10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

(Mark One)

[ X ]	QUARTERLY REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the quarterly period ended June 30, 2017
	OR
[ ]	TRANSITION REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to

Commission File Number	Name of Registrant, Address of Principal Executive Offices and Telephone Number	State of Incorporation	I.R.S. Employer Identification Number
1-16681	Spire Inc. 700 Market Street St. Louis, MO 63101 314-342-0500	Missouri	74-2976504
1-1822	Laclede Gas Company 700 Market Street St. Louis, MO 63101 314-342-0500	Missouri	43-0368139
2-38960	Alabama Gas Corporation 2101 6th Avenue North Birmingham, AL 35203 205-326-8100	Alabama	63-0022000

Indicate by check mark whether each registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such report) and (2) has been subject to such filing requirements for the past 90 days.

Spire Inc.	Yes [ X ]	No [ ]
Laclede Gas Company	Yes [ X ]	No [ ]
Alabama Gas Corporation	Yes [ X ]	No [ ]

Indicate by check mark whether each registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Spire Inc.	Yes [ X ]	No [ ]
Laclede Gas Company	Yes [ X ]	No [ ]
Alabama Gas Corporation	Yes [ X ]	No [ ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

	Large accelerated filer	Accelerated filer	Non- accelerated filer	Smaller reporting company	Emerging growth company
Spire Inc.	X
Laclede Gas Company			X
Alabama Gas Corporation			X

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

Spire Inc.	[ ]
Laclede Gas Company	[ ]
Alabama Gas Corporation	[ ]

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

Spire Inc.	Yes [ ]	No [ X ]
Laclede Gas Company	Yes [ ]	No [ X ]
Alabama Gas Corporation	Yes [ ]	No [ X ]

The number of shares outstanding of each registrant’s common stock as of July 31, 2017 was as follows:

Spire Inc.	Common Stock, par value $1.00 per share	48,262,027
Laclede Gas Company	Common Stock, par value $1.00 per share (all owned by Spire Inc.)	24,577
Alabama Gas Corporation	Common Stock, par value $0.01 per share (all owned by Spire Inc.)	1,972,052

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

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

TABLE OF CONTENTS			Page No.
GLOSSARY			2
PART I. FINANCIAL INFORMATION
Item 1	Financial Statements (Unaudited):
	Spire Inc.
		Condensed Consolidated Statements of Income	4
		Condensed Consolidated Statements of Comprehensive Income	5
		Condensed Consolidated Balance Sheets	6
		Condensed Consolidated Statements of Common Shareholders’ Equity	8
		Condensed Consolidated Statements of Cash Flows	9
	Laclede Gas Company
		Condensed Statements of Income	10
		Condensed Statements of Comprehensive Income	11
		Condensed Balance Sheets	12
		Condensed Statements of Common Shareholder’s Equity	14
		Condensed Statements of Cash Flows	15
	Alabama Gas Corporation
		Condensed Statements of Income	16
		Condensed Balance Sheets	17
		Condensed Statements of Common Shareholder’s Equity	19
		Condensed Statements of Cash Flows	20
	Notes to Financial Statements
		Note 1. Summary of Significant Accounting Policies	21
		Note 2. Earnings Per Common Share	25
		Note 3. Regulatory Matters	26
		Note 4. Financing Arrangements and Long-term Debt	29
		Note 5. Fair Value of Financial Instruments	30
		Note 6. Fair Value Measurements	31
		Note 7. Concentrations of Credit Risk	35
		Note 8. Pension Plans and Other Postretirement Benefits	35
		Note 9. Information by Operating Segment	38
		Note 10. Commitments and Contingencies	41
Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations		44
Item 3	Quantitative and Qualitative Disclosures About Market Risk		63
Item 4	Controls and Procedures		64
PART II. OTHER INFORMATION
Item 1	Legal Proceedings		65
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds		65
Item 6	Exhibits		65
SIGNATURES			66
EXHIBIT INDEX			67

1

GLOSSARY OF KEY TERMS AND ABBREVIATIONS

Alabama Utilities	Alagasco and Mobile Gas, the utilities serving the Alabama region	Laclede Gas	Laclede Gas Company, or Missouri Utilities
Alagasco	Alabama Gas Corporation	MDNR	Missouri Department of Natural Resources
AOCI	Accumulated other comprehensive income or loss	MGE	Missouri Gas Energy
APSC	Alabama Public Service Commission	MGP	Manufactured gas plant
ASC	Accounting Standards Codification	Missouri Utilities	Laclede Gas Company (including MGE), the utilities serving the Missouri region
ASU	Accounting Standards Update	MMBtu	Million British thermal units
Bcf	Billion cubic feet	Mobile Gas	Mobile Gas Service Corporation
BVCP	Brownfields/Voluntary Cleanup Program	MoPSC	Missouri Public Service Commission
CERCLA	Comprehensive Environmental Response, Compensation, and Liability Act of 1980	MSPSC	Mississippi Public Service Commission
CCM	Cost Control Mechanism	NYMEX	New York Mercantile Exchange, Inc.
Degree days	The average of a day’s high and low temperature below 65, subtracted from 65, multiplied by the number of days impacted	NYSE	New York Stock Exchange
EnergySouth	EnergySouth, Inc.	O&M	Operation and maintenance expense
EPA	US Environmental Protection Agency	OPC	Missouri Office of the Public Counsel
EPS	Earnings per share	OTCBB	Over-the-Counter Bulletin Board
FASB	Financial Accounting Standards Board	PGA	Purchased Gas Adjustment
FERC	Federal Energy Regulatory Commission	PRP	Potentially responsible party
GAAP	Accounting principles generally accepted in the United States of America	RSE	Rate Stabilization and Equalization
Gas Marketing	Operating segment including Spire Marketing, which is engaged in the non-regulated marketing of natural gas and related activities	SEC	US Securities and Exchange Commission
Gas Utility	Segment including the regulated operations of the Utilities	Spire Marketing	Spire Marketing Inc. (formerly known as Laclede Energy Resources, Inc., or LER)
GSA	Gas Supply Adjustment	US	United States
ICE	Intercontinental Exchange	Utilities	Laclede Gas, Alagasco, and the subsidiaries of EnergySouth
ISRS	Infrastructure System Replacement Surcharge	Willmut Gas	Willmut Gas & Oil Company

2

PART I. FINANCIAL INFORMATION

The interim financial statements included herein have been prepared by three separate registrants — Spire Inc. (Spire or the Company), Laclede Gas Company (Laclede Gas or Missouri Utilities) and Alabama Gas Corporation (Alagasco) — without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). These financial statements should be read in conjunction with the financial statements and the notes thereto included in each registrant’s respective Form 10-K for the fiscal year ended September 30, 2016.

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

3

Item 1. Financial Statements

SPIRE INC.

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended June 30,					Nine Months Ended June 30,
(In millions, except per share amounts)	2017		2016			2017		2016
Operating Revenues:
Gas Utility	$	305.1	$	253.2		$	1,419.1	$	1,263.5
Gas Marketing and other	18.4		(3.9		)	62.9		(5.5		)
Total Operating Revenues	323.5		249.3			1,482.0		1,258.0
Operating Expenses:
Gas Utility
Natural and propane gas	76.7		54.1			524.8		463.7
Operation and maintenance	100.8		91.8			298.6		277.7
Depreciation and amortization	38.4		34.2			114.0		101.5
Taxes, other than income taxes	30.5		27.4			112.2		99.5
Total Gas Utility Operating Expenses	246.4		207.5			1,049.6		942.4
Gas Marketing and other	26.8		6.5			112.6		25.6
Total Operating Expenses	273.2		214.0			1,162.2		968.0
Operating Income	50.3		35.3			319.8		290.0
Other Income	1.5		1.6			5.6		3.8
Interest Charges:
Interest on long-term debt	19.0		16.6			57.3		50.2
Other interest charges	2.4		2.8			8.9		7.5
Total Interest Charges	21.4		19.4			66.2		57.7
Income Before Income Taxes	30.4		17.5			259.2		236.1
Income Tax Expense	8.7		6.8			84.3		77.7
Net Income	$	21.7	$	10.7		$	174.9	$	158.4
Weighted Average Number of Common Shares Outstanding:
Basic	48.1		44.4			46.4		43.6
Diluted	48.2		44.6			46.6		43.8
Basic Earnings Per Share of Common Stock	$	0.45	$	0.24		$	3.76	$	3.62
Diluted Earnings Per Share of Common Stock	$	0.45	$	0.24		$	3.75	$	3.60
Dividends Declared Per Share of Common Stock	$	0.53	$	0.49		$	1.58	$	1.47
See the accompanying Notes to Financial Statements.

4

SPIRE INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)

	Three Months Ended June 30,						Nine Months Ended June 30,
(In millions)	2017			2016			2017			2016
Net Income	$	21.7		$	10.7		$	174.9		$	158.4
Other Comprehensive (Loss) Income, Before Tax:
Cash flow hedging derivative instruments:
Net hedging (losses) gains arising during the period	(1.0		)	(4.3		)	11.5			(5.6		)
Reclassification adjustment for (gains) losses included in net income	—			(1.5		)	0.1			0.2
Net unrealized (losses) gains on cash flow hedging derivative instruments	(1.0		)	(5.8		)	11.6			(5.4		)
Net gains on defined benefit pension and other postretirement plans	0.1			—			0.2			0.1
Net unrealized losses on available for sale securities	—			—			(0.1		)	—
Other Comprehensive (Loss) Income, Before Tax	(0.9		)	(5.8		)	11.7			(5.3		)
Income Tax (Benefit) Expense Related to Items of Other Comprehensive Income	(0.4		)	(2.2		)	4.3			(2.0		)
Other Comprehensive (Loss) Income, Net of Tax	(0.5		)	(3.6		)	7.4			(3.3		)
Comprehensive Income	$	21.2		$	7.1		$	182.3		$	155.1
See the accompanying Notes to Financial Statements.

5

SPIRE INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

	June 30,			September 30,			June 30,
(Dollars in millions, except per share amounts)	2017			2016			2016
ASSETS
Utility Plant	$	5,071.4		$	4,793.6		$	4,339.5
Less: Accumulated depreciation and amortization	1,609.6			1,506.4			1,311.5
Net Utility Plant	3,461.8			3,287.2			3,028.0
Non-utility Property (net of accumulated depreciation and amortization of $8.4, $8.1 and $7.9 at June 30, 2017, September 30, 2016, and June 30, 2016, respectively)	39.9			13.7			13.8
Goodwill	1,163.9			1,164.9			946.0
Other Investments	63.8			62.1			62.4
Total Other Property and Investments	1,267.6			1,240.7			1,022.2
Current Assets:
Cash and cash equivalents	8.3			5.2			4.9
Accounts receivable:
Utility	141.9			127.8			133.1
Other	124.0			113.4			82.7
Allowance for doubtful accounts	(17.7		)	(20.5		)	(20.2		)
Delayed customer billings	7.0			1.6			3.5
Inventories:
Natural gas	144.4			174.0			116.6
Propane gas	12.0			12.0			12.0
Materials and supplies	18.4			16.3			15.3
Natural gas receivable	6.5			9.7			17.5
Derivative instrument assets	7.3			11.4			9.0
Unamortized purchased gas adjustments	73.9			49.7			5.4
Other regulatory assets	70.7			44.2			37.5
Prepayments and other	32.4			24.8			36.1
Total Current Assets	629.1			569.6			453.4
Deferred Charges:
Regulatory assets	840.5			838.0			730.7
Other	99.2			128.9			64.7
Total Deferred Charges	939.7			966.9			795.4
Total Assets	$	6,298.2		$	6,064.4		$	5,299.0

6

SPIRE INC.

CONDENSED CONSOLIDATED BALANCE SHEETS (Continued)

(UNAUDITED)

	June 30,		September 30,			June 30,
	2017		2016			2016
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock (par value $1.00 per share; 70.0 million shares authorized; 48.3 million, 45.6 million and 45.6 million shares issued and outstanding at June 30, 2017, September 30, 2016 and June 30, 2016, respectively)	$	48.2	$	45.6		$	45.6
Paid-in capital	1,323.7		1,175.9			1,173.5
Retained earnings	653.1		550.9			588.6
Accumulated other comprehensive income (loss)	3.2		(4.2		)	(5.3		)
Total Common Stock Equity	2,028.2		1,768.2			1,802.4
Long-term debt (less current portion)	1,925.3		1,820.7			1,839.8
Total Capitalization	3,953.5		3,588.9			3,642.2
Current Liabilities:
Current portion of long-term debt	—		250.0			—
Notes payable	450.7		398.7			97.6
Accounts payable	206.4		210.9			135.8
Advance customer billings	15.9		70.2			53.0
Wages and compensation accrued	38.9		39.8			36.5
Dividends payable	26.3		23.5			22.3
Customer deposits	35.0		34.9			31.9
Interest accrued	24.2		14.8			19.7
Taxes accrued	55.6		55.2			41.4
Unamortized purchased gas adjustments	1.0		1.7			—
Other regulatory liabilities	24.9		28.9			22.4
Other	30.9		32.7			31.2
Total Current Liabilities	909.8		1,161.3			491.8
Deferred Credits and Other Liabilities:
Deferred income taxes	705.3		607.3			574.1
Pension and postretirement benefit costs	300.4		303.7			246.9
Asset retirement obligations	214.7		206.4			164.6
Regulatory liabilities	139.8		130.7			105.7
Other	74.7		66.1			73.7
Total Deferred Credits and Other Liabilities	1,434.9		1,314.2			1,165.0
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$	6,298.2	$	6,064.4		$	5,299.0
See the accompanying Notes to Financial Statements.

7

SPIRE INC.

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS’ EQUITY

(UNAUDITED)

	Common Stock Outstanding				Paid-in Capital			Retained Earnings			AOCI*
(Dollars in millions)	Shares		Amount											Total
Balance at September 30, 2015	43,335,012		$	43.3	$	1,038.1		$	494.2		$	(2.0	)	$	1,573.6
Net income	—		—		—			158.4			—			158.4
Common stock offering	2,185,000		2.2		131.0			—			—			133.2
Dividend reinvestment plan	17,454		—		1.0			—			—			1.0
Stock-based compensation costs	—		—		4.6			—			—			4.6
Stock issued under stock-based compensation plans	127,489		0.1		0.5			—			—			0.6
Employee’s tax withholding for stock-based compensation	(29,227	)	—		(1.7		)	—			—			(1.7		)
Dividends declared	—		—		—			(64.0		)	—			(64.0		)
Other comprehensive loss, net of tax	—		—		—			—			(3.3		)	(3.3		)
Balance at June 30, 2016	45,635,728		$	45.6	$	1,173.5		$	588.6		$	(5.3	)	$	1,802.4
Balance at September 30, 2016	45,650,642		$	45.6	$	1,175.9		$	550.9		$	(4.2	)	$	1,768.2
Net income	—		—		—			174.9			—			174.9
Common stock offering	2,504,684		2.5		143.0			—			—			145.5
Dividend reinvestment plan	18,025		—		1.2			—			—			1.2
Stock-based compensation costs	—		—		5.9			0.9			—			6.8
Stock issued under stock-based compensation plans	119,660		0.1		(0.1		)	—			—			—
Employee’s tax withholding for stock-based compensation	(35,167	)	—		(2.2		)	—			—			(2.2		)
Dividends declared	—		—		—			(73.6		)	—			(73.6		)
Other comprehensive income, net of tax	—		—		—			—			7.4			7.4
Balance at June 30, 2017	48,257,844		$	48.2	$	1,323.7		$	653.1		$	3.2		$	2,028.2
* Accumulated other comprehensive income (loss)
See the accompanying Notes to Financial Statements.

