.5
2016	0.5
2017	0.6
2018	0.6
2019 - 2023	4.5
Postretirement Plans [Member] | Paid From Qualified Trust [Member]	'
Expected benefit payments [Abstract]	'
2014	9.5
2015	9.9
2016	10.7
2017	11.7
2018	12.8
2019 - 2023	84.1
Postretirement Plans [Member] | Paid From Laclede Gas Funds [Member]	'
Expected benefit payments [Abstract]	'
2014	0.3
2015	0.3
2016	0.3
2017	0.4
2018	0.4
2019 - 2023	$2.20

Recovered_Sheet3

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 11 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'	'
Medical cost trend assumed for next year	7.50%	7.00%
Rate to which the medical cost trend rate is assumed to decline (the ultimate medical cost trend rate)	5.00%	5.00%
Year that the rate reaches the ultimate trend	'2020	'2017
Assumed 1% change in the assumed medical cost trend rate [Abstract]	'	'
Effect of 1% increase on net periodic postretirement benefit cost	$1,520	'
Effect of 1% decrease on net periodic postretirement benefit cost	1,390	'
Effect of 1% increase on accumulated postretirement benefit obligation	7,060	'
Effect of 1% decrease on accumulated postretirement benefit obligation	$6,580	'

Recovered_Sheet4

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 12 (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
In Thousands, unless otherwise specified
Pension Plans [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	$345,443	$274,130	$247,959
Derivative Assets, fair value measurements	4,186	3,027	'
Cash margin payable	5,480	'	'
Cash margin receivable	'	3	'
Pension Plans [Member] | Cash and Cash Equivalents [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	18,177	57,614	'
Pension Plans [Member] | Stock/Bond Mutual Fund [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	115,817	'	'
Pension Plans [Member] | U.S Bond Mutual Funds [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	17,682	36,767	'
Pension Plans [Member] | U.S Government [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	55,743	57,925	'
Pension Plans [Member] | U.S Corporate [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	110,925	93,169	'
Pension Plans [Member] | U.S. Municipal [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	6,799	9,493	'
Pension Plans [Member] | International [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	21,594	18,885	'
Pension Plans [Member] | Derivative Instrument [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	-1,294	277	'
Pension Plans [Member] | Quoted Prices in Active Markets (Level 1) [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	35,859	94,381	'
Pension Plans [Member] | Quoted Prices in Active Markets (Level 1) [Member] | Cash and Cash Equivalents [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	18,177	57,614	'
Pension Plans [Member] | Quoted Prices in Active Markets (Level 1) [Member] | U.S Bond Mutual Funds [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	17,682	36,767	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	309,584	179,749	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member] | Stock/Bond Mutual Fund [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	115,817	'	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member] | U.S Government [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	55,743	57,925	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member] | U.S Corporate [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	110,925	93,169	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member] | U.S. Municipal [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	6,799	9,493	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member] | International [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	21,594	18,885	'
Pension Plans [Member] | Significant Observable Inputs (Level 2) [Member] | Derivative Instrument [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	-1,294	277	'
Postretirement Plans [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	111,645	67,442	51,744
Postretirement Plans [Member] | Cash and Cash Equivalents [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	1,411	1,106	'
Postretirement Plans [Member] | Stock/Bond Mutual Fund [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	110,234	66,336	'
Postretirement Plans [Member] | Quoted Prices in Active Markets (Level 1) [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	111,645	67,442	'
Postretirement Plans [Member] | Quoted Prices in Active Markets (Level 1) [Member] | Cash and Cash Equivalents [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	1,411	1,106	'
Postretirement Plans [Member] | Quoted Prices in Active Markets (Level 1) [Member] | Stock/Bond Mutual Fund [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Fair Value Measurement of Plan Assets	$110,234	$66,336	'