8

SPIRE INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Nine Months Ended June 30,
(In millions)	2017			2016
Operating Activities:
Net Income	$	174.9		$	158.4
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	114.4			102.0
Deferred income taxes and investment tax credits	84.1			77.7
Changes in assets and liabilities:
Accounts receivable	(33.1		)	6.7
Unamortized purchased gas adjustments	(26.1		)	(11.3		)
Accounts payable	14.8			(6.4		)
Delayed/advance customer billings – net	(59.7		)	7.8
Taxes accrued	(4.8		)	(10.9		)
Inventories	27.5			71.5
Other assets and liabilities	24.2			(38.5		)
Other	4.5			(0.1		)
Net cash provided by operating activities	320.7			356.9
Investing Activities:
Capital expenditures	(298.6		)	(195.3		)
Settlement for acquisition of EnergySouth	3.8			—
Other	1.1			(1.5		)
Net cash used in investing activities	(293.7		)	(196.8		)
Financing Activities:
Issuance of long-term debt	250.0			80.0
Repayment of long-term debt	(393.8		)	(80.0		)
Issuance (repayment) of short-term debt - net	52.0			(240.4		)
Issuance of common stock	146.4			136.1
Dividends paid	(70.9		)	(62.9		)
Other	(7.6		)	(1.8		)
Net cash used in financing activities	(23.9		)	(169.0		)
Net Increase (Decrease) in Cash and Cash Equivalents	3.1			(8.9		)
Cash and Cash Equivalents at Beginning of Period	5.2			13.8
Cash and Cash Equivalents at End of Period	$	8.3		$	4.9
Supplemental disclosure of cash (paid) refunded for:
Interest	$	(54.5	)	$	(48.2	)
Income taxes	(0.7		)	3.9
See the accompanying Notes to Financial Statements.

9

LACLEDE GAS COMPANY

CONDENSED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended June 30,				Nine Months Ended June 30,
(In millions)	2017		2016		2017		2016
Operating Revenues:
Utility	$	198.5	$	179.3	$	1,009.3	$	943.2
Total Operating Revenues	198.5		179.3		1,009.3		943.2
Operating Expenses:
Utility
Natural and propane gas	61.9		48.0		494.4		440.6
Operation and maintenance	61.2		58.4		179.2		178.7
Depreciation and amortization	23.2		22.3		68.9		66.0
Taxes, other than income taxes	21.7		21.2		81.6		76.4
Total Operating Expenses	168.0		149.9		824.1		761.7
Operating Income	30.5		29.4		185.2		181.5
Other Income	0.7		1.0		2.7		2.2
Interest Charges:
Interest on long-term debt	8.0		8.1		24.5		24.7
Other interest charges	1.5		1.0		4.4		3.2
Total Interest Charges	9.5		9.1		28.9		27.9
Income Before Income Taxes	21.7		21.3		159.0		155.8
Income Tax Expense	6.2		7.4		48.5		48.2
Net Income	$	15.5	$	13.9	$	110.5	$	107.6
See the accompanying Notes to Financial Statements.

10

LACLEDE GAS COMPANY

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(UNAUDITED)

	Three Months Ended June 30,				Nine Months Ended June 30,
(In millions)	2017		2016		2017		2016
Net Income	$	15.5	$	13.9	$	110.5	$	107.6
Other Comprehensive Income, Net of Tax	—		0.1		—		0.3
Comprehensive Income	$	15.5	$	14.0	$	110.5	$	107.9
See the accompanying Notes to Financial Statements.

11

LACLEDE GAS COMPANY

CONDENSED BALANCE SHEETS

(UNAUDITED)

	June 30,			September 30,			June 30,
(Dollars in millions, except per share amounts)	2017			2016			2016
ASSETS
Utility Plant	$	2,914.1		$	2,718.5		$	2,659.7
Less: Accumulated depreciation and amortization	670.3			604.5			595.4
Net Utility Plant	2,243.8			2,114.0			2,064.3
Goodwill	210.2			210.2			210.2
Other Property and Investments	58.9			57.3			56.5
Total Other Property and Investments	269.1			267.5			266.7
Current Assets:
Cash and cash equivalents	2.6			2.1			1.5
Accounts receivable:
Utility	94.4			87.9			101.0
Associated companies	1.7			2.2			1.3
Other	13.8			11.4			10.5
Allowance for doubtful accounts	(13.4		)	(16.1		)	(16.5		)
Delayed customer billings	7.0			1.6			3.5
Inventories:
Natural gas	93.6			127.3			78.2
Propane gas	12.0			12.0			12.0
Materials and supplies	11.3			9.2			9.2
Derivative instrument assets	0.7			4.9			5.1
Unamortized purchased gas adjustments	29.0			43.1			0.6
Other regulatory assets	38.2			23.9			23.7
Prepayments and other	21.3			14.5			20.4
Total Current Assets	312.2			324.0			250.5
Deferred Charges:
Regulatory assets	583.4			589.8			562.6
Other	3.1			1.1			5.0
Total Deferred Charges	586.5			590.9			567.6
Total Assets	$	3,411.6		$	3,296.4		$	3,149.1

12

LACLEDE GAS COMPANY

CONDENSED BALANCE SHEETS (Continued)

(UNAUDITED)

	June 30,			September 30,			June 30,
	2017			2016			2016
CAPITALIZATION AND LIABILITIES
Capitalization:
Paid-in capital and common stock (par value $1.00 per share; 50,000 authorized; 24,577 shares issued and outstanding)	$	755.3		$	752.0		$	750.9
Retained earnings	414.0			318.3			333.9
Accumulated other comprehensive loss	(1.8		)	(1.8		)	(1.4		)
Total Common Stock Equity	1,167.5			1,068.5			1,083.4
Long-term debt	804.5			804.1			803.9
Total Capitalization	1,972.0			1,872.6			1,887.3
Current Liabilities:
Notes payable	—			243.7			97.6
Notes payable – associated companies	260.2			—			38.8
Accounts payable	54.0			67.6			49.7
Accounts payable – associated companies	5.4			5.4			4.1
Advance customer billings	0.7			49.1			35.2
Wages and compensation accrued	29.4			29.9			28.7
Dividends payable	—			14.0			22.4
Customer deposits	13.2			13.5			13.3
Interest accrued	9.5			7.7			9.4
Taxes accrued	28.3			29.1			21.0
Regulatory liabilities	2.7			1.3			1.3
Other	7.5			9.9			9.1
Total Current Liabilities	410.9			471.2			330.6
Deferred Credits and Other Liabilities:
Deferred income taxes	620.9			556.9			548.8
Pension and postretirement benefit costs	204.2			211.8			191.9
Asset retirement obligations	77.9			75.2			75.0
Regulatory liabilities	83.6			67.3			65.7
Other	42.1			41.4			49.8
Total Deferred Credits and Other Liabilities	1,028.7			952.6			931.2
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$	3,411.6		$	3,296.4		$	3,149.1
See the accompanying Notes to Financial Statements.

13

LACLEDE GAS COMPANY

CONDENSED STATEMENTS OF COMMON SHAREHOLDER’S EQUITY

(UNAUDITED)

	Common Stock Outstanding			Paid-in Capital		Retained Earnings			AOCI*
(Dollars in millions)	Shares	Amount										Total
Balance at September 30, 2015	24,577	$	0.1	$	748.2	$	291.2		$	(1.7	)	$	1,037.8
Net income	—	—		—		107.6			—			107.6
Stock-based compensation costs	—	—		2.6		—			—			2.6
Dividends declared	—	—		—		(64.9		)	—			(64.9		)
Other comprehensive income, net of tax	—	—		—		—			0.3			0.3
Balance at June 30, 2016	24,577	$	0.1	$	750.8	$	333.9		$	(1.4	)	$	1,083.4
Balance at September 30, 2016	24,577	$	0.1	$	751.9	$	318.3		$	(1.8	)	$	1,068.5
Net income	—	—		—		110.5			—			110.5
Stock-based compensation costs	—	—		3.3		—			—			3.3
Dividends declared	—	—		—		(14.8		)	—			(14.8		)
Balance at June 30, 2017	24,577	$	0.1	$	755.2	$	414.0		$	(1.8	)	$	1,167.5
* Accumulated other comprehensive income (loss)
See the accompanying Notes to Financial Statements.

14

LACLEDE GAS COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Nine Months Ended June 30,
(In millions)	2017			2016
Operating Activities:
Net Income	$	110.5		$	107.6
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	68.9			66.0
Deferred income taxes and investment tax credits	48.5			48.2
Changes in assets and liabilities:
Accounts receivable	(11.0		)	24.6
Unamortized purchased gas adjustments	12.8			21.7
Accounts payable	(6.2		)	(7.3		)
Delayed/advance customer billings – net	(53.8		)	9.1
Taxes accrued	(0.7		)	(4.5		)
Inventories	31.6			60.1
Other assets and liabilities	0.5			(29.4		)
Other	1.4			0.7
Net cash provided by operating activities	202.5			296.8
Investing Activities:
Capital expenditures	(189.5		)	(138.8		)
Other	0.7			0.9
Net cash used in investing activities	(188.8		)	(137.9		)
Financing Activities:
Repayment of short-term debt - net	(243.7		)	(135.4		)
Borrowings from Spire - net	260.2			38.8
Dividends paid	(28.7		)	(62.5		)
Other	(1.0		)	—
Net cash used in financing activities	(13.2		)	(159.1		)
Net Increase (Decrease) in Cash and Cash Equivalents	0.5			(0.2		)
Cash and Cash Equivalents at Beginning of Period	2.1			1.7
Cash and Cash Equivalents at End of Period	$	2.6		$	1.5
Supplemental disclosure of cash (paid) refunded for:
Interest	$	(26.9	)	$	(22.1	)
Income taxes	—			2.1
See the accompanying Notes to Financial Statements.

15

ALABAMA GAS CORPORATION

CONDENSED STATEMENTS OF INCOME

(UNAUDITED)

	Three Months Ended June 30,				Nine Months Ended June 30,
(In millions)	2017		2016		2017		2016
Operating Revenues:
Utility	$	90.5	$	74.0	$	336.0	$	322.3
Total Operating Revenues	90.5		74.0		336.0		322.3
Operating Expenses:
Utility
Natural gas	22.5		13.1		65.1		55.4
Operation and maintenance	32.9		33.5		95.6		99.7
Depreciation and amortization	12.6		11.9		37.2		35.5
Taxes, other than income taxes	7.0		6.2		23.9		23.1
Total Operating Expenses	75.0		64.7		221.8		213.7
Operating Income	15.5		9.3		114.2		108.6
Other Income	0.6		0.5		2.1		1.5
Interest Charges:
Interest on long-term debt	2.8		2.8		8.4		8.5
Other interest charges	0.8		0.6		2.3		1.9
Total Interest Charges	3.6		3.4		10.7		10.4
Income Before Income Taxes	12.5		6.4		105.6		99.7
Income Tax Expense	5.1		2.4		40.3		37.7
Net Income	$	7.4	$	4.0	$	65.3	$	62.0
See the accompanying Notes to Financial Statements.

16

ALABAMA GAS CORPORATION

CONDENSED BALANCE SHEETS

(UNAUDITED)

	June 30,			September 30,			June 30,
(Dollars in millions, except per share amounts)	2017			2016			2016
ASSETS
Utility Plant	$	1,809.0		$	1,729.6		$	1,679.8
Less: Accumulated depreciation and amortization	791.2			756.6			716.1
Net Utility Plant	1,017.8			973.0			963.7
Current Assets:
Cash and cash equivalents	0.1			—			—
Accounts receivable:
Utility	40.6			34.0			32.2
Associated companies	0.2			—			—
Other	5.8			7.2			5.3
Allowance for doubtful accounts	(2.2		)	(3.3		)	(3.7		)
Inventories:
Natural gas	29.0			34.6			28.3
Materials and supplies	5.9			5.9			6.0
Deferred income taxes	—			—			5.0
Unamortized purchased gas adjustments	44.9			5.6			4.8
Other regulatory assets	17.3			14.9			13.8
Prepayments and other	6.6			5.1			6.1
Total Current Assets	148.2			104.0			97.8
Deferred Charges:
Regulatory assets	228.7			230.7			167.5
Deferred income taxes	181.1			221.4			211.0
Other	63.2			60.8			57.7
Total Deferred Charges	473.0			512.9			436.2
Total Assets	$	1,639.0		$	1,589.9		$	1,497.7

17

ALABAMA GAS CORPORATION

CONDENSED BALANCE SHEETS (Continued)

(UNAUDITED)

	June 30,		September 30,		June 30,
	2017		2016		2016
CAPITALIZATION AND LIABILITIES
Capitalization:
Paid-in capital and common stock (par value $0.01 per share; 3.0 million shares authorized; 2.0 million shares issued and outstanding)	$	420.9	$	451.9	$	451.9
Retained earnings	463.5		415.4		432.2
Total Common Stock Equity	884.4		867.3		884.1
Long-term debt	247.7		247.6		247.6
Total Capitalization	1,132.1		1,114.9		1,131.7
Current Liabilities:
Notes payable	—		82.0		—
Notes payable – associated companies	114.9		—		37.8
Accounts payable	45.1		34.3		26.6
Accounts payable – associated companies	1.4		0.4		1.3
Advance customer billings	15.2		21.1		17.8
Wages and compensation accrued	7.5		7.8		7.8
Customer deposits	18.1		18.2		18.6
Interest accrued	3.5		3.3		3.6
Taxes accrued	20.5		21.6		19.8
Regulatory liabilities	17.8		22.7		21.1
Other	3.4		6.3		5.1
Total Current Liabilities	247.4		217.7		159.5
Deferred Credits and Other Liabilities:
Pension and postretirement benefit costs	77.9		74.3		55.0
Asset retirement obligations	125.4		120.1		89.4
Regulatory liabilities	34.4		41.7		40.0
Other	21.8		21.2		22.1
Total Deferred Credits and Other Liabilities	259.5		257.3		206.5
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	$	1,639.0	$	1,589.9	$	1,497.7
See the accompanying Notes to Financial Statements.

18

ALABAMA GAS CORPORATION

CONDENSED STATEMENTS OF COMMON SHAREHOLDER’S EQUITY

(UNAUDITED)

	Common Stock Outstanding			Paid-in Capital			Retained Earnings
(Dollars in millions)	Shares	Amount								Total
Balance at September 30, 2015	1,972,052	$	—	$	480.9		$	393.7		$	874.6
Net income	—	—		—			62.0			62.0
Return of capital to Spire	—	—		(29.0		)	—			(29.0		)
Dividends declared	—	—		—			(23.5		)	(23.5		)
Balance at June 30, 2016	1,972,052	$	—	$	451.9		$	432.2		$	884.1
Balance at September 30, 2016	1,972,052	$	—	$	451.9		$	415.4		$	867.3
Net income	—	—		—			65.3			65.3
Return of capital to Spire	—	—		(31.0		)	—			(31.0		)
Dividends declared	—	—		—			(17.2		)	(17.2		)
Balance at June 30, 2017	1,972,052	$	—	$	420.9		$	463.5		$	884.4
See the accompanying Notes to Financial Statements.

19

ALABAMA GAS CORPORATION

CONDENSED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Nine Months Ended June 30,
(In millions)	2017			2016
Operating Activities:
Net Income	$	65.3		$	62.0
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	37.2			35.5
Deferred income taxes and investment tax credits	40.3			37.7
Changes in assets and liabilities:
Accounts receivable	(12.4		)	(6.4		)
Unamortized purchased gas adjustments	(39.3		)	(33.0		)
Accounts payable	10.7			4.3
Advance customer billings	(5.9		)	(1.3		)
Taxes accrued	(1.1		)	(6.2		)
Inventories	5.6			11.5
Other assets and liabilities	(4.1		)	(7.0		)
Other	(0.3		)	(0.7		)
Net cash provided by operating activities	96.0			96.4
Investing Activities:
Capital expenditures	(80.2		)	(56.1		)
Other	—			(1.8		)
Net cash used in investing activities	(80.2		)	(57.9		)
Financing Activities:
Issuance of long-term debt	—			80.0
Redemption and maturity of long-term debt	—			(80.0		)
Repayment of short-term debt - net	(82.0		)	(31.0		)
Borrowings from Spire - net	114.9			37.8
Return of capital to Spire	(31.0		)	(29.0		)
Dividends paid	(17.2		)	(23.5		)
Other	(0.4		)	—
Net cash used in financing activities	(15.7		)	(45.7		)
Net Increase (Decrease) in Cash and Cash Equivalents	0.1			(7.2		)
Cash and Cash Equivalents at Beginning of Period	—			7.2
Cash and Cash Equivalents at End of Period	$	0.1		$	—
Supplemental disclosure of cash (paid) refunded for:
Interest	$	(9.3	)	$	(9.2	)
Income taxes	—			0.8
See the accompanying Notes to Financial Statements.

20

SPIRE INC., LACLEDE GAS COMPANY AND ALABAMA GAS CORPORATION

NOTES TO FINANCIAL STATEMENTS

(UNAUDITED)

(Dollars in millions, except per share amounts)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION –These notes are an integral part of the accompanying unaudited financial statements of Spire Inc. (Spire or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Laclede Gas, Alagasco and the subsidiaries of EnergySouth, Inc. (EnergySouth) are collectively referred to as the Utilities. The subsidiaries of EnergySouth are Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas & Oil Company (Willmut Gas).

The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial information with the instructions to Form 10-Q and Rule 10-01 of Regulation S‑X. Accordingly, they do not include all of the disclosures required for complete financial statements. In the opinion of management, the accompanying unaudited financial statements include all adjustments (consisting of only normal recurring adjustments) necessary for the fair presentation of the results of operations for the periods presented. This Form 10-Q should be read in conjunction with the Notes to Financial Statements contained in Spire’s, Laclede Gas’, and Alagasco’s Annual Reports on Form 10-K for the fiscal year ended September 30, 2016.

The consolidated financial position, results of operations, and cash flows of Spire are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between Laclede Gas and Alagasco and their affiliates, as well as intercompany balances on their balance sheets, have not been eliminated from their separate financial statements. Results of operations of EnergySouth are included in Spire’s results of operations since the September 12, 2016 acquisition and impact the comparability of financial statement periods presented for the Company.

NATURE OF OPERATIONS – Spire Inc. (NYSE: SR), headquartered in St. Louis, Missouri, is a public utility holding company. The Company has two reportable segments: Gas Utility and Gas Marketing. The Gas Utility segment consists of the regulated natural gas distribution operations of the Company and is the core business segment of Spire in terms of revenue and earnings generation. The Gas Utility segment is comprised of the operations of: the Missouri Utilities, serving St. Louis and eastern Missouri, Kansas City and western Missouri (through MGE); Alagasco, serving central and northern Alabama; and the subsidiaries of EnergySouth, serving southern Alabama and south-central Mississippi. Spire’s primary non-utility business, Spire Marketing Inc. (Spire Marketing) was formerly known as Laclede Energy Resources, Inc., which changed its name on December 12, 2016. Spire Marketing is included in the Gas Marketing segment and provides non-regulated natural gas services. The activities of other subsidiaries are described in Note 9, Information by Operating Segment, and are reported as Other. Laclede Gas and Alagasco each have a single reportable segment.

The Company’s earnings are primarily derived from its Gas Utility segment. Due to the seasonal nature of the Utilities’ business, earnings are typically concentrated during the heating season of November through April each fiscal year. As a result, the interim statements of income for Spire, Laclede Gas and Alagasco are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year.

GOODWILL – Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. The changes in the carrying amount of goodwill by reportable segment are shown below, reflecting the effect of a $3.8 cash payment to Spire related to the EnergySouth acquisition, offset by net adjustments to acquired insurance receivable and prepaid assets.

	Gas Utility		Gas Marketing		Other			Total
Balance as of September 30, 2016	$	210.2	$	—	$	954.7		$	1,164.9
Adjustments related to the acquisition of EnergySouth	—		—		(1.0		)	(1.0		)
Balance as of June 30, 2017	$	210.2	$	—	$	953.7		$	1,163.9

21

REVENUE RECOGNITION – The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues for Laclede Gas at June 30, 2017, September 30, 2016, and June 30, 2016 were $31.9, $26.1, and $28.5, respectively.

Alagasco records natural gas distribution revenues in accordance with the tariff established by the Alabama Public Service Commission (APSC). Unbilled revenues for Alagasco, which are not recorded as revenue until billed, at June 30, 2017, September 30, 2016, and June 30, 2016 were $6.0, $5.9, and $6.4, respectively.

The subsidiaries of EnergySouth record natural gas revenues in accordance with tariffs established by the APSC and the Mississippi Public Service Commission (MSPSC). Their unbilled revenues are accrued as described for Laclede Gas above.

Spire’s other subsidiaries, including Spire Marketing, record revenues when earned, either when the product is delivered or when services are performed.

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

GROSS RECEIPTS TAXES – Gross receipts taxes associated with the Company’s natural gas utility services are imposed on the Utilities and billed to their customers. The revenue and expense amounts are recorded gross in the “Operating Revenues” and “Taxes, other than income taxes” lines, respectively, in the statements of income. The following table presents gross receipts taxes recorded as revenues.

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Spire	$	18.0	$	14.8	$	71.7	$	65.0
Laclede Gas	12.4		11.1		52.0		49.7
Alagasco	4.2		3.7		16.1		15.3

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

As authorized by the Missouri Public Service Commission (MoPSC), MSPSC and APSC, the Purchased Gas Adjustment (PGA) clauses and Gas Supply Adjustment (GSA) riders allow the Utilities to pass through to customers the cost of purchased gas supplies. Regulatory assets and liabilities related to the PGA clauses and the GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. See additional information about regulatory assets and liabilities in Note 3, Regulatory Matters.

22

TRANSACTIONS WITH AFFILIATES –Transactions between affiliates of the Company have been eliminated from the consolidated financial statements of Spire. Laclede Gas and Alagasco borrowed funds from the Company and incurred related interest, as reflected in their separate financial statements, and participated in normal intercompany shared services transactions. Laclede Gas’ and Alagasco’s other transactions with affiliates included:

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Laclede Gas
Purchases of natural gas from Spire Marketing	$	11.8	$	6.7	$	53.3	$	31.5
Sales of natural gas to Spire Marketing	1.5		—		7.8		1.7
Insurance services received from Laclede Insurance Risk Services	0.5		0.2		1.6		0.7
Transportation services received from Laclede Pipeline Company	0.3		0.3		0.8		0.8
Alagasco
Insurance services received from Laclede Insurance Risk Services	0.5		—		1.5		—

ACCRUED CAPITAL EXPENDITURES – Accrued capital expenditures, shown in the following table, are excluded from capital expenditures in the statements of cash flows.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	26.5	$	21.6	$	9.9
Laclede Gas	16.5		14.8		5.3
Alagasco	7.9		6.8		4.6

RECLASSIFICATIONS – Certain prior period amounts have been reclassified to conform to the current period presentation. Net income and total equity were not affected by these reclassifications.

NEW ACCOUNTING PRONOUNCEMENTS – In April 2015, the FASB issued Accounting Standards Update (ASU) No. 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs. Under prior GAAP, debt issuance costs were recorded as a deferred charge (asset), while debt discount and debt premium costs were recorded as a liability adjustment. This amendment requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Spire, Laclede Gas and Alagasco adopted this ASU as of December 31, 2016. Retrospective adjustments have been made to the previous year balance sheets as of September 30, 2016 and June 30, 2016. The amounts reclassified from other deferred charges to reduce long-term debt are shown in the following table. The ASU does not address the presentation of debt issuance costs related to line-of-credit arrangements, and those continue to be reported as deferred charges.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	14.9	$	13.0	$	11.9
Laclede Gas	4.0		4.2		4.4
Alagasco	2.3		2.4		2.4

In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation: Improvements to Employee Share-Based Payment Accounting. The standard is intended to simplify several areas of accounting for share-based compensation arrangements, including the income tax impact, classification on the statement of cash flows and forfeitures. Spire, Laclede Gas and Alagasco adopted this ASU in the interim quarterly reporting period ended June 30, 2017. Amendments related to the timing of when excess tax benefits are recognized, minimum statutory withholding requirements, and forfeitures were applied using a modified retrospective transition method by means of a cumulative-effect adjustment to retained earnings as of October 1, 2016, and amendments requiring recognition of excess tax benefits and tax deficiencies in the income statement were applied prospectively as of that date. Amendments related to the presentation of excess tax benefits on the statement of cash flows and the presentation of employee taxes paid on the statement of cash flows when an employer withholds shares to meet the minimum statutory withholding requirement were applied retrospectively. There were no material impacts on the financial statements of the Company, Laclede Gas, or Alagasco, all of which adopted a policy of accounting for forfeitures when they occur.

23

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers. Under the new standard, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. In doing so, companies may need to use more judgment and make more estimates than under current guidance. ASU No. 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. Entities have the option of using either a full retrospective or modified retrospective approach to adopting this guidance. In August 2015, the FASB issued ASU No. 2015-14, which made the guidance in ASU No. 2014-09 effective for fiscal years beginning after December 15, 2017 and interim periods within those years. In 2016, the FASB issued related ASU Nos. 2016-08, 2016-10, 2016-11, 2016-12, and 2016-20 which further modified the standards for accounting for revenue. The Company, Laclede Gas and Alagasco are currently evaluating their sources of revenue and related contracts, the available transition methods, and the potential impacts of the updates. The conclusions of these assessments are contingent, in part, upon the completion of deliberations currently in progress by the power and utilities industry, notably in connection with efforts to produce an accounting guide being developed by the American Institute of Certified Public Accountants (AICPA). In association with this undertaking, the AICPA formed a number of industry task forces, including a Power & Utilities Task Force. Industry representatives and organizations, the largest auditing firms, the AICPA’s Revenue Recognition Working Group and its Financial Reporting Executive Committee have undertaken, and continue to undertake, consideration of several items relevant to our industry as further discussed below. Where applicable or necessary, the FASB’s Transition Resource Group is also participating. Currently, the industry is working to finalize conclusions in several areas including 1) the accounting for funds received from third parties to partially or fully reimburse the cost of construction of an asset, 2) determination of stand-alone selling price for commodities, and 3) the accounting for alternative revenue programs, such as performance-based ratemaking. Existing alternative revenue program guidance, though excluded by the FASB in updating specific guidance associated with revenue from contracts with customers, was relocated without substantial modification to accounting guidance for rate-regulated entities. It will require separate presentation of such revenues (subject to the above-noted deliberations) in the statement of income. Pending the completion of the industry deliberations and internal assessments later this year, the Company, Laclede Gas and Alagasco are currently unable to determine the effect the new guidance will have on their financial position, results of operations, cash flows, and business processes or the transition method they will utilize to adopt the new guidance in the first quarter of fiscal year 2019 (or earlier).

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments – Overall: Recognition and Measurement of Financial Assets and Financial Liabilities, which provides revised guidance concerning certain matters involving the recognition, measurement, and disclosure of financial instruments. It is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Unrealized gains and losses on equity securities previously classified as available-for-sale will be recognized immediately in earnings rather than recorded in other comprehensive income. Entities will record a cumulative-effect adjustment as of the beginning of the fiscal year in which the guidance is adopted, which requires amounts reported in accumulated other comprehensive income for such equity securities to be reclassified to retained earnings. Based on an assessment of their current financial instruments, the Company, Laclede Gas and Alagasco expect to adopt this standard in the first quarter of fiscal year 2019 with no significant impact.

In February 2016, the FASB issued ASU No. 2016-02, Leases. The new standard requires lessees to recognize a right-of-use asset and lease liability for almost all lease contracts based on the present value of lease payments. There is an exemption for short-term leases. The ASU provides new guidelines for identifying and classifying a lease, and classification affects the pattern and income statement line item for the related expense. This update will be applied using a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The ASU is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2020.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses: Measurement of Credit Losses on Financial Instruments. The standard introduces new guidance for the accounting for credit losses on instruments within its scope, including trade receivables. It is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years, and may be adopted a year earlier. The new guidance will be initially applied through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2021.

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In March 2017, the FASB issued ASU No. 2017-07, Compensation – Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amended guidance requires that the service cost component of pension and postretirement benefit costs be presented within the same line item in the income statement as other compensation costs (except for the amount being capitalized), while other components are to be presented outside the subtotal of operating income and are no longer eligible for capitalization. The ASU is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The amended guidance will be applied retrospectively for income statement presentation and prospectively for capitalization. The Company, Laclede Gas and Alagasco are currently assessing the regulatory and other impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2019.

2. EARNINGS PER COMMON SHARE

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Basic EPS:
Net Income	$	21.7	$	10.7	$	174.9	$	158.4
Less: Income allocated to participating securities	0.1		—		0.4		0.5
Net Income Available to Common Shareholders	$	21.6	$	10.7	$	174.5	$	157.9
Weighted Average Shares Outstanding (in millions)	48.1		44.4		46.4		43.6
Basic Earnings Per Share of Common Stock	$	0.45	$	0.24	$	3.76	$	3.62
Diluted EPS:
Net Income	$	21.7	$	10.7	$	174.9	$	158.4
Less: Income allocated to participating securities	0.1		—		0.4		0.5
Net Income Available to Common Shareholders	$	21.6	$	10.7	$	174.5	$	157.9
Weighted Average Shares Outstanding (in millions)	48.1		44.4		46.4		43.6
Dilutive Effect of Restricted Stock, Restricted Stock Units, and Stock Options (in millions)*	0.1		0.2		0.2		0.2
Weighted Average Diluted Shares (in millions)	48.2		44.6		46.6		43.8
Diluted Earnings Per Share of Common Stock	$	0.45	$	0.24	$	3.75	$	3.60
* Calculation excludes certain outstanding shares (shown in millions by period at the right) attributable to stock units subject to performance or market conditions and restricted stock, which could have a dilutive effect in the future	0.4		0.5		0.4		0.5

Spire’s 2.875 million equity units issued in June 2014 were anti-dilutive for the three and nine months ended June 30, 2016; accordingly, they were excluded from the calculation of weighted average diluted shares for those periods. On April 3, 2017, Spire settled the purchase contracts underlying those equity units, by issuing approximately 2.5 million shares of its common stock.

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3. REGULATORY MATTERS

As explained in Note 1, Summary of Significant Accounting Policies, Laclede Gas and Alagasco account for regulated operations in accordance with FASB ASC Topic 980, “Regulated Operations.” The following regulatory assets and regulatory liabilities, including purchased gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of June 30, 2017, September 30, 2016 and June 30, 2016.