Recovered_Sheet5

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 13 (Details) (USD $)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2010	Aug. 01, 2007	Dec. 31, 2010	Aug. 01, 2007	Feb. 20, 2010
						Laclede Gas [Member]	Laclede Gas [Member]	Missouri Gas Energy (MGE) [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'	'	'	'	'
Rate Recovery Of Benefit Costs	'	'	'	'	'	$15,500,000	$4,800,000	$10,000,000
Extent of Lump-sum payments recognized, percentage	'1	'	'	'	'	'	'	'
Lump-sum payments recognized as settlements	79,484,000	60,085,000	-2,293,000	'	'	'	'	'
Implementation period used to calculate return on plan assets (in years)	'4 years	'	'	'	'	'	'	'
Gains or losses includible in cost amortized to extent exceeds benefit obligations or market-related value of plan assets, percentage.	10.00%	'	'	'	'	'	'	'
Recovery in rates for postretirement benefit	'	'	'	9,500,000	7,600,000	'	'	'
Anticipated Contributions to pension plans for qualified trust	24,000,000	'	'	'	'	'	'	'
Anticipated contributions to pension plans for non-qualified plans	400,000	'	'	'	'	'	'	'
Defined Benefit Plan Medical Insurance Offered Post Early Retirement Until Age Maximum	'65 years	'	'	'	'	'	'	'
Amortization period for transition obligation excluded from postretirement benefit cost (in years)	'20 years	'	'	'	'	'	'	'
Anticipated contributions to the postretirement plans for qualified trusts	19,200,000	'	'	'	'	'	'	'
Anticipated payment directly to participants in postretirement plan	300,000	'	'	'	'	'	'	'
Other Plans [Abstract]	'	'	'	'	'	'	'	'
401(K) plans, cost of defined contributions	$5,000,000	$3,800,000	$3,600,000	'	'	'	'	'

STOCKHOLDERS_EQUITY_Details

STOCKHOLDER'S EQUITY (Details) (USD $)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Stockholders' Equity Note [Abstract]	'	'	'
Common stock outstanding (in shares)	24,549	12,804	'
Increase in common stock and paid-in capital	$480,800,000	$44,400,000	'
Shares sold to parent company	11,745	1,087	'
Proceeds from sale of stock used to reduce short-term borrowings	476,500,000	42,700,000	'
Portion of Stock Sale Proceeds to Fund Acquisition	475,000,000	'	'
Dividend payment restriction formula component - fixed amount	8,000,000	'	'
Dividend payment restriction formula resulting calculation - available to pay dividends in period	833,000,000	355,000,000	'
SEC effective shelf registration Form S-3 for issuance of bonds, unsecured debt, and preferred stock - maximum available	890,000,000	350,000,000	'
MoPSC authorized debt issuance through June 30, 2013 - maximum available	518,000,000	'	'
MoPSC authorized debt issuance - remaining available	370,800,000	'	'
Accumulated other comprehensive income (loss) [Abstract]	'	'	'
Balance, beginning balance	-2,101,000	-2,473,000	'
Current period change	-5,000	372,000	402,000
Balance, ending balance	-2,106,000	-2,101,000	-2,473,000
Net Unrealized Gains (Losses) on Cash Flow Hedges [Member]	'	'	'
Accumulated other comprehensive income (loss) [Abstract]	'	'	'
Balance, beginning balance	129,000	-53,000	'
Current period change	-53,000	182,000	'
Balance, ending balance	76,000	129,000	'
Defined Benefit Pension and Other Postretirement Benefit Plans [Member]	'	'	'
Accumulated other comprehensive income (loss) [Abstract]	'	'	'
Balance, beginning balance	-2,230,000	-2,420,000	'
Current period change	48,000	190,000	'
Balance, ending balance	($2,182,000)	($2,230,000)	'

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Maturities on long-term debt [Abstract]	'
2013	$0
2014	0
2015	0
2016	0
2017	$100

LONGTERM_DEBT_Part_2_Narrative

LONG-TERM DEBT Part 2 - Narrative (Details) (USD $)

12 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Aug. 13, 2013

Mar. 15, 2013

Aug. 13, 2013

Mar. 15, 2013

Aug. 13, 2013

Mar. 15, 2013

Aug. 13, 2013

Oct. 15, 2012

Aug. 13, 2013

Mar. 15, 2013

Aug. 13, 2013

Mar. 15, 2013

Aug. 13, 2013

No Call Options [Member]

Make Whole Call Options [Member]

Callable at par in 2013 [Member]

Laclede Gas [Member]

Private Placement [Member]

Tranche 1 [Member]

Tranche 1 [Member]

Tranche 2 [Member]

Tranche 2 [Member]

Tranche 3 [Member]

First Mortgage [Member]

First Mortgage [Member]

First Mortgage [Member]

First Mortgage [Member]

First Mortgage [Member]

First Mortgage [Member]

Laclede Gas [Member]

Laclede Gas [Member]

Private Placement [Member]

Laclede Gas [Member]

Private Placement [Member]

Laclede Gas [Member]

Laclede Gas [Member]

Tranche 1 [Member]

Tranche 1 [Member]