	June 30,		September 30,		June 30,
Spire	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	41.7	$	27.0	$	26.9
Unamortized purchased gas adjustments	73.9		49.7		5.4
Other	29.0		17.2		10.6
Total Regulatory Assets (current)	144.6		93.9		42.9
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	453.4		487.9		434.4
Cost of removal	135.4		130.6		81.2
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	43.4		30.1		29.6
Total Regulatory Assets (non-current)	840.5		838.0		730.7
Total Regulatory Assets	$	985.1	$	931.9	$	773.6
Regulatory Liabilities:
Current:
Rate Stabilization and Equalization (RSE) adjustment	$	1.2	$	7.5	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Unamortized purchased gas adjustments	1.0		1.7		—
Other	9.5		6.2		3.8
Total Regulatory Liabilities (current)	25.9		30.6		22.4
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Accrued cost of removal	74.6		74.8		55.4
Other	34.1		17.6		13.8
Total Regulatory Liabilities (non-current)	139.8		130.7		105.7
Total Regulatory Liabilities	$	165.7	$	161.3	$	128.1

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	June 30,		September 30,		June 30,
Laclede Gas	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	34.9	$	20.2	$	20.2
Unamortized purchased gas adjustments	29.0		43.1		0.6
Other	3.3		3.7		3.5
Total Regulatory Assets (current)	67.2		67.0		24.3
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	352.3		375.7		352.1
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	22.8		24.7		25.0
Total Regulatory Assets (non-current)	583.4		589.8		562.6
Total Regulatory Assets	$	650.6	$	656.8	$	586.9
Regulatory Liabilities:
Current:
Other	$	2.7	$	1.3	$	1.3
Total Regulatory Liabilities (current)	2.7		1.3		1.3
Non-current:
Accrued cost of removal	54.8		55.1		55.4
Other	28.8		12.2		10.3
Total Regulatory Liabilities (non-current)	83.6		67.3		65.7
Total Regulatory Liabilities	$	86.3	$	68.6	$	67.0

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	June 30,		September 30,		June 30,
Alagasco	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	6.8	$	6.8	$	6.7
Unamortized purchased gas adjustments	44.9		5.6		4.8
Other	10.5		8.1		7.1
Total Regulatory Assets (current)	62.2		20.5		18.6
Non-current:
Pension and postretirement benefit costs	92.2		98.9		82.3
Cost of removal	135.4		130.6		81.2
Other	1.1		1.2		4.0
Total Regulatory Assets (non-current)	228.7		230.7		167.5
Total Regulatory Assets	$	290.9	$	251.2	$	186.1
Regulatory Liabilities:
Current:
RSE adjustment	$	1.2	$	5.0	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Other	2.4		2.5		2.5
Total Regulatory Liabilities (current)	17.8		22.7		21.1
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Other	3.3		3.4		3.5
Total Regulatory Liabilities (non-current)	34.4		41.7		40.0
Total Regulatory Liabilities	$	52.2	$	64.4	$	61.1

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

	Spire						Laclede Gas
	June 30,		September 30,		June 30,		June 30,		September 30,		June 30,
	2017		2016		2016		2017		2016		2016
Future income taxes due from customers	$	166.6	$	151.3	$	146.4	$	166.6	$	151.3	$	146.4
Pension and postretirement benefit costs	231.0		240.6		203.8		231.0		240.6		203.8
Other	11.4		12.9		13.2		11.4		12.9		13.2
Total Regulatory Assets Not Earning a Return	$	409.0	$	404.8	$	363.4	$	409.0	$	404.8	$	363.4

Like all the Company’s regulatory assets, these regulatory assets are expected to be recovered from customers in future rates. The recovery period for the future income taxes due from customers and pension and postretirement benefit costs could be as long as 20 years, based on current Internal Revenue Service guidelines and average remaining service life of active participants, respectively. The other items not earning a return are expected to be recovered over a period not to exceed 15 years, consistent with precedent set by the MoPSC. Alagasco does not have any regulatory assets that are not earning a return.

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4. FINANCING ARRANGEMENTS AND LONG-TERM DEBT

On December 14, 2016, Spire, Laclede Gas, and Alagasco entered into a new syndicated revolving credit facility pursuant to a loan agreement with 11 banks, expiring December 14, 2021. The largest portion provided by a single bank under the line is 12.3%. The loan agreement replaces Spire’s and Laclede Gas’ existing loan agreements dated as of September 3, 2013 and amended September 3, 2014, which were set to expire on September 3, 2019, and Alagasco’s existing loan agreement dated September 2, 2014, which was set to expire September 2, 2019. All three agreements were terminated on December 14, 2016.

The loan agreement has an aggregate credit commitment of $975.0, including sublimits of $300.0 for Spire, $475.0 for Laclede Gas, and $200.0 for Alagasco. These sublimits may be reallocated from time to time among the three borrowers within the $975.0 aggregate commitment. Spire may use its line to provide for the funding needs of various subsidiaries. Spire, Laclede Gas, and Alagasco expect to use the loan agreement for general corporate purposes, including short-term borrowings and letters of credit. The agreement also contains financial covenants limiting each borrower’s consolidated total debt, including short-term debt, to no more than 70% of its total capitalization. As defined in the line of credit, on June 30, 2017, total debt was 54% of total capitalization for the consolidated Company, 48% for Laclede Gas, and 29% for Alagasco.

On December 21, 2016, Spire established a commercial paper program (Program) pursuant to which Spire may issue short-term, unsecured commercial paper notes (Notes). Amounts available under the Program may be borrowed, repaid, and re-borrowed from time to time, with the aggregate face or principal amount of the Notes outstanding under the Program at any time not to exceed $975.0. The Notes may have maturities of up to 365 days from date of issue. The net proceeds of the issuances of the Notes are expected to be used for general corporate purposes, including to provide working capital for both utility and non-utility subsidiaries. As of June 30, 2017, Notes outstanding under the Program totaled $450.7. Of that amount, $260.2 and $114.9 were lent to Laclede Gas and Alagasco, respectively, at Spire’s cost.

On March 10, 2017, Spire redeemed in full at par its $250.0 floating rate notes due August 15, 2017, plus accrued and unpaid interest.

On March 15, 2017, Spire completed the issuance and sale of $100.0 in aggregate principal amount of Senior Notes due March 15, 2027. The notes bear interest at the rate of 3.93% per annum, payable semi-annually. The notes are senior unsecured obligations of the Company. Spire used the proceeds from the sale of the notes for the repayment of other debt.

In 2014, Spire issued 2.875 million equity units as a portion of the Alagasco acquisition financing. The equity units were originally issued at $50 per unit pursuant to the Purchase Contract and Pledge Agreement (purchase contract) dated as of June 11, 2014 between Spire and U.S. Bank National Association, as purchase contract agent, collateral agent, custodial agent and securities intermediary. These units consisted of $143.8 aggregate principal amount of 2014 Series A 2.00% remarketable junior subordinated notes due 2022 (the Junior Notes) and the purchase contract obligating the holder to purchase common shares at a future settlement date (set to be three years in the future and prior to the Junior Notes maturity). The equity unit investments were effectively replaced as planned in a series of transactions outlined below:

– On February 22, 2017, the selling securityholders (as defined below) agreed to purchase the Junior Notes in connection with the remarketing of the junior subordinated notes that comprised a component of the equity units.

– On the same day, Spire entered into two related agreements: (1) a Securities Purchase and Registration Rights Agreement (the SPRRA), among Spire and the several purchasers named therein (the selling securityholders), obligating the selling securityholders to sell the Junior Notes to Spire in exchange for $143.8 aggregate principal amount of Spire’s 3.543% Senior Notes due 2024 (the Senior Notes) and a cash payment, and (2) an underwriting agreement with the selling securityholders and the several underwriters named therein in connection with the public offering of $150.0 aggregate principal amount of Senior Notes consisting of $6.2 principal amount of the Senior Notes issued and sold by Spire and $143.8 principal amount of the Senior Notes sold by the selling securityholders. The SPRRA granted the selling securityholders the right to offer the Senior Notes to the public in secondary public offerings.

– The public offering was completed on February 27, 2017. Spire used its net proceeds from its sale of the Senior Notes to repay short-term debt. Spire did not receive any proceeds from the sale of the Senior Notes by the selling securityholders.

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– On April 3, 2017, Spire settled the purchase contracts underlying its 2.875 million equity units by issuing approximately 2.5 million shares of its common stock at a purchase price of $57.3921 per share. Fractional shares were settled in cash at $67.50 per share. The purchase price was funded with the proceeds from the Junior Notes. Under the contract terms, the equity units were converted to common stock at the rate of 0.8712, with a corresponding adjustment to purchase price. Spire received net cash proceeds of approximately $142.0, which it used to repay short-term debt incurred the previous month to redeem the floating rate notes.

5. FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts of cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. Refer to Note 6, Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis.

The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis are shown below and classified according to the fair value hierarchy. There were no such instruments classified as Level 3 (significant unobservable inputs) as of June 30, 2017, September 30, 2016, or June 30, 2016.

		Classification of Estimated Fair Value
Carrying Amount	Fair Value	Quoted Prices in Active Markets (Level 1)	Significant Observable Inputs (Level 2)

Spire

As of June 30, 2017
Cash and cash equivalents	$	8.3	$	8.3	$	8.3	$	—
Short-term debt	450.7		450.7		—		450.7
Long-term debt	1,925.3		2,033.0		—		2,033.0
As of September 30, 2016
Cash and cash equivalents	$	5.2	$	5.2	$	5.2	$	—
Short-term debt	398.7		398.7		—		398.7
Long-term debt, including current portion	2,070.7		2,257.1		—		2,257.1
As of June 30, 2016
Cash and cash equivalents	$	4.9	$	4.9	$	4.9	$	—
Short-term debt	97.6		97.6		—		97.6
Long-term debt	1,839.8		2,014.3		—		2,014.3

Laclede Gas

As of June 30, 2017
Cash and cash equivalents	$	2.6	$	2.6	$	2.6	$	—
Short-term debt	260.2		260.2		—		260.2
Long-term debt	804.5		883.9		—		883.9
As of September 30, 2016
Cash and cash equivalents	$	2.1	$	2.1	$	2.1	$	—
Short-term debt	243.7		243.7		—		243.7
Long-term debt	804.1		900.4		—		900.4
As of June 30, 2016
Cash and cash equivalents	$	1.5	$	1.5	$	1.5	$	—
Short-term debt	136.4		136.4		—		136.4
Long-term debt	803.9		901.8		—		901.8

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					Classification of Estimated Fair Value
	Carrying Amount		Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)
Alagasco
As of June 30, 2017
Cash and cash equivalents	$	0.1	$	0.1	$	0.1	$	—
Short-term debt	114.9		114.9		—		114.9
Long-term debt	247.7		267.6		—		267.6
As of September 30, 2016
Short-term debt	$	82.0	$	82.0	$	—	$	82.0
Long-term debt	247.6		275.5		—		275.5
As of June 30, 2016
Short-term debt	$	37.8	$	37.8	$	—	$	37.8
Long-term debt	247.6		272.5		—		272.5

6. FAIR VALUE MEASUREMENTS

The information presented below 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.

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

Derivative instruments included in Level 1 are valued using quoted market prices on the New York Mercantile Exchange (NYMEX) or the Intercontinental Exchange (ICE). Derivative instruments classified in Level 2 include physical commodity derivatives that are valued using Over-the-Counter Bulletin Board (OTCBB), broker, or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. Also included in Level 2 are certain derivative instruments that have values that are similar to, and correlate with, quoted prices for exchange-traded instruments in active markets and derivative instruments with settlement dates more than one year into the future. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. The Level 3 balances as of June 30, 2017, September 30, 2016 and June 30, 2016 consisted of gas commodity contracts. The Company’s and the Utilities’ policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer.

The mutual funds are included in “Other Investments” on the Company’s balance sheets and in “Other Property and Investments” on Laclede Gas’ balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exists between the Company, Laclede Gas, or Alagasco and the counterparty to a derivative contract.

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Spire

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of June 30, 2017
ASSETS
Gas Utility
US stock/bond mutual funds	$	18.0	$	4.1		$	—	$	—		$	22.1
NYMEX/ICE natural gas contracts	1.9		—			—		(1.3		)	0.6
Gasoline and heating oil contracts	0.1		—			—		—			0.1
Subtotal	20.0		4.1			—		(1.3		)	22.8
Gas Marketing
NYMEX/ICE natural gas contracts	1.5		3.2			—		(2.6		)	2.1
Natural gas commodity contracts	—		6.1			0.6		(1.7		)	5.0
Total	$	21.5	$	13.4		$	0.6	$	(5.6	)	$	29.9
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	1.3	$	—		$	—	$	(1.3	)	$	—
Gas Marketing
NYMEX/ICE natural gas contracts	0.8		1.8			—		(2.6		)	—
Natural gas commodity contracts	—		6.7			—		(1.7		)	5.0
Other
Interest rate swaps	—		(0.6		)	—		—			(0.6		)
Total	$	2.1	$	7.9		$	—	$	(5.6	)	$	4.4

32

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of September 30, 2016
ASSETS
Gas Utility
US stock/bond mutual funds	$	16.8	$	4.1	$	—	$	—		$	20.9
NYMEX/ICE natural gas contracts	5.3		—		—		(0.4		)	4.9
NYMEX gasoline and heating oil contracts	0.4		—		—		(0.3		)	0.1
Subtotal	22.5		4.1		—		(0.7		)	25.9
Gas Marketing
NYMEX/ICE natural gas contracts	0.4		3.4		—		(3.4		)	0.4
Natural gas commodity contracts	—		8.7		0.2		(0.9		)	8.0
Total	$	22.9	$	16.2	$	0.2	$	(5.0	)	$	34.3
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	1.6	$	—	$	—	$	(1.6	)	$	—
OTCBB natural gas contracts	—		0.2		—		—			0.2
Subtotal	1.6		0.2		—		(1.6		)	0.2
Gas Marketing
NYMEX/ICE natural gas contracts	3.5		1.6		—		(5.1		)	—
Natural gas commodity contracts	—		2.6		—		(0.9		)	1.7
Other
Interest rate swaps	—		3.0		—		—			3.0
Total	$	5.1	$	7.4	$	—	$	(7.6	)	$	4.9
As of June 30, 2016
ASSETS
Gas Utility
US stock/bond mutual funds	$	16.4	$	4.0	$	—	$	—		$	20.4
NYMEX/ICE natural gas contracts	8.2		—		—		(3.1		)	5.1
Subtotal	24.6		4.0		—		(3.1		)	25.5
Gas Marketing
NYMEX/ICE natural gas contracts	0.6		5.5		—		(5.6		)	0.5
Natural gas commodity contracts	—		6.3		0.3		(0.6		)	6.0
Total	$	25.2	$	15.8	$	0.3	$	(9.3	)	$	32.0
LIABILITIES
Gas Utility
OTCBB natural gas contracts	$	—	$	0.6	$	—	$	—		$	0.6
Subtotal	—		0.6		—		—			0.6
Gas Marketing
NYMEX/ICE natural gas contracts	6.5		2.5		—		(9.0		)	—
Natural gas commodity contracts	—		3.4		—		(0.5		)	2.9
Other
Interest Rate Swaps	—		4.0		—		—			4.0
Total	$	6.5	$	10.5	$	—	$	(9.5	)	$	7.5

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Laclede Gas

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of June 30, 2017
ASSETS
US stock/bond mutual funds	$	18.0	$	4.1	$	—	$	—		$	22.1
NYMEX/ICE natural gas contracts	1.9		—		—		(1.3		)	0.6
NYMEX gasoline and heating oil contracts	0.1		—		—		—			0.1
Total	$	20.0	$	4.1	$	—	$	(1.3	)	$	22.8
LIABILITIES
NYMEX/ICE natural gas contracts	$	1.3	$	—	$	—	$	(1.3	)	$	—
Total	$	1.3	$	—	$	—	$	(1.3	)	$	—

As of September 30, 2016
ASSETS
US stock/bond mutual funds	$	16.8	$	4.1	$	—	$	—		$	20.9
NYMEX/ICE natural gas contracts	5.3		—		—		(0.4		)	4.9
NYMEX gasoline and heating oil contracts	0.3		—		—		(0.3		)	—
Total	$	22.4	$	4.1	$	—	$	(0.7	)	$	25.8
LIABILITIES
NYMEX/ICE natural gas contracts	$	1.6	$	—	$	—	$	(1.6	)	$	—
OTCBB natural gas contracts	—		0.2		—		—			0.2
Total	$	1.6	$	0.2	$	—	$	(1.6	)	$	0.2

As of June 30, 2016
ASSETS
US stock/bond mutual funds	$	16.4	$	4.0	$	—	$	—		$	20.4
NYMEX/ICE natural gas contracts	8.2		—		—		(3.1		)	5.1
Total	$	24.6	$	4.0	$	—	$	(3.1	)	$	25.5
LIABILITIES
OTCBB natural gas contracts	$	—	$	0.6	$	—	$	—		$	0.6
Total	$	—	$	0.6	$	—	$	—		$	0.6

Alagasco

During the fiscal second quarter of 2016 Alagasco commenced a gasoline derivative program to stabilize the cost of fuel used in operations. As of June 30, 2017, September 30, 2016, and June 30, 2016, the fair value of related gasoline contracts was not significant.

34

7. CONCENTRATIONS OF CREDIT RISK

Other than in Spire Marketing, Spire has no significant concentrations of credit risk.

A significant portion of Spire Marketing’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. The concentration of transactions with these counterparties has the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. To manage this risk, as well as credit risk from significant counterparties in these and other industries, Spire Marketing has established procedures to determine the creditworthiness of its counterparties. These procedures include obtaining credit ratings and credit reports, analyzing counterparty financial statements to assess financial condition, and considering the industry environment in which the counterparty operates. This information is monitored on an ongoing basis. In some instances, Spire Marketing may require credit assurances such as prepayments, letters of credit, or parental guarantees. In addition, Spire Marketing may enter into netting arrangements to mitigate credit risk with counterparties in the energy industry with whom it conducts both sales and purchases of natural gas. Sales are typically made on an unsecured credit basis with payment due the month following delivery. Accounts receivable amounts are closely monitored and provisions for uncollectible amounts are accrued when losses are probable. Spire Marketing records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in its accounts receivable attributable to energy producers and their marketing affiliates totaled $10.6 at June 30, 2017 ($5.6 reflecting netting arrangements). Spire Marketing’s accounts receivable attributable to utility companies and their marketing affiliates were $63.8 at June 30, 2017 ($60.0 reflecting netting arrangements).

Spire Marketing also has concentrations of credit risk with certain individually significant counterparties and with pipeline companies associated with its natural gas receivable amounts. At June 30, 2017, the amounts included in accounts receivable from its five largest counterparties (in terms of net accounts receivable exposure) totaled $30.7 ($29.0 reflecting netting arrangements). Four of these five counterparties are investment-grade rated companies. The fifth is not rated.

8. PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

Pension Plans

The pension plans of Spire consist of plans for employees at the Missouri Utilities, plans covering employees of Alagasco, and plans for employees of EnergySouth since September 12, 2016.

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

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

35

The net periodic pension cost included the following components:

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Spire
Service cost – benefits earned during the period	$	5.0		$	3.8		$	15.5		$	11.5
Interest cost on projected benefit obligation	7.0			6.9			20.8			21.0
Expected return on plan assets	(9.4		)	(8.6		)	(29.0		)	(26.3		)
Amortization of prior service cost	0.2			0.1			0.7			0.3
Amortization of actuarial loss	3.0			1.9			9.6			5.9
Loss on lump-sum settlements	—			0.2			11.9			2.4
Special termination benefits	—			—			—			1.6
Subtotal	5.8			4.3			29.5			16.4
Regulatory adjustment	3.1			4.4			0.3			11.1
Net pension cost	$	8.9		$	8.7		$	29.8		$	27.5

Laclede Gas
Service cost – benefits earned during the period	$	3.0		$	2.5		$	9.6		$	7.5
Interest cost on projected benefit obligation	4.8			5.4			14.5			16.2
Expected return on plan assets	(6.8		)	(6.7		)	(21.2		)	(20.1		)
Amortization of prior service cost	0.2			0.1			0.7			0.3
Amortization of actuarial loss	2.5			1.9			8.2			5.9
Loss on lump-sum settlements	—			—			11.5			—
Special termination benefits	—			—			—			1.6
Subtotal	3.7			3.2			23.3			11.4
Regulatory adjustment	1.3			3.0			(4.5		)	8.8
Net pension cost	$	5.0		$	6.2		$	18.8		$	20.2

Alagasco
Service cost – benefits earned during the period	$	1.6		$	1.3		$	4.7		$	4.0
Interest cost on projected benefit obligation	1.6			1.5			4.6			4.8
Expected return on plan assets	(1.8		)	(1.9		)	(5.4		)	(6.2		)
Amortization of actuarial loss	0.5			—			1.4			—
Loss on lump-sum settlements	—			0.2			0.4			2.4
Subtotal	1.9			1.1			5.7			5.0
Regulatory adjustment	1.6			1.4			4.3			2.3
Net pension cost	$	3.5		$	2.5		$	10.0		$	7.3

Pursuant to the provisions of the Missouri Utilities’ and Alagasco’s pension plans, pension obligations may be satisfied by monthly annuities, lump-sum cash payments, or special termination benefits. Lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs in a specific year. Special termination benefits, when offered, are also recognized as settlements which can result in gains or losses. In the quarter ended March 31, 2017, the Laclede Gas plan and one of the Alagasco plans met the criteria for settlement recognition, resulting in the remeasurement of the obligation of the plans using updated census data and assumptions for discount and mortality. The total lump-sum payments recognized as settlements for plan remeasurement were $36.3 and $1.9 for the Laclede plan and Alagasco plan, respectively. The lump-sum settlements resulted in losses of $11.5 and $0.4 for the Laclede plan and Alagasco plan, respectively. In the quarters ended March 31 and June 30, 2016, an Alagasco plan met the criteria for settlement recognition. The lump-sum payments recognized as settlements for the Alagasco remeasurements totaled $12.6. The lump-sum settlement resulted in a loss of $2.2 and $0.2 in the quarters ended March 31 and June 30, 2016, respectively. In the quarter ended December 31, 2015, the Laclede Gas pension plans provided qualified employees with voluntary early retirement packages that qualified as special termination benefits, resulting in a charge of $1.6. All gains and losses on lump-sum settlements were recorded with a regulatory adjustment and did not impact income.

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The funding policy of the Utilities is to contribute an amount not less than the minimum required by government funding standards, nor more than the maximum deductible amount for federal income tax purposes. Fiscal year 2017 contributions to Laclede Gas’ pension plans through June 30, 2017 were $22.5 to the qualified trusts and $0.2 to non-qualified plans. There were no fiscal 2017 contributions to the Alagasco pension plans through June 30, 2017.

Contributions to the Missouri Utilities’ pension plans for the remainder of fiscal 2017 are anticipated to be $6.5 to the qualified trusts and $0.4 to the non-qualified plans. No contributions to Alagasco’s pension plans are expected to be required for the remainder of fiscal 2017, but a voluntary contribution is likely in September.

Postretirement Benefits

The Utilities provide certain life insurance benefits at retirement. Laclede Gas plans provide for medical insurance after early retirement until age 65. For retirements prior to January 1, 2015, the MGE plans provided medical insurance after retirement until death. For retirements after January 1, 2015, the MGE plans provide medical insurance after early retirement until age 65. Under the Alagasco plans, medical insurance is currently available upon retirement until death for certain retirees depending on the type of employee and the date the employee was originally hired.

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

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Spire
Service cost – benefits earned during the period	$	2.7		$	2.7		$	8.2		$	8.2
Interest cost on accumulated postretirement benefit obligation	2.2			2.6			6.5			7.6
Expected return on plan assets	(3.5		)	(3.3		)	(10.3		)	(10.1		)
Amortization of prior service credit	—			0.1			—			0.2
Amortization of actuarial loss	0.6			0.9			1.8			2.7
Special termination benefits	—			—			—			2.6
Subtotal	2.0			3.0			6.2			11.2
Regulatory adjustment	(0.8		)	(1.7		)	(2.4		)	(7.6		)
Net postretirement benefit cost	$	1.2		$	1.3		$	3.8		$	3.6

Laclede Gas
Service cost – benefits earned during the period	$	2.6		$	2.6		$	7.8		$	7.9
Interest cost on accumulated postretirement benefit obligation	1.7			2.1			5.1			6.1
Expected return on plan assets	(2.3		)	(2.1		)	(6.8		)	(6.4		)
Amortization of prior service credit	0.1			0.1			0.2			0.2
Amortization of actuarial loss	0.6			1.0			1.9			2.9
Special termination benefits	—			—			—			2.6
Subtotal	2.7			3.7			8.2			13.3
Regulatory adjustment	(0.4		)	(1.2		)	(1.1		)	(6.2		)
Net postretirement benefit cost	$	2.3		$	2.5		$	7.1		$	7.1

Alagasco
Service cost – benefits earned during the period	$	—		$	0.1		$	0.2		$	0.3
Interest cost on accumulated postretirement benefit obligation	0.4			0.5			1.2			1.5
Expected return on plan assets	(1.1		)	(1.2		)	(3.3		)	(3.7		)
Amortization of prior service credit	(0.1		)	—			(0.2		)	—
Amortization of actuarial gain	—			(0.1		)	(0.1		)	(0.2		)
Subtotal	(0.8		)	(0.7		)	(2.2		)	(2.1		)
Regulatory adjustment	(0.5		)	(0.5		)	(1.4		)	(1.4		)
Net postretirement benefit income	$	(1.3	)	$	(1.2	)	$	(3.6	)	$	(3.5	)

37

Missouri and Alabama state law provide for the recovery in rates of costs accrued pursuant to GAAP provided that such costs are funded through an independent, external funding mechanism. The Utilities have established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi Trusts as external funding mechanisms. The assets of the VEBA and Rabbi Trusts consist primarily of money market securities and mutual funds invested in stocks and bonds. During the quarter ended December 31, 2015, the Laclede Gas postretirement plan offered qualified employees voluntary enhanced early retirement packages that resulted in a special termination benefits charge of $2.6.

The Utilities’ funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. Year-to-date contributions to the postretirement plans through June 30, 2017 totaled $8.8 for the Missouri Utilities. Contributions to the postretirement plans for the remainder of fiscal year 2017 are anticipated to be $5.1 to the qualified trusts and $0.4 paid directly to participants from the Missouri Utilities’ funds. For Alagasco, there were no contributions to the postretirement plans during the nine months of fiscal year 2017, and none are expected to be required for the remainder of the fiscal year.

9. INFORMATION BY OPERATING SEGMENT

The Company has two reportable segments: Gas Utility and Gas Marketing. The Gas Utility segment is the aggregation of the regulated operations of the Utilities. The Gas Marketing segment includes the results of Spire Marketing, a subsidiary engaged in the non-regulated marketing of natural gas and related activities, including utilizing natural gas storage contracts for providing natural gas sales. In addition, other non-utility activities of the Company include:

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

• Spire STL Pipeline LLC, a subsidiary of Spire planning construction of a proposed 65-mile Federal Energy Regulatory Commission (FERC)-regulated pipeline to deliver natural gas into eastern Missouri; and

• Spire’s subsidiaries engaged in the operation of a propane pipeline, compression of natural gas and risk management, among other activities. All subsidiaries are wholly owned.

Accounting policies are described in Note 1, Summary of Significant Accounting Policies. Intersegment transactions include sales of natural gas from Spire Marketing to Laclede Gas and from Laclede Gas to Spire Marketing, insurance services provided by Laclede Insurance Risk Services to Laclede Gas and Alagasco, and propane transportation services provided by Laclede Pipeline Company to Laclede Gas.

Management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impacts of net unrealized gains and losses and other timing differences associated with energy-related transactions. Net economic earnings also exclude the after-tax impacts related to acquisition, divestiture, and restructuring activities.

38

	Gas Utility		Gas Marketing			Other			Eliminations			Consolidated
Three Months Ended June 30, 2017
Operating Revenues:
Revenues from external customers	$	305.1	$	17.9		$	0.5		$	—		$	323.5
Intersegment revenues	1.5		—			1.6			(3.1		)	—
Total Operating Revenues	306.6		17.9			2.1			(3.1		)	323.5
Operating Expenses:
Gas Utility
Natural and propane gas	88.7		—			—			(12.0		)	76.7
Operation and maintenance	101.9		—			—			(1.1		)	100.8
Depreciation and amortization	38.4		—			—			—			38.4
Taxes, other than income taxes	30.5		—			—			—			30.5
Total Gas Utility Operating Expenses	259.5		—			—			(13.1		)	246.4
Gas Marketing and Other	—		12.0			4.8			10.0			26.8
Total Operating Expenses	259.5		12.0			4.8			(3.1		)	273.2
Operating Income (Loss)	$	47.1	$	5.9		$	(2.7	)	$	—		$	50.3
Net Economic Earnings (Loss)	$	23.3	$	2.3		$	(4.0	)	$	—		$	21.6
Three Months Ended June 30, 2016
Operating Revenues:
Revenues from external customers	$	253.2	$	(4.3	)	$	0.4		$	—		$	249.3
Intersegment revenues	0.1		6.6			0.5			(7.2		)	—
Total Operating Revenues	253.3		2.3			0.9			(7.2		)	249.3
Operating Expenses:
Gas Utility
Natural and propane gas	61.1		—			—			(7.0		)	54.1
Operation and maintenance	91.9		—			—			(0.1		)	91.8
Depreciation and amortization	34.2		—			—			—			34.2
Taxes, other than income taxes	27.4		—			—			—			27.4
Total Gas Utility Operating Expenses	214.6		—			—			(7.1		)	207.5
Gas Marketing and Other	—		3.9			2.7			(0.1		)	6.5
Total Operating Expenses	214.6		3.9			2.7			(7.2		)	214.0
Operating Income (Loss)	$	38.7	$	(1.6	)	$	(1.8	)	$	—		$	35.3
Net Economic Earnings (Loss)	$	18.0	$	1.8		$	(5.2	)	$	—		$	14.6

39

	Gas Utility		Gas Marketing			Other			Eliminations			Consolidated
Nine Months Ended June 30, 2017
Operating Revenues:
Revenues from external customers	$	1,419.1	$	61.8		$	1.1		$	—		$	1,482.0
Intersegment revenues	7.9		—			4.6			(12.5		)	—
Total Operating Revenues	1,427.0		61.8			5.7			(12.5		)	1,482.0
Operating Expenses:
Gas Utility
Natural and propane gas	578.8		—			—			(54.0		)	524.8
Operation and maintenance	301.7		—			—			(3.1		)	298.6
Depreciation and amortization	114.0		—			—			—			114.0
Taxes, other than income taxes	112.2		—			—			—			112.2
Total Gas Utility Operating Expenses	1,106.7		—			—			(57.1		)	1,049.6
Gas Marketing and Other	—		58.9			9.1			44.6			112.6
Total Operating Expenses	1,106.7		58.9			9.1			(12.5		)	1,162.2
Operating Income (Loss)	$	320.3	$	2.9		$	(3.4	)	$	—		$	319.8
Net Economic Earnings (Loss)	$	187.3	$	3.7		$	(12.9	)	$	—		$	178.1
Nine Months Ended June 30, 2016
Operating Revenues:
Revenues from external customers	$	1,263.5	$	(6.7	)	$	1.2		$	—		$	1,258.0
Intersegment revenues	2.0		29.8			1.4			(33.2		)	—
Total Operating Revenues	1,265.5		23.1			2.6			(33.2		)	1,258.0
Operating Expenses:
Gas Utility
Natural and propane gas	496.0		—			—			(32.3		)	463.7
Operation and maintenance	278.4		—			—			(0.7		)	277.7
Depreciation and amortization	101.5		—			—			—			101.5
Taxes, other than income taxes	99.5		—			—			—			99.5
Total Gas Utility Operating Expenses	975.4		—			—			(33.0		)	942.4
Gas Marketing and Other	—		18.4			7.4			(0.2		)	25.6
Total Operating Expenses	975.4		18.4			7.4			(33.2		)	968.0
Operating Income (Loss)	$	290.1	$	4.7		$	(4.8	)	$	—		$	290.0
Net Economic Earnings (Loss)	$	170.5	$	4.5		$	(11.8	)	$	—		$	163.2

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

	June 30,			September 30,			June 30,
	2017			2016			2016
Total Assets:
Gas Utility	$	5,323.1		$	5,184.7		$	4,646.9
Gas Marketing	223.6			205.0			167.8
Other	2,171.8			1,836.6			1,592.6
Eliminations	(1,420.3		)	(1,161.9		)	(1,108.3		)
Total Assets	$	6,298.2		$	6,064.4		$	5,299.0

40

The following table reconciles the Company’s net economic earnings to net income.