Tranche 2 [Member]

Tranche 2 [Member]

Tranche 3 [Member]

Laclede Gas [Member]

Laclede Gas [Member]

Laclede Gas [Member]

Private Placement [Member]

Laclede Gas [Member]

Private Placement [Member]

Laclede Gas [Member]

Laclede Gas [Member]

Laclede Gas [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maturity of first mortgage bonds

$25,000,000

$0

$25,000,000

'

'

'

'

'

'

'

'

'

'

$25,000,000

'

'

'

'

'

Stated interest rate on debt issued

'

6.50%

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

3.00%

3.40%

3.40%

4.63%

Debt issued, maturity term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 years

'

'15 years

'

Proceeds from Issuance of First Mortgage Bond

550,000,000

0

0

'

'

'

450,000,000

100,000,000

100,000,000

55,000,000

250,000,000

45,000,000

100,000,000

'

'

'

'

'

'

Fixed-rate long-term debt amount

890,000,000

350,000,000

'

50,000,000

410,000,000

80,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

MoPSC authorized debt issuance through June 30, 2013 - maximum available

518,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

MoPSC authorized debt issuance - remaining available

$370,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock shares authorized (in shares)

1,480,000

1,480,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

DERIVATIVE_INSTRUMENTS_AND_HED2

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Part 1 (Details) (USD $)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Derivative [Line Items]	'	'	'
Maximum percentage of normal volumes hedged	70.00%	'	'
Maximum number of months normal volumes can be hedged (in months)	'36 months	'	'
Gasoline futures contracts notional amount (in gallons)	300,000	'	'
Average price of gasoline futures contracts (dollars per gallon)	$2.23	'	'
Expected pre-tax unrealized gain (loss) reclassifications into the Statements of Consolidated Income during the next twelve months	100,000	'	'
Contract volumes of NYMEX natural gas option used to mitigate price risk (in MMBtu)	23,600,000	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	1,803,000	7,682,000	'
Liability Derivatives	8,898,000	9,563,000	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	1,803,000	7,682,000	'
Fair value of cash margin receivables offset with derivatives	1,890,000	1,964,000	'
Netting of assets and liabilities with the same counterparty	-3,693,000	-9,646,000	'
Total	0	0	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Derivative instrument assets	0	0	'
Other deferred charges	0	0	'
Total	0	0	'
Fair value of liability derivatives presented above	8,898,000	9,563,000	'
Fair value of cash margin payables offset with derivatives	6,000	83,000	'
Netting of assets and liabilities with the same counterparty	-3,693,000	-9,646,000	'
Derivative instrument liabilities, per Consolidated Balance Sheets	5,211,000	0	'
Other Receivables from Broker-Dealers and Clearing Organizations	2,900,000	8,000,000	'
Derivative Instruments in Other Current Liabilities	3,817,000	0	'
Other Deferred Credits, Current	1,394,000	0	'
Not Designated as Hedging Instrument [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	1,698,000	7,348,000	'
Liability Derivatives	8,898,000	9,563,000	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	1,698,000	7,348,000	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	8,898,000	9,563,000	'
NYMEX Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	'	7,338,000	'
Liability Derivatives	'	9,563,000	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	'	7,338,000	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	'	9,563,000	'
NYMEX Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member] | Accounts Receivable Other [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	1,434,000	'	'
Liability Derivatives	3,455,000	'	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	1,434,000	'	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	3,455,000	'	'
OTCBB Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	228,000	'	'
Liability Derivatives	4,045,000	'	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	228,000	'	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	4,045,000	'	'
OTCBB Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member] | Other Deferred Credits [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	4,000	'	'
Liability Derivatives	1,398,000	'	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	4,000	'	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	1,398,000	'	'
NYMEX Gasoline and Heating Oil Contracts [Member] | Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	'	334,000	'
Liability Derivatives	'	0	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	'	334,000	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	'	0	'
NYMEX Gasoline and Heating Oil Contracts [Member] | Designated as Hedging Instrument [Member] | Accounts Receivable Other [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	105,000	'	'
Liability Derivatives	0	'	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	105,000	'	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	0	'	'
NYMEX Gasoline and Heating Oil Contracts [Member] | Not Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Asset Derivatives	'	10,000	'
Liability Derivatives	'	0	'
Derivative instrument assets reconciliation [Abstract]	'	'	'
Fair value of asset derivatives presented above	'	10,000	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Fair value of liability derivatives presented above	'	0	'
NYMEX Gasoline and Heating Oil Contracts [Member] | Cash Flow Hedging [Member] | Designated as Hedging Instrument [Member]	'	'	'
Derivatives, Fair Value [Line Items]	'	'	'
Effective portion of gain (loss) recognized in OCI on derivatives	123,000	297,000	355,000
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Effective portion of gain (loss) reclassified from AOCI to income	211,000	0	466,000
Ineffective portion of gain (loss) on derivatives recognized in income	-127,000	175,000	12,000
NYMEX Gasoline and Heating Oil Contracts [Member] | Other Income and (Income Deductions) - Net [Member] | Not Designated as Hedging Instrument [Member]	'	'	'
Derivative Instrument Assets, per Consolidated Balance Sheets:	'	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	41,000	19,000	37,000
Laclede Gas Company [Member] | Fiscal 2014 [Member] | NYMEX Natural Gas Contracts [Member] | Open Long Futures Positions [Member]	'	'	'
Derivative [Line Items]	'	'	'
MMBtu	7,260,000	'	'
Avg. Price Per MMBtu	3.99	'	'
Laclede Gas Company [Member] | Fiscal 2014 [Member] | OTCBB Natural Gas Contracts [Member] | Open Long Futures Positions [Member]	'	'	'
Derivative [Line Items]	'	'	'
MMBtu	16,810,000	'	'
Avg. Price Per MMBtu	3.97	'	'
Laclede Gas Company [Member] | Fiscal 2015 [Member] | NYMEX Natural Gas Contracts [Member] | Open Long Futures Positions [Member]	'	'	'
Derivative [Line Items]	'	'	'
MMBtu	940,000	'	'
Avg. Price Per MMBtu	3.84	'	'
Laclede Gas Company [Member] | Fiscal 2015 [Member] | OTCBB Natural Gas Contracts [Member] | Open Long Futures Positions [Member]	'	'	'
Derivative [Line Items]	'	'	'
MMBtu	7,580,000	'	'
Avg. Price Per MMBtu	$4.22	'	'