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Net Income	$	21.7		$	10.7		$	174.9		$	158.4
Adjustments, pre-tax:
Unrealized (gain) loss on energy-related derivative contracts	(2.2		)	4.9			3.2			2.9
Lower of cost or market inventory adjustments	—			(0.1		)	—			0.6
Realized gain on economic hedges prior to sale of the physical commodity	—			(0.3		)	(0.2		)	(0.9		)
Acquisition, divestiture and restructuring activities	1.9			1.8			2.1			5.1
Income tax effect of adjustments	0.2			(2.4		)	(1.9		)	(2.9		)
Net Economic Earnings	$	21.6		$	14.6		$	178.1		$	163.2

10. COMMITMENTS AND CONTINGENCIES

Commitments

The Company and the Utilities have entered into contracts with various counterparties, expiring on dates through 2031, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at June 30, 2017 are estimated at approximately $1,311.6, $518.7, and $296.5 for the Company, Laclede Gas, and Alagasco, respectively. Additional contracts are generally entered into prior to or during the heating season of November through April. The Utilities recover their costs from customers in accordance with their PGA clauses or GSA riders.

Contingencies

The Company and Utilities account for environmental liabilities and other contingencies in accordance with accounting standards under the loss contingency guidance of ASC Topic 450, “Contingencies,” when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated.

The Company and the Utilities own and operate natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Utilities’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, the Company or the Utilities may incur additional environmental liabilities that may result in additional costs, which may be material.

In addition to matters noted below, the Company, Laclede Gas, and Alagasco are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome will not have a material effect on the consolidated statements of income, balance sheets, and statements of cash flows of the Company, Laclede Gas, or Alagasco. However, there is uncertainty in the valuation of pending claims and prediction of litigation results.

In the natural gas industry, many gas distribution companies have incurred environmental liabilities associated with sites they or their predecessor companies formerly owned or operated where manufactured gas operations took place. The Utilities each have former manufactured gas plant (MGP) operations in their respective service territories.

Laclede Gas

Laclede Gas has identified four former MGP sites in eastern Missouri where costs have been incurred and claims have been asserted: one in Shrewsbury, Missouri and three in the city of St. Louis, Missouri (City). Laclede Gas has enrolled two of the sites in the City in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP). The third site in the City is the result of a new claim assertion by the United States Environmental Protection Agency (EPA) and such claim is currently being investigated. In Laclede Gas’ western service area, MGE has enrolled all of its owned former MGP sites in the BVCP.

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With regard to the former MGP site located in Shrewsbury, Missouri, Laclede Gas and state and federal environmental regulators agreed upon certain remedial actions to a portion of the site in a 1999 Administrative Order on Consent (AOC), which actions have been completed. On September 22, 2008, the EPA Region VII issued a letter of Termination and Satisfaction terminating the AOC. However, if after this termination of the AOC, regulators require additional remedial actions, or additional claims are asserted, Laclede Gas may incur additional costs.

In conjunction with redevelopment of one of the sites located in the City, Laclede Gas and another former owner of the site entered into an agreement (Remediation Agreement) with the City development agencies, the developer, and an environmental consultant that obligates one of the City agencies and the environmental consultant to remediate the site and obtain a No Further Action letter from the Missouri Department of Natural Resources (MDNR). The Remediation Agreement also provides for a release of Laclede Gas and the other former site owner from certain liabilities related to the past and current environmental condition of the site and requires the developer and the environmental consultant to maintain certain insurance coverage, including remediation cost containment, premises pollution liability, and professional liability. The operative provisions of the Remediation Agreement were triggered on December 20, 2010, on which date Laclede Gas and the other former site owner, as full consideration under the Remediation Agreement, paid a small percentage of the cost of remediation of the site. The amount paid by Laclede Gas did not materially impact the financial condition, results of operations, or cash flows of the Company.

Laclede Gas has not owned the second site located in the City for many years. In a letter dated June 29, 2011, the Attorney General for the state of Missouri informed Laclede Gas that the MDNR had completed an investigation of the site. The Attorney General requested that Laclede Gas participate in the follow up investigations of the site. In a letter dated January 10, 2012, Laclede Gas stated that it would participate in future environmental response activities at the site in conjunction with other potentially responsible parties (PRPs) that are willing to contribute to such efforts in a meaningful and equitable fashion. Accordingly, Laclede Gas entered into a cost sharing agreement for remedial investigation with other PRPs. Pending MDNR approval, which has not occurred to date, the remedial investigation of the site will begin.

Additionally, in correspondence dated November 30, 2016, Region 7 of the EPA has asserted that Laclede Gas is liable under Section 107(a) of the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (CERCLA) for alleged coal gas waste contamination at a third site in the northern portion of the City on which Laclede Gas operated a MGP. Laclede Gas has not owned or operated the site (also known as Station “B”) for over 70 years. Laclede Gas and the site owner have met with the EPA and reviewed its assertions. Both Laclede and the site owner have notified EPA that the information and data provided by EPA to date does not rise to the level of documenting a threat to the public health or environment. As such, Laclede Gas is requesting more information from the EPA, some of which will also be utilized to identify other former owners and operators of the site that could be added as PRPs. To date, Laclede has not received a response from the EPA.

Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the MGP sites. While some of the insurers have denied coverage and reserved their rights, Laclede Gas continues to discuss potential reimbursements with them.

On March 10, 2015, Laclede Gas received a Section 104(e) information request from EPA Region 7 regarding the former Thompson Chemical/Superior Solvents site in the City. In turn, Laclede Gas issued a Freedom of Information Act (FOIA) request to the EPA on April 3, 2015, in an effort to identify the basis of the inquiry. The FOIA response from the EPA was received on July 15, 2015 and a response was provided to the EPA on August 15, 2015. Laclede Gas has received no further inquiry from the EPA regarding this matter.

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 area, Kansas City Coal Gas Station A North, Kansas City Coal Gas Station A South, and Independence MGP #2. Source removal has been conducted at all of the owned sites since 2003 with the exception of Joplin. On September 15, 2016, a request was made with the MDNR for a restrictive covenant use limitation with respect to Joplin. Remediation efforts at the seven sites are at various stages of completion, ranging from groundwater monitoring and sampling following source removal activities to the aforementioned request in respect to Joplin. As part of its participation in the BVCP, MGE communicates regularly with the MDNR with respect to its remediation efforts and monitoring activities at these sites. On May 11, 2015, MDNR approved the next phase of investigation at the Kansas City Station A North and Railroad areas.

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To date, costs incurred for all Missouri Utilities’ MGP sites for investigation, remediation and monitoring these sites have not been material. However, the amount of costs relative to future remedial actions at these and other sites is unknown and may be material. The actual future costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remediation actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and government regulations, the ultimate ability of other PRPs to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries.

In 2013, Laclede Gas retained an outside consultant to conduct probabilistic cost modeling of 19 former MGP sites owned or operated by Laclede Gas in eastern Missouri or MGE in western Missouri. The purpose of this analysis was to develop an estimated range of probabilistic future liability for each site. That analysis, completed in August 2014, provided a range of demonstrated possible future expenditures to investigate, monitor and remediate all 19 MGP sites. Laclede Gas has recorded its best estimate of the probable expenditures that relate to these matters. The amount is not material.

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

Alagasco

Alagasco is in the chain of title of nine former MGP sites, four of which it still owns, and five former manufactured gas distribution sites, one of which it still owns. As of June 30, 2017, Alagasco does not foresee a probable or reasonably estimable loss associated with these nine former MGP sites. Alagasco and the Company do not expect potential liabilities that may arise from remediating these sites to have a material impact on their future financial condition or results of operations.

In 2012, Alagasco responded to an EPA Request for Information Pursuant to Section 104 of CERCLA relating to the 35th Avenue Superfund Site located in North Birmingham, Jefferson County, Alabama. Alagasco was identified as a PRP under CERCLA for the cleanup of the site or costs the EPA incurs in cleaning up the site. At this point, Alagasco has not been provided information that would allow it to determine the extent, if any, of its potential liability with respect to the 35th Avenue Superfund Site and vigorously denies its inclusion as a PRP.

On December 17, 2013, an incident occurred at a Housing Authority apartment complex in Birmingham, Alabama that resulted in one fatality, personal injuries and property damage. Alagasco cooperated with the National Transportation Safety Board (NTSB) which investigated the incident. The NTSB report of findings was issued on March 30, 2016 and no safety recommendations, fines, or penalties were contained therein. Alagasco has been named as a defendant in several lawsuits arising from the incident, and additional lawsuits and claims may be filed against Alagasco.

Mobile Gas

Mobile Gas is in the chain of title of one former MGP site which it still owns in Mobile, Alabama. On September 15, 2010, Mobile Gas filed an application to enroll the site into the Alabama Department of Environmental Management’s (ADEM) Voluntary Cleanup Program (VCP). This application was accepted by ADEM on November 16, 2010. Investigation and testing have been completed. Mobile Gas received an approved remediation plan from ADEM and the remedial actions taken under the plan were completed by June 30, 2017. Mobile Gas and the Company do not expect potential liabilities that may arise from remediating this site to have a material impact on their future financial condition or results of operations.

Since April 2012, a total of 14 lawsuits have been filed against Mobile Gas in Mobile County Circuit Court alleging that in the first half of 2008, Mobile Gas spilled tert-butyl mercaptan, an odorant added to natural gas for safety reasons, in Eight Mile, Alabama. Eleven of the lawsuits have been settled. The remaining three lawsuits, which include approximately 270 individual plaintiffs, allege nuisance, fraud and negligence causes of actions, and seek unspecified compensatory and punitive damages. A claim has been made against the insurance carriers requesting reimbursement for costs accrued in respect to this spill, and a related receivable has been recorded. The Company does not expect potential liabilities that may arise from these lawsuits to have a material impact on its future financial condition or results of operations.

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

(Dollars in millions, except per share amounts)

This section analyzes the financial condition and results of operations of Spire Inc. (Spire or the Company), Laclede Gas Company (Laclede Gas or the Missouri Utilities), and Alabama Gas Corporation (Alagasco). Laclede Gas, Alagasco, and EnergySouth, Inc. (EnergySouth) are wholly owned subsidiaries of the Company. Laclede Gas, Alagasco and the subsidiaries of EnergySouth, are collectively referred to as the Utilities. The subsidiaries of EnergySouth are Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas & Oil Company (Willmut Gas). This section includes management’s view of factors that affect the respective businesses of the Company, Laclede Gas, and Alagasco, explanations of financial results including changes in earnings and costs from the prior periods, and the effects of such factors on the Company’s, Laclede Gas’ and Alagasco’s overall financial condition and liquidity.

Certain matters discussed in this report, excluding historical information, include forward-looking statements. Certain words, such as “may,” “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “seek,” and similar words and expressions identify forward-looking statements that involve uncertainties and risks. Future developments may not be in accordance with our current expectations or beliefs and the effect of future developments may not be those anticipated. Among the factors that may cause results to differ materially from those contemplated in any forward-looking statement are:

• Weather conditions and catastrophic events, particularly severe weather in the natural gas producing areas of the country;

• Volatility in gas prices, particularly sudden and sustained changes in natural gas prices, including the related impact on margin deposits associated with the use of natural gas derivative instruments;

• The impact of changes and volatility in natural gas prices on our competitive position in relation to suppliers of alternative heating sources, such as electricity;

• Changes in gas supply and pipeline availability, including decisions by natural gas producers to reduce production or shut in producing natural gas wells, expiration of existing supply and transportation arrangements that are not replaced with contracts with similar terms and pricing, as well as other changes that impact supply for and access to the markets in which our subsidiaries transact business;

• Acquisitions may not achieve their intended results, including anticipated cost savings;

• Legislative, regulatory and judicial mandates and decisions, some of which may be retroactive, including those affecting:

▪allowed rates of return,

▪incentive regulation,

▪industry structure,

▪purchased gas adjustment provisions,

▪rate design structure and implementation,

▪regulatory assets,

▪non-regulated and affiliate transactions,

▪franchise renewals,

▪ environmental or safety matters, including the potential impact of legislative and regulatory actions related to climate change and pipeline safety,

▪taxes,

▪pension and other postretirement benefit liabilities and funding obligations, or

▪accounting standards;

•The results of litigation;

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

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

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

• Capital and energy commodity market conditions, including the ability to obtain funds with reasonable terms for necessary capital expenditures and general operations and the terms and conditions imposed for obtaining sufficient gas supply;

• Discovery of material weakness in internal controls; and

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

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

RESULTS OF OPERATIONS

Overview

The Company has two reportable segments: Gas Utility and Gas Marketing. Spire’s earnings are primarily derived from its Gas Utility segment, which reflects the regulated activities of the Utilities. The Gas Utility segment consists of the regulated businesses of Laclede Gas, Alagasco and the subsidiaries of EnergySouth. Due to the seasonal nature of the Utilities’ business, earnings of Spire, Laclede Gas and Alagasco are typically concentrated during the heating season of November through April each fiscal year.

Gas Utility - Laclede Gas

Laclede Gas is Missouri’s largest natural gas distribution company and is regulated by the Missouri Public Service Commission (MoPSC). Laclede Gas serves St. Louis and eastern Missouri through Laclede Gas and serves Kansas City and western Missouri through Missouri Gas Energy (MGE). Laclede Gas delivers natural gas to retail customers at rates and in accordance with tariffs authorized by the MoPSC. The earnings of Laclede Gas are primarily generated by the sale of heating energy. The rate design for each service territory serves to lessen the impact of weather volatility on its customers during cold winters and stabilize Laclede Gas’ earnings.

Gas Utility - Alagasco

Alagasco is the largest natural gas distribution utility in the state of Alabama. Alagasco’s service territory is located in central and northern Alabama. Among the cities served by Alagasco are Birmingham, the center of the largest metropolitan area in Alabama, and Montgomery, the state capital. Alagasco is regulated by the Alabama Public Service Commission (APSC). Alagasco purchases natural gas through interstate and intrastate suppliers and distributes the purchased gas through its distribution facilities for sale to residential, commercial, and industrial customers and other end-users of natural gas. Alagasco also provides transportation services to large industrial and commercial customers located on its distribution system. These transportation customers, using Alagasco as their agent or acting on their own, purchase gas directly from marketers or suppliers and arrange for delivery of the gas into the Alagasco distribution system. Alagasco charges a fee to transport such customer-owned gas through its distribution system to the customers’ facilities.

Gas Marketing

Spire’s primary non-utility business, Spire Marketing Inc. (Spire Marketing), which changed its name from Laclede Energy Resources, Inc. on December 12, 2016, is engaged in the marketing of natural gas and related activities on a non-regulated basis. Spire Marketing markets natural gas across the country with the core of its footprint located in and around the central United States (US). It holds firm transportation and storage contracts in order to effectively manage its customer base, which consists of producers, pipelines, power generators, storage operators, municipalities, utility companies, and large commercial and industrial customers.