NOTES_PAYABLE_AND_CREDIT_AGREE2

NOTES PAYABLE AND CREDIT AGREEMENTS (Details) (USD $)	12 Months Ended				12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 03, 2013	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
			Line of Credit [Member]	Line of Credit [Member]	Commercial Paper [Member]	Commercial Paper [Member]	Borrowings from Laclede Group [Member]	Borrowings from Laclede Group [Member]
				bank
Line of Credit Facility [Line Items]	'	'	'	'	'	'	'	'
Line of credit facility borrowing capacity	'	'	'	$450,000,000	'	'	'	'
Banks in syndicated line of credit facility	'	'	'	9	'	'	'	'
Banks in syndicated line of credit facility, largest borrowing portion provided by a single bank	'	'	'	15.60%	'	'	'	'
For the entire fiscal year, short-term borrowings average	63,400,000	122,000,000	'	'	34,200,000	43,800,000	29,200,000	78,200,000
Weighted average interest rate on the short-term borrowings per annum	0.30%	0.30%	'	'	0.30%	0.30%	0.30%	0.30%
Short term borrowings outstanding in the period - minimum	0	59,600,000	'	'	0	0	0	13,000,000
Short term borrowings outstanding in the period - maximum	160,500,000	200,100,000	'	'	99,400,000	133,500,000	91,700,000	107,500,000
Short term borrowings - end of period	$120,700,000	$77,200,000	'	'	$74,000,000	$40,100,000	$46,700,000	$37,100,000
Line of Credit debt covenants capitalization ratio allowed maximum	'	'	'	70.00%	'	'	'	'
Short term debt to total capitalization ratio	'	'	51.00%	'	'	'	'	'
Weighted average interest rate on the short-term borrowings at fiscal year end	0.30%	0.20%	'	'	0.30%	0.20%	0.30%	0.20%

DERIVATIVE_INSTRUMENTS_AND_HED3

DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Part 2 (Details) (NYMEX Gasoline and Heating Oil Contracts [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]	'	'	'
Derivatives in Cash Flow Hedging Relationships [Abstract]	'	'	'
Effective portion of gain (loss) recognized in OCI on derivatives	$123	$297	$355
Effective portion of gain (loss) reclassified from AOCI to income	211	0	466
Ineffective portion of gain (loss) on derivatives recognized in income	-127	175	12
Not Designated as Hedging Instrument [Member] | Other Income and (Income Deductions) - Net [Member]	'	'	'
Derivatives Not Designated as Hedging Instruments [Abstract]	'	'	'
Gain (loss) recognized in income on derivatives	$41	$19	$37

FAIR_VALUE_OF_FINANCIAL_INSTRU2

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2010
In Thousands, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	$23,916	$2,402	$923	$1,009
Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	23,916	2,402	'	'
Short-term debt	120,729	77,225	'	'
Long-term debt, including current portion	887,712	364,416	'	'
Estimate of Fair Value, Fair Value Disclosure [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	23,916	2,402	'	'
Short-term debt	120,729	77,225	'	'
Long-term debt, including current portion	930,369	452,768	'	'
Quoted Prices in Active Markets (Level 1) [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	23,892	'	'	'
Short-term debt	0	'	'	'
Long-term debt, including current portion	0	'	'	'
Significant Observable Inputs (Level 2) [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	24	'	'	'
Short-term debt	120,729	'	'	'
Long-term debt, including current portion	930,369	'	'	'
Significant Unobservable Inputs (Level 3) [Member]	'	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'	'
Cash and cash equivalents	0	'	'	'
Short-term debt	0	'	'	'
Long-term debt, including current portion	$0	'	'	'

FAIR_VALUE_MEASUREMENTS_Detail

FAIR VALUE MEASUREMENTS (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2012
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	$14,500	$13,187
NYMEX natural gas contracts- Asset	0	'
OTCBB natural gas contracts	0	'
NYMEX gasoline and heating oil contracts- Asset	0	'
Total Assets	14,500	13,187
NYMEX natural gas contracts- Liabilities	0	0
OTCBB natural gas contracts	5,211	'
Quoted Prices in Active Markets (Level 1) [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	14,500	13,187
NYMEX natural gas contracts- Asset	1,466	7,338
OTCBB natural gas contracts	0	'
NYMEX gasoline and heating oil contracts- Asset	105	344
Total Assets	16,071	20,869
NYMEX natural gas contracts- Liabilities	3,455	9,563
OTCBB natural gas contracts	0	'
Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts- Asset	0	0
OTCBB natural gas contracts	232	'
NYMEX gasoline and heating oil contracts- Asset	0	0
Total Assets	232	0
NYMEX natural gas contracts- Liabilities	0	0
OTCBB natural gas contracts	5,443	'
Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts- Asset	0	0
OTCBB natural gas contracts	0	'
NYMEX gasoline and heating oil contracts- Asset	0	0
Total Assets	0	0
NYMEX natural gas contracts- Liabilities	0	0
OTCBB natural gas contracts	0	'
Effects of Netting and Cash Margin Receivables Payables [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
U. S. Stock/Bond Mutual Funds	0	0
NYMEX natural gas contracts- Asset	-1,466	-7,338
OTCBB natural gas contracts	-232	'
NYMEX gasoline and heating oil contracts- Asset	-105	-344
Total Assets	-1,803	-7,682
NYMEX natural gas contracts- Liabilities	-3,455	-9,563
OTCBB natural gas contracts	($232)	'