Other

In addition to the Gas Utility and Gas Marketing segments, other non-utility activities of the Company include:

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

• Spire STL Pipeline LLC, a subsidiary of Spire planning construction of a proposed 65-mile Federal Energy Regulatory Commission (FERC) regulated pipeline to deliver natural gas into eastern Missouri; and

• Spire’s subsidiaries engaged in the operation of a propane pipeline, compression of natural gas and risk management, among other activities. All subsidiaries are wholly owned.

EARNINGS

Net income reported by Spire, Laclede Gas and Alagasco is determined in accordance with accounting principles generally accepted in the United States of America (GAAP). Management also uses the non-GAAP financial measures of net economic earnings, net economic earnings per share and contribution margin when internally evaluating and reporting results of operations. These non-GAAP measures should not be considered as alternatives to, or more meaningful than, GAAP measures such as net income, earnings per share and operating income. Reconciliations of non-GAAP financial measures to the most directly comparable GAAP measures are provided on the following pages.

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

Net economic earnings and net economic earnings per share are non-GAAP measures that exclude from net income the after-tax impacts of fair value accounting and timing adjustments associated with energy-related transactions as well as acquisition, divestiture, and restructuring activities. These fair value and timing adjustments are made in instances where the accounting treatment differs from the economic substance of the underlying transaction, including the following:

• Net unrealized gains and losses on energy-related derivatives that are required by GAAP fair value accounting associated with current changes in the fair value of financial and physical transactions prior to their completion and settlement. These unrealized gains and losses result primarily from two sources:

1) changes in the fair values of physical and/or financial derivatives prior to the period of settlement; and,

2) ineffective portions of accounting hedges, required to be recorded in earnings prior to settlement, due to differences in commodity price changes between the locations of the forecasted physical purchase or sale transactions and the locations of the underlying hedge instruments;

• Lower of cost or market adjustments to the carrying value of commodity inventories resulting when the market price of the commodity falls below its original cost, to the extent that those commodities are economically hedged; and

• Realized gains and losses resulting from the settlement of economic hedges prior to the sale of the physical commodity.

These adjustments eliminate the impact of timing differences and the impact of current changes in the fair value of financial and physical transactions prior to their completion and settlement. Unrealized gains or losses are recorded in each period until being replaced with the actual gains or losses realized when the associated physical transactions occur. While management uses these non-GAAP measures to evaluate both the Utilities and non-utility businesses, the net effect of adjustments on the Utilities’ earnings is minimal because gains or losses on their natural gas derivative instruments are deferred pursuant to state regulation.

Management believes that excluding the earnings volatility caused by recognizing changes in fair value prior to settlement and other timing differences associated with related purchase and sale transactions provides a useful representation of the economic effects of only the actual settled transactions and their effects on results of operations. In addition, management excludes the impact related to unique acquisition, divestiture, and restructuring activities when evaluating on-going performance, and therefore excludes these impacts from net economic earnings. Management believes that this presentation provides a useful representation of operating performance by facilitating comparisons of year-over-year results. The definition and measurement of net economic earnings provided above is consistent with that used by management and the Board of Directors in assessing the Company’s, Laclede Gas’ and Alagasco’s performance as well as determining performance under the Company’s, Laclede Gas’ and Alagasco’s incentive compensation plans. Further, the Company believes this better enables an investor to view the Company’s, Laclede Gas’ and Alagasco’s performance in that period on a basis that would be comparable to prior periods.

Non-GAAP Measure – Contribution Margin

In addition to operating revenues and operating expenses, management also uses the non-GAAP measure of contribution margin when evaluating results of operations. The Utilities pass to their customers (subject to prudence review by, as applicable, the MoPSC, APSC, or MSPSC) increases and decreases in the wholesale cost of natural gas in accordance with their Purchased Gas Adjustment (PGA) clauses or Gas Supply Adjustment (GSA) rider. The volatility of the wholesale natural gas market results in fluctuations from period to period in the recorded levels of, among other items, revenues and natural gas cost expense. Nevertheless, increases and decreases in the cost of gas associated with system gas sales volumes and gross receipts tax expense, which are calculated as a percentage of revenues, with the same amount, excluding immaterial timing differences, included in revenues, has no direct effect on operating income. As these costs are included in revenue and operating expenses and management does not have any control over these amounts for the Utilities, management believes that contribution margin is a useful supplemental measure. In addition, it is management’s belief that contribution margin and the remaining operating expenses that calculate operating income are useful in assessing the Company’s and the Utilities’ performance as management has more ability to influence control over these revenues and expenses.

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SPIRE

Net Income and Net Economic Earnings

The following tables reconcile the Company’s net economic earnings to the most comparable GAAP number, net income.

		Gas Utility			Gas Marketing			Other			Total			Per Diluted Share**
Three Months Ended June 30, 2017
	Net Income (Loss) (GAAP)	$	23.0		$	3.7		$	(5.0	)	$	21.7		$	0.45
	Adjustments, pre-tax:
	Unrealized loss (gain) on energy-related derivatives	0.1			(2.3		)	—			(2.2		)	(0.05		)
	Acquisition, divestiture and restructuring activities	0.2			—			1.7			1.9			0.04
	Income tax effect of adjustments*	—			0.9			(0.7		)	0.2			—
	Net Economic Earnings (Loss) (Non-GAAP)**	$	23.3		$	2.3		$	(4.0	)	$	21.6		$	0.44
Three Months Ended June 30, 2016
	Net Income (Loss) (GAAP)	$	17.9		$	(1.0	)	$	(6.2	)	$	10.7		$	0.24
	Adjustments, pre-tax:
	Unrealized loss on energy-related derivatives	—			4.9			—			4.9			0.11
	Lower of cost or market inventory adjustments	—			(0.1		)	—			(0.1		)	—
	Realized gain on economic hedges prior      to the sale of the physical commodity	—			(0.3		)	—			(0.3		)	(0.01		)
	Acquisition, divestiture and restructuring activities	0.2			—			1.6			1.8			0.04
	Income tax effect of adjustments*	(0.1		)	(1.7		)	(0.6		)	(2.4		)	(0.06		)
	Weighted average shares adjustment	—			—			—			—			0.01
	Net Economic Earnings (Loss) (Non-GAAP)**	$	18.0		$	1.8		$	(5.2	)	$	14.6		$	0.33

* Income taxes are calculated by applying federal, state, and local income tax rates applicable to ordinary income to the amounts of the pre-tax reconciling items.

** Fiscal 2016 net economic earnings per share exclude the impact of the May 2016 equity issuance to fund a portion of the EnergySouth acquisition. The weighted average diluted shares used in the net economic earnings per share calculation for the three months ended June 30, 2016 was 43.5 million compared to 44.6 million in the GAAP diluted EPS calculation. Fiscal 2017 net economic earnings per share is calculated by replacing consolidated net income with consolidated net economic earnings in the GAAP diluted EPS calculation.

Consolidated

Spire’s net income was $21.7 for the three months ended June 30, 2017, compared with $10.7 for the three months ended June 30, 2016. Basic and diluted earnings per share for the three months ended June 30, 2017 were $0.45, compared with basic and diluted earnings per share of $0.24, for the three months ended June 30, 2016. Net income increased $11.0 due to the $5.1 increase in Utilities earnings combined with the $4.7 earnings increase in Gas Marketing and $1.2 lower expenses in Other. Spire’s net economic earnings were $21.6 ($0.44 per diluted share) for the three months ended June 30, 2017, an increase of $7.0 from the $14.6 ($0.33 per diluted share) reported for the same period last year. The increase in net economic earnings is primarily attributable to stronger results delivered by the Gas Utility segment, as described below. Net economic earnings per share reflects the 2,185,000 shares issued in May 2016 to help finance the EnergySouth acquisition and the 2,504,700 shares issued on April 3, 2017 resulting from the conversion of equity units issued in 2014.

Gas Utility

For the three months ended June 30, 2017, Gas Utility net income and net economic earnings increased $5.1 and $5.3, respectively, versus the prior-year quarter, primarily due to growth in net income at both Alagasco (up $3.4) and the Missouri Utilities (up $1.6). Alagasco’s net income increase was driven by a $6.7 increase in contribution margin, primarily the result of favorable regulatory adjustments, and was offset by higher depreciation expense and income taxes.

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Gas Marketing

The Gas Marketing segment reported net income totaling $3.7 for the three months ended June 30, 2017, versus a net loss of $1.0 in the prior-year quarter. Net economic earnings for the quarter increased $0.5 compared with the prior-year period. The primary driver of the increase in net income was favorable fair value mark-to-market adjustments, while both net income and net economic earnings benefited from increased value from spreads and asset optimization in the current year quarter versus the prior-year quarter.

Operating Revenues and Operating Expenses

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

		Gas Utility			Gas Marketing			Other			Eliminations			Consolidated
Three Months Ended June 30, 2017
	Operating Income (Loss)	$	47.1		$	5.9		$	(2.7	)	$	—		$	50.3
	Operation and maintenance expenses	101.9			1.5			4.5			(1.3		)	106.6
	Depreciation and amortization	38.4			0.1			0.1			—			38.6
	Taxes, other than income taxes	30.5			0.1			0.1			—			30.7
	Less: Gross receipts tax expense	(17.3		)	—			—			—			(17.3		)
	Contribution Margin (Non-GAAP)	200.6			7.6			2.0			(1.3		)	208.9
	Natural and propane gas costs	88.7			10.3			0.1			(1.8		)	97.3
	Gross receipts tax expense	17.3			—			—			—			17.3
	Operating Revenues	$	306.6		$	17.9		$	2.1		$	(3.1	)	$	323.5
Three Months Ended June 30, 2016
	Operating Income (Loss)	$	38.7		$	(1.6	)	$	(1.8	)	$	—		$	35.3
	Operation and maintenance expenses	91.9			1.1			2.6			(0.3		)	95.3
	Depreciation and amortization	34.2			0.1			0.1			—			34.4
	Taxes, other than income taxes	27.4			0.2			—			—			27.6
	Less: Gross receipts tax expense	(15.3		)	—			—			—			(15.3		)
	Contribution Margin (Non-GAAP)	176.9			(0.2		)	0.9			(0.3		)	177.3
	Natural and propane gas costs	61.1			2.5			—			(6.9		)	56.7
	Gross receipts tax expense	15.3			—			—			—			15.3
	Operating Revenues	$	253.3		$	2.3		$	0.9		$	(7.2	)	$	249.3

Consolidated

As shown in the table above, Spire reported an operating revenue increase 0f $74.2 for the three months ended June 30, 2017 compared with the same period last year, with increases in both Gas Utility and Gas Marketing.Spire’s contribution margin increased $31.6 compared with last year due to increases in the Gas Utility segment reflecting $12.6 from the EnergySouth acquisition and an increase of $6.7 from Alagasco and $4.4 from the Missouri Utilities. The Gas Marketing contribution margin increase of $7.8 stemmed from favorable fair value mark-to-market adjustments and higher storage optimization. Depreciation and amortization expenses were up in the Gas Utility segment, reflecting the EnergySouth acquisition and higher overall capital investments. Operation and maintenance (O&M) expenses in the quarter were $10.0 higher than the prior-year quarter, due to $7.8 in additional costs resulting from the EnergySouth acquisition and $2.8 higher expenses in the Missouri Utilities offsetting slightly lower costs at Alagasco. These fluctuations are described in more detail below.

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Gas Utility

Operating Revenues – Gas Utility operating revenues for the three months ended June 30, 2017 were $306.6, or $53.3 higher than the same period last year. The increase in Gas Utility operating revenues was attributable to the following factors:

EnergySouth acquisition	$	17.6
Missouri Utilities – Higher PGA gas cost recoveries	12.2
Alagasco – Higher GSA gas cost recoveries	11.2
Alagasco – Lower Rate Stabilization and Equalization (RSE) revenue reduction and higher Cost Control Mechanism (CCM) benefit	5.0
Missouri Utilities – Higher Infrastructure System Replacement Surcharge (ISRS)	4.0
Missouri Utilities – Off-system sales and capacity release	2.8
Missouri Utilities and Alagasco – Higher gross receipt taxes	1.6
Missouri Utilities and Alagasco – Weather / volumetric usage	(2.0		)
All other factors	0.9
Total Variation	$	53.3

As shown, the increase was primarily attributable to higher revenues reflecting the EnergySouth acquisition, higher gas cost recoveries of $23.4 between the Alagasco and Missouri Utilities, higher ISRS charges within the Missouri Utilities, and the adjustments under the Alabama RSE rate-setting mechanism.

Contribution Margin – Gas Utility contribution margin was $200.6 for the three months ended June 30, 2017, a $23.7 increase over the same period last year. The net increase was attributable to the following factors:

EnergySouth contribution margin	$	12.6
Alagasco – Lower RSE revenue adjustment and higher CCM benefit	5.0
Missouri Utilities – Higher ISRS	4.0
Missouri Utilities – Weather / volumetric usage	(1.7		)
Missouri Utilities – Customer growth	1.0
All other factors	2.8
Total Variation	$	23.7

As shown, the increase in contribution margin was primarily attributable to the margin contributed by the EnergySouth acquisition, the positive impacts of higher ISRS at the Missouri Utilities, and the favorable regulatory adjustments for Alagasco in the current quarter. These favorable impacts more than offset the effect of warmer weather. The Missouri Utilities experienced significantly milder weather this quarter with degree days 22% warmer than normal and 10% warmer than the prior year. In the Alagasco territory, weather was 30% warmer than normal this year, and 3% warmer than in the prior year.

Operating Expenses – Depreciation and amortization expenses for the three months ended June 30, 2017 increased $4.2 from last year, primarily due to $2.6 from the EnergySouth acquisition and higher levels of capital expenditures by the Missouri Utilities and Alagasco. O&M expenses for the three months ended June 30, 2017 were $10.0 higher than the same period in the prior year, largely due to the $7.8 attributable to the EnergySouth acquisition and a $2.8 increase at the Missouri Utilities more than offsetting the slight decline at Alagasco. The Missouri Utilities’ O&M expense increase was driven primarily by increased employee-related costs and higher professional services and fees.

Gas Marketing

Operating Revenues – Operating revenues increased $15.6 versus the prior-year period as a result of higher total volume and general pricing levels, along with the effect of changes in trading activities. Under GAAP, revenues associated with trading activities are presented net of related costs. Average pricing for the three months ended June 30, 2017 was approximately $2.927/MMBtu versus approximately $2.031/MMBtu for the quarter ended June 30, 2016.

Contribution Margin – Gas Marketing contribution margin during the three months ended June 30, 2017 increased $7.8 from the same period last year. The increase in contribution margin is primarily due to greater spreads and increased asset optimization in the current-year quarter versus the prior year.

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Interest Charges

Consolidated interest charges during the three months ended June 30, 2017 increased by $2.0 from the same period last year. The increase was primarily driven by the debt incurred and assumed as a result of the EnergySouth acquisition, combined with marginally higher interest rates on the senior notes issued in March of this year that were used to retire $250.0 of floating rate debt. For the three months ended June 30, 2017 and 2016, average short-term borrowings were $428.2 and $208.5, respectively, and the average interest rates on these borrowings were 1.3% and 0.9%, respectively.

Income Taxes

Consolidated income tax expense during the three months ended June 30, 2017 was $1.9 higher versus the prior-year quarter primarily as a result of higher pre-tax book income.

LACLEDE GAS

	Three Months Ended June 30,
	2017			2016
Operating Income	$	30.5		$	29.4
Operation and maintenance expenses	61.2			58.4
Depreciation and amortization	23.2			22.3
Taxes, other than income taxes	21.7			21.2
Less: Gross receipts tax expense	(12.4		)	(11.5		)
Contribution Margin (non-GAAP)	124.2			119.8
Natural and propane gas costs	61.9			48.0
Gross receipts tax expense	12.4			11.5
Operating Revenues	$	198.5		$	179.3
Net Income	$	15.5		$	13.9

Operating revenues for the three months ended June 30, 2017 increased $19.2 from the same period last year primarily due to $12.2 higher gas cost recoveries, a $4.0 increase in ISRS charges and $2.8 in higher off-system sales that was only partly offset by a $2.0 negative impact of warmer weather. Contribution margin for the three months ended June 30, 2017 increased $4.4 from the same period last year, largely due to the $4.0 increase in ISRS charges and the off-system sales impact, partly offset by a $1.7 impact of warmer than normal weather. O&M expenses for the three months ended June 30, 2017 increased $2.8, largely attributable to higher employee-related costs and higher professional services and fees. Depreciation and amortization increased $0.9 in the current quarter versus the prior-year quarter due to higher capital investments. Resulting net income for the three months ended June 30, 2017 increased $1.6 from the same period last year.

Temperatures in Laclede Gas’ service areas during the three months ended June 30, 2017 were 10% warmer than the same period last year, resulting in lower usage on a year-over-year comparative basis. Further, temperatures versus normal (the basis of Laclede Gas’ rate design) were 22% warmer, which continued to constrain margins. The Missouri Utilities’ total system therms sold and transported were 236.6 million for the three months ended June 30, 2017, compared with 237.3 million for the same period last year. Total off-system therms sold and transported were 14.4 million for the three months ended June 30, 2017, compared with 15.5 million for the same period last year.

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ALAGASCO

	Three Months Ended June 30,
	2017			2016
Operating Income	$	15.5		$	9.3
Operation and maintenance expenses	32.9			33.5
Depreciation and amortization	12.6			11.9
Taxes, other than income taxes	7.0			6.2
Less: Gross receipts tax expense	(4.2		)	(3.8		)
Contribution Margin (Non-GAAP)	63.8			57.1
Natural and propane gas costs	22.5			13.1
Gross receipts tax expense	4.2			3.8
Operating Revenues	$	90.5		$	74.0
Net Income	$	7.4		$	4.0

Operating revenues for the three months ended June 30, 2017 increased $16.5 from the same period last year. The change was principally driven by an $11.2 increase in gas cost recoveries and a higher net increase to revenue due to RSE and CCM adjustments in the current year versus the prior year. Contribution margin increased $6.7, primarily due to the net increase to revenue related to RSE and CCM adjustments of $5.0. Depreciation and amortization expenses for the three months ended June 30, 2017 were slightly higher than the same period last year. O&M expenses were $0.6 lower, primarily due to lower employee-related costs. Net income during the three months ended June 30, 2017 increased $3.4 from the same period last year, primarily due to the higher contribution margins, offset partly by higher income tax expense.

Temperatures in Alagasco’s service area during the three months ended June 30, 2017 were 3% warmer than a year ago, and 30% above normal. Alagasco’s total system therms sold and transported were 204.1 million for the three months ended June 30, 2017, compared with 191.3 million for the same period last year.

For further information on the GSA, CCM and RSE mechanisms, please see Note 1, Summary of Significant Accounting Policies, and Note 15, Regulatory Matters, of Alagasco’s Annual Report on Form 10-K for the year ended September 30, 2016.

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NINE MONTHS ENDED JUNE 30, 2017

SPIRE

Net Income and Net Economic Earnings

The following tables reconcile the Company’s net economic earnings to the most comparable GAAP number, net income.

		Gas Utility			Gas Marketing			Other			Total			Per Diluted Share**
Nine Months Ended June 30, 2017
	Net Income (Loss) (GAAP)	$	187.0		$	1.9		$	(14.0	)	$	174.9		$	3.75
	Adjustments, pre-tax:
	Unrealized loss on energy-related derivatives	0.1			3.1			—			3.2			0.07
	Realized gain on economic hedges prior      to the sale of the physical commodity	—			(0.2		)	—			(0.2		)	—
	Acquisition, divestiture and restructuring activities	0.3			—			1.8			2.1			0.04
	Income tax effect of adjustments*	(0.1		)	(1.1		)	(0.7		)	(1.9		)	(0.04		)
	Net Economic Earnings (Loss) (Non-GAAP)	$	187.3		$	3.7		$	(12.9	)	$	178.1		$	3.82
Nine Months Ended June 30, 2016
	Net Income (Loss) (GAAP)	$	169.6		$	2.8		$	(14.0	)	$	158.4		$	3.60
	Adjustments, pre-tax:
	Unrealized (gain) loss on energy-related derivatives	(0.1		)	3.0			—			2.9			0.07
	Lower of cost or market inventory adjustments	—			0.6			—			0.6			0.01
	Realized gain on economic hedges prior      to the sale of the physical commodity	—			(0.9		)	—			(0.9		)	(0.02		)
	Acquisition, divestiture and restructuring activities	1.6			—			3.5			5.1			0.12
	Income tax effect of adjustments*	(0.6		)	(1.0		)	(1.3		)	(2.9		)	(0.07		)
	Weighted average shares adjustment	—			—			—			—			0.03
	Net Economic Earnings (Loss) (Non-GAAP)	$	170.5		$	4.5		$	(11.8	)	$	163.2		$	3.74

* Income taxes are calculated by applying applicable federal, state, and local income tax rates applicable to ordinary income to the amounts of the pre-tax reconciling items.

** Fiscal 2016 net economic earnings per share exclude the impact of the May 2016 equity issuance to fund a portion of the EnergySouth acquisition. The weighted average diluted shares used in the net economic earnings per share calculation for the nine months ended June 30, 2016 was 43.5 million compared to 43.8 million in the GAAP diluted EPS calculation. Fiscal 2017 net economic earnings per share is calculated by replacing consolidated net income with consolidated net economic earnings in the GAAP diluted EPS calculation.

Consolidated

Spire’s net income was $174.9 for the nine months ended June 30, 2017, compared with $158.4 for the nine months ended June 30, 2016. Basic and diluted earnings per share for the nine months ended June 30, 2017 were $3.76 and $3.75, respectively, compared with basic and diluted earnings per share of $3.62 and $3.60, respectively, for the nine months ended June 30, 2016. Net income increased $16.5, driven by $17.4 higher income in the Gas Utility segment more than offsetting the decline of $0.9 experienced by Gas Marketing. Net economic earnings were $178.1 ($3.82 per diluted share) for the nine months ended June 30, 2017, up from $163.2 ($3.74 per diluted share) for the same period last year, as improvements for Gas Utility more than offset the $0.8 net economic earnings decline experienced by Gas Marketing. These fluctuations are described in more detail below.

Gas Utility

Gas Utility net income and net economic earnings increased by $17.4 and $16.8, respectively, for the nine months ended June 30, 2017, compared with the nine months ended June 30, 2016. As discussed in more detail below, improvements in both measures were primarily due to the inclusion of EnergySouth results in the current year, improvements in results at the Missouri Utilities and Alagasco, offset by milder weather.

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Gas Marketing

The Gas Marketing segment reported net income totaling $1.9 for the nine months ended June 30, 2017, versus net income of $2.8 during the same period last year due to lower storage optimization and price volatility in the current year, primarily the result of an extremely warm winter. Net economic earnings for the nine months ended June 30, 2017 were $3.7, a decrease of $0.8 from the same period last year due to the timing of storage optimization.

Operating Revenues and Operating Expenses

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

		Gas Utility			Gas Marketing			Other			Eliminations			Consolidated
Nine Months Ended June 30, 2017
	Operating Income (Loss)	$	320.3		$	2.9		$	(3.4	)	$	—		$	319.8
	Operation and maintenance expenses	301.7			4.4			8.4			(3.9		)	310.6
	Depreciation and amortization	114.0			0.1			0.3			—			114.4
	Taxes, other than income taxes	112.2			0.3			0.2			—			112.7
	Less: Gross receipts tax expense	(70.4		)	(0.1		)	—			—			(70.5		)
	Contribution Margin (Non-GAAP)	777.8			7.6			5.5			(3.9		)	787.0
	Natural and propane gas costs	578.8			54.1			0.2			(8.6		)	624.5
	Gross receipts tax expense	70.4			0.1			—			—			70.5
	Operating Revenues	$	1,427.0		$	61.8		$	5.7		$	(12.5	)	$	1,482.0
Nine Months Ended June 30, 2016
	Operating Income (Loss)	$	290.1		$	4.7		$	(4.8	)	$	—		$	290.0
	Operation and maintenance expenses	278.4			4.1			7.1			(0.9		)	288.7
	Depreciation and amortization	101.5			0.1			0.4			—			102.0
	Taxes, other than income taxes	99.5			0.3			(0.1		)	—			99.7
	Less: Gross receipts tax expense	(65.0		)	(0.1		)	—			—			(65.1		)
	Contribution Margin (Non-GAAP)	704.5			9.1			2.6			(0.9		)	715.3
	Natural and propane gas costs	496.0			13.9			—			(32.3		)	477.6
	Gross receipts tax expense	65.0			0.1			—			—			65.1
	Operating Revenues	$	1,265.5		$	23.1		$	2.6		$	(33.2	)	$	1,258.0

Consolidated

As shown in the table above, Spire’s operating revenues for the nine months ended June 30, 2017 increased at both Gas Utility and Gas Marketing. The Gas Utility increase was due principally to the current year revenues relating to the EnergySouth acquisition and higher revenues at the Missouri Utilities and Alagasco. The Gas Marketing increase was due to the impact of higher prices and volumes. Spire’s contribution margin increased $71.7 compared with the same nine-month period last year due primarily to Gas Utility growth attributable to the EnergySouth acquisition ($59.5), the Missouri Utilities (up $10.6) and Alagasco (up $3.2), partially offset by a $1.5 decrease from Gas Marketing. Depreciation and amortization expenses were higher in the Gas Utility segment, due to the EnergySouth acquisition and higher capital investments in both the Missouri Utilities and Alagasco. O&M expenses increased, primarily due to the expenses associated with the EnergySouth acquisition. These fluctuations are described in more detail below.

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Gas Utility

Operating Revenues – Gas Utility operating revenues for the nine months ended June 30, 2017 were $1,427.0, or $161.5 higher than the same period last year. The increase in Gas Utility operating revenues was attributable to the following factors:

EnergySouth acquisition	$	81.7
Missouri Utilities – Higher PGA gas cost recoveries	40.6
Alagasco – Higher GSA gas cost recoveries	30.2
Missouri Utilities – Off-system sales, capacity release	17.4
Missouri Utilities – Higher ISRS	10.8
Alagasco – Lower RSE revenue reduction and higher CCM benefit	10.8
Missouri Utilities and Alagasco – Higher gross receipt taxes	3.1
Missouri Utilities and Alagasco – Weather / volumetric usage	(33.0		)
All other factors	(0.1		)
Total Variation	$	161.5

As shown, the increase was primarily attributable to the EnergySouth acquisition, higher PGA and GSA gas cost recoveries, higher ISRS charges within the Missouri Utilities, and favorable regulatory adjustments at Alagasco. These favorable revenue drivers were offset partly by the impact of warmer weather.

Contribution Margin – Gas Utility contribution margin was $777.8 for the nine months ended June 30, 2017, a $73.3 increase over the same period last year. The increase was attributable to the following factors:

EnergySouth acquisition	$	59.5
Missouri Utilities – Higher ISRS	10.8
Alagasco – Lower RSE revenue reduction and higher CCM benefit	10.8
Missouri Utilities – Higher off-system sales	1.1
Missouri Utilities and Alagasco – Weather / volumetric usage	(10.3		)
All other factors	1.4
Total Variation	$	73.3

The negative contribution impact that resulted from the warmer weather in the current year was mitigated by the inclusion of EnergySouth results in the current year, favorable impacts from the Missouri Utilities’ ISRS charges, and Alagasco’s favorable RSE and CCM adjustments.

Operating Expenses – Depreciation and amortization expenses for the nine months ended June 30, 2017 increased $12.5 from the same period last year, with $7.9 attributable to the EnergySouth acquisition and the remainder due to higher levels of capital investment over the past year at both the Missouri Utilities and Alagasco. O&M expenses for the nine months ended June 30, 2017 increased $23.3 from last year, as the inclusion of $26.9 of EnergySouth expenses and a slight $0.5 increase at the Missouri Utilities offset $4.1 lower O&M expenses at Alagasco. The constrained expense growth at the Missouri Utilities and expense reductions at Alagasco were partially attributable to the warmer weather, with lower employee-related expenses at both the Missouri and Alabama Utilities in the current year only being partly offset by higher property tax expense at the Missouri Utilities.

Gas Marketing

Operating Revenues – Gas Marketing operating revenues during the nine months ended June 30, 2017 increased $38.7 from the same period last year, principally due to higher total volume and general pricing levels, along with the effect of changes in trading activities. Overall commodity pricing in the current year was $0.836/MMBtu higher than the prior year.

Contribution Margin – Gas Marketing contribution margin during the nine months ended June 30, 2017 decreased $1.5 from the same period last year. The decrease is primarily due to lower storage optimization. These negative impacts were only partially offset by the favorable impact of higher overall volumes and increased asset optimization.

Interest Charges

Consolidated interest charges during the nine months ended June 30, 2017 were $8.5 higher than the same period last year. The increase was primarily driven by debt incurred and assumed as a result of the EnergySouth

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acquisition, combined with marginally higher interest rates on floating rate debt in the first six months of the year and higher interest rates on the senior notes issued in March of this year that were used to retire the $250.0 of floating rate debt. Also, for the nine months ended June 30, 2017 and 2016, average short-term borrowings were $477.6 and $297.9, respectively, and the average interest rates on these borrowings were 1.2% and 0.9%, respectively.

Income Taxes

Consolidated income tax expense during the nine months ended June 30, 2017 increased $6.6 from the same period last year primarily as a result of higher pre-tax book income. The effective tax rate for the current year of 32.5% is slightly less than the 32.9% rate for the prior year.

LACLEDE GAS

	Nine Months Ended June 30,
	2017			2016
Operating Income	$	185.2		$	181.5
Operation and maintenance expenses	179.2			178.7
Depreciation and amortization	68.9			66.0
Taxes, other than income taxes	81.6			76.4
Less: Gross receipts tax expense	(51.4		)	(49.7		)
Contribution Margin (Non-GAAP)	463.5			452.9
Natural and propane gas costs	494.4			440.6
Gross receipts tax expense	51.4			49.7
Operating Revenues	$	1,009.3		$	943.2
Net Income	$	110.5		$	107.6

Operating revenues during the nine months ended June 30, 2017 increased $66.1 from the same period last year primarily due to $40.6 higher wholesale gas costs passed on to customers, off-system sales of $17.4, ISRS charge increases of $10.8, offset primarily by the $5.0 decrease related to the current year’s warmer weather. Contribution margin increased $10.6 primarily due to the $10.8 higher ISRS charges being slightly offset by the negative weather impact. O&M expenses during the nine months ended June 30, 2017 increased $0.5 from the same period last year, and depreciation increased by $2.9 due to continuing increases in the levels of capital investment. The increase in O&M expenses was driven by bad debts and higher property taxes, partly offset by lower employee-related costs. Net income increased $2.9, primarily due to the factors discussed above.

Temperatures in Laclede Gas’ service areas during the nine months ended June 30, 2017 were 1% lower than the same period last year, and 20% warmer than normal. The Missouri Utilities’ total system therms sold and transported were 1,488.2 million for the nine months ended June 30, 2017 compared with 1,490.4 million for the same period last year, including a 6.1 million decrease in off-system sales. Total off-system therms sold and transported were 173.9 million for the nine months ended June 30, 2017, compared with 180.0 million for the same period last year.

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ALAGASCO

	Nine Months Ended June 30,
	2017			2016
Operating Income