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	12 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2013	Sep. 03, 2013
				State [Member]	State [Member]
Federal [Abstract]	'	'	'	'	'
Current	($6,539,000)	($11,288,000)	$133,000	'	'
Deferred	20,103,000	27,186,000	19,848,000	'	'
Investment tax credits	-213,000	-213,000	-213,000	'	'
State and local [Abstract]	'	'	'	'	'
Current	-984,000	-1,825,000	-152,000	'	'
Deferred	2,284,000	4,600,000	3,380,000	'	'
Total Income Tax Expense	14,651,000	18,460,000	22,996,000	'	'
Effective income tax rate variance from federal statutory rate [Abstract]	'	'	'	'	'
Federal income tax statutory rate	35.00%	35.00%	35.00%	'	'
State and local income taxes, net of federal income tax benefits	3.30%	2.60%	2.70%	'	'
Certain expenses capitalized on books and deducted on tax return	-10.80%	-8.90%	-6.10%	'	'
Taxes related to prior years	-1.60%	-0.60%	-0.80%	'	'
Other items - net	-2.80%	-1.10%	-0.80%	'	'
Effective income tax rate	23.10%	27.00%	30.00%	'	'
Deferred tax assets: [Abstract]	'	'	'	'	'
Reserves not currently deductible	13,933,000	16,400,000	'	'	'
Pension and other postretirement benefits	71,367,000	73,480,000	'	'	'
Unamortized investment tax credits	1,799,000	1,955,000	'	'	'
Other	10,450,000	14,513,000	'	'	'
Total deferred tax assets	97,549,000	106,348,000	'	'	'
Deferred tax liabilities: [Abstract]	'	'	'	'	'
Relating to property	341,975,000	303,332,000	'	'	'
Regulatory pension and other postretirement benefits	124,871,000	121,554,000	'	'	'
Deferred gas costs	7,112,000	20,652,000	'	'	'
Other	5,396,000	26,414,000	'	'	'
Total deferred tax liabilities	479,354,000	471,952,000	'	'	'
Net deferred tax liability	381,805,000	365,604,000	'	'	'
Net deferred tax liability - current	-1,692,000	-10,146,000	'	'	'
Net deferred tax liability - non-current	380,113,000	355,458,000	'	'	'
Unrecognized tax benefits [Roll Forward]	'	'	'	'	'
Unrecognized tax benefits, beginning of year	5,615,000	5,536,000	'	'	'
Increases (decreases) related to tax positions taken in current year	1,420,000	490,000	'	'	'
Reductions due to lapse of applicable statute of limitations	-5,018,000	-411,000	'	'	'
Unrecognized tax benefits, end of year	2,017,000	5,615,000	5,536,000	'	'
Unrecognized tax benefits affect on the Company's effective tax rate	1,500,000	1,200,000	'	'	'
Interest accrued associated with uncertain tax positions	100,000	500,000	'	'	'
Interest expense accrued during fiscal year	100,000	200,000	200,000	'	'
Tax Credit Carryforward [Line Items]	'	'	'	'	'
Reversal of accrued penalties	600,000	'	'	'	'
Deferred Tax Assets, Tax Credit Carryforwards	'	'	'	'	6,600,000
Deferred Tax Assets, Tax Credit Carryforwards, Net, Current	'	'	'	4,300,000	'
Deferred Tax Assets, Tax Credit Carryforwards, Net, Noncurrent	'	'	'	$2,300,000	'

OTHER_INCOME_AND_INCOME_DEDUCT2

OTHER INCOME AND INCOME (DEDUCTIONS) NET (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Other Nonoperating Income (Expense) [Abstract]	'	'	'
Interest income	$947	$1,230	$1,057
Net investment gain (loss)	2,544	2,626	-73
Other income	377	804	53
Other income deductions	-1,859	-1,955	-212
Other Income and (Income Deductions) - Net	$2,009	$2,705	$825

INFORMATION_BY_OPERATING_SEGME2

INFORMATION BY OPERATING SEGMENT (Details) (USD $)	3 Months Ended								12 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Operating Segment Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Operating Revenues	$111,529,000	$131,757,000	$364,145,000	$251,934,000	$98,976,000	$117,771,000	$298,897,000	$251,983,000	$859,365,000	$767,627,000	$932,328,000
Depreciation and amortization	'	'	'	'	'	'	'	'	48,283,000	40,739,000	39,214,000
Interest income	'	'	'	'	'	'	'	'	947,000	1,230,000	1,057,000
Interest charges	'	'	'	'	'	'	'	'	26,137,000	25,156,000	25,544,000
Income Tax Expense	'	'	'	'	'	'	'	'	14,651,000	18,460,000	22,996,000
Net economic earnings	'	'	'	'	'	'	'	'	57,209,000	49,789,000	53,803,000
Total assets	2,981,016,000	'	'	'	1,760,152,000	'	'	'	2,981,016,000	1,760,152,000	1,643,046,000
Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	128,496,000	106,734,000	67,304,000
After-tax earnings resulting from the non-regulated sale of propane inventory	'	'	'	'	'	'	'	'	'	'	6,100,000
Reconciliation of Net Economic Earnings to Net Income [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Net Economic Earnings above	'	'	'	'	'	'	'	'	57,209,000	49,789,000	53,803,000
Unrealized gain (loss) on energy-related derivative contracts, net of tax	'	'	'	'	'	'	'	'	-100,000	110,000	-26,000
Add: Acquisition, divestiture, and restructuring activities	'	'	'	'	'	'	'	'	8,344,000	0	0
Net Income	-10,518,000	3,765,000	29,775,000	25,743,000	-2,353,000	4,630,000	25,925,000	21,697,000	48,765,000	49,899,000	53,777,000
Regulated Gas Distribution [Member]	'	'	'	'	'	'	'	'	'	'	'
Operating Segment Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Operating Revenues	'	'	'	'	'	'	'	'	857,762,000	764,651,000	913,190,000
Depreciation and amortization	'	'	'	'	'	'	'	'	48,283,000	40,739,000	39,214,000
Interest income	'	'	'	'	'	'	'	'	947,000	1,230,000	1,057,000
Interest charges	'	'	'	'	'	'	'	'	26,137,000	25,156,000	25,544,000
Income Tax Expense	'	'	'	'	'	'	'	'	19,243,000	17,393,000	18,694,000
Net economic earnings	'	'	'	'	'	'	'	'	56,635,000	48,089,000	46,952,000
Total assets	2,981,016,000	'	'	'	1,758,952,000	'	'	'	2,981,016,000	1,758,952,000	1,641,386,000
Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	128,496,000	106,734,000	67,304,000
Reconciliation of Net Economic Earnings to Net Income [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Net Economic Earnings above	'	'	'	'	'	'	'	'	56,635,000	48,089,000	46,952,000
Non-Regulated Other [Member]	'	'	'	'	'	'	'	'	'	'	'
Operating Segment Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Operating Revenues	'	'	'	'	'	'	'	'	1,603,000	2,976,000	19,138,000
Depreciation and amortization	'	'	'	'	'	'	'	'	0	0	0
Interest income	'	'	'	'	'	'	'	'	0	0	0
Interest charges	'	'	'	'	'	'	'	'	0	0	0
Income Tax Expense	'	'	'	'	'	'	'	'	-4,592,000	1,067,000	4,302,000
Net economic earnings	'	'	'	'	'	'	'	'	574,000	1,700,000	6,851,000
Total assets	0	'	'	'	1,200,000	'	'	'	0	1,200,000	1,660,000
Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	0	0	0
Reconciliation of Net Economic Earnings to Net Income [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Net Economic Earnings above	'	'	'	'	'	'	'	'	574,000	1,700,000	6,851,000
Adjustments & Eliminations [Member]	'	'	'	'	'	'	'	'	'	'	'
Operating Segment Information [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Operating Revenues	'	'	'	'	'	'	'	'	0	0	0
Depreciation and amortization	'	'	'	'	'	'	'	'	0	0	0
Interest income	'	'	'	'	'	'	'	'	0	0	0
Interest charges	'	'	'	'	'	'	'	'	0	0	0
Income Tax Expense	'	'	'	'	'	'	'	'	0	0	0
Net economic earnings	'	'	'	'	'	'	'	'	0	0	0
Total assets	0	'	'	'	0	'	'	'	0	0	0
Expenditures for Additions to Long-Lived Assets	'	'	'	'	'	'	'	'	0	0	0
Reconciliation of Net Economic Earnings to Net Income [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Net Economic Earnings above	'	'	'	'	'	'	'	'	$0	$0	$0

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Details) (USD $)

12 Months Ended

36 Months Ended

12 Months Ended

36 Months Ended

0 Months Ended

12 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2011

Sep. 30, 2007

Nov. 26, 2013

Sep. 30, 2005

Sep. 30, 2017

Sep. 30, 2016

Sep. 30, 2013

Jun. 30, 2010

Sep. 30, 2013

Sep. 30, 2013

site

Forecast [Member]

Forecast [Member]

MF Global Inc [Member]

Laclede Gas [Member]

Missouri Gas Energy (MGE) [Member]

Vehicles and Power Operated Equipment Leases [Member]

Laclede Gas [Member]

Commitments [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated capital expenditures, next fiscal year

'

$175,000,000

'

'

'

'

'

'

'

'

'

'

'

Approximate contract amount of project

'

2,000,000

'

'

'

'

'

'

'

'

'

'

'

Minimum total payments required for natural gas contracts

'

793,000,000

'

'

'

'

'

'

'

'

'

'

'

Leases and Guarantees [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional years available for lease renewal (in years)

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

Office headquarters lease rental aggregate expense

'

1,000,000

900,000

900,000

'

'

'

'

'

'

'

600,000

'

Annual minimum rental payments

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Minimum rental costs obligations - current fiscal year

'

'

'

'

'

'

'

'

'

'

'

'

2,700,000

Minimum rental costs obligations - due in two years

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

Minimum rental costs obligations - due in three years

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

Minimum rental costs obligations - due in four years

'

'

'

'

'

'

'

'

'

'

'

'

400,000

Minimum rental costs obligations - due in five years

'

'

'

'

'

'

'

'

'

'

'

'

100,000

Annual intercompany expense for liquid propane transportation service

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

Number of months' notice required to terminate intercompany transportation agreement

'

'P6M

'

'

'

'

'

'

'

'

'

'

'

Contingencies and Indemnifications [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of former manufactured gas plant (MGP) sites in Missouri

'

3

'

'

'

'

'

'

'

'

'

'

'

Number of former manufactured gas plant (MGP) sites in Shrewsbury, Missouri

'

1

'

'

'

'

'

'

'

'

'

'

'

Number of former manufactured gas plant (MGP) sites in the City of St. Louis

'

2

'

'

'

'

'

'

'

'

'

'

'

Minimum cost estimate for a one-time contractual transfer of risk

'

'

'

'

'

'

5,800,000

'

'

'

'

'

'

Maximum cost estimate for a one-time contractual transfer of risk

'

'

'

'

'

'

36,300,000

'

'

'

'

'

'

Original proposed disallowance amount related to recovery of purchased gas costs

'

'

'

'

6,000,000

'

'

'

'

'

'

'

'

Revenue sharing agreements, Company's net margin amount subject to reduced sharing percentage

'

2,000,000

'

'

'

'

'

'

'

'

'

'

'

Revenue sharing agreements, Company's net margin amount subject to reduced sharing percentage, Company's percentage share

'

15.00%

'

'

'

'

'

15.00%

0.00%

'

'

'

'

Notice of employment related violations issued to company, applicable period

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

Amount remaining on deposit with a brokerage firm for Laclede Gas

'

'

'

'

'

200,000

'

'

'

'

'

'

'

Percentage of deposits recovered from banktrupt entity

'

'

'

'

'

'

'

'

'

$0.98

'

'

'

INTERIM_FINANCIAL_INFORMATION_2

INTERIM FINANCIAL INFORMATION (UNAUDITED) (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Total Operating Revenues	$111,529	$131,757	$364,145	$251,934	$98,976	$117,771	$298,897	$251,983	$859,365	$767,627	$932,328
Operating Income (Loss)	-12,353	7,154	50,691	42,052	-973	9,708	44,553	37,522	87,544	90,810	101,492
Net Income (Loss)	($10,518)	$3,765	$29,775	$25,743	($2,353)	$4,630	$25,925	$21,697	$48,765	$49,899	$53,777

SCHEDULE_II_Details

SCHEDULE II (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2011
Allowance for Doubtful Accounts [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
BALANCE AT BEGINNING OF PERIOD	$7,601	$9,969	$10,176
ADDITIONS TO INCOME	5,584	6,011	7,257
CHARGED TO OTHER ACCOUNTS	8,234	10,145	11,340
DEDUCTIONS FROM RESERVES	13,477	18,524	18,804
BALANCE AT CLOSE OF PERIOD	7,942	7,601	9,969
Miscellaneous: Injuries and Property Damage [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
BALANCE AT BEGINNING OF PERIOD	4,540	3,603	3,228
ADDITIONS TO INCOME	1,934	3,150	2,416
CHARGED TO OTHER ACCOUNTS	0	0	0
DEDUCTIONS FROM RESERVES	2,135	2,213	2,041
BALANCE AT CLOSE OF PERIOD	4,339	4,540	3,603
Miscellaneous: Deferred Compensation [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
BALANCE AT BEGINNING OF PERIOD	14,205	13,474	12,571
ADDITIONS TO INCOME	1,781	1,756	1,893
CHARGED TO OTHER ACCOUNTS	0	0	0
DEDUCTIONS FROM RESERVES	1,306	1,025	990
BALANCE AT CLOSE OF PERIOD	14,680	14,205	13,474
Miscellaneous: Group Medical Claims Incurred But Not Reported [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
BALANCE AT BEGINNING OF PERIOD	1,560	1,300	1,450
ADDITIONS TO INCOME	17,205	15,381	14,171
CHARGED TO OTHER ACCOUNTS	0	0	0
DEDUCTIONS FROM RESERVES	16,116	15,121	14,321
BALANCE AT CLOSE OF PERIOD	2,649	1,560	1,300
Total Miscellaneous [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
BALANCE AT BEGINNING OF PERIOD	20,305	18,377	17,249
ADDITIONS TO INCOME	20,920	20,287	18,480
CHARGED TO OTHER ACCOUNTS	0	0	0
DEDUCTIONS FROM RESERVES	19,557	18,359	17,352
BALANCE AT CLOSE OF PERIOD	$21,668	$20,305	$18,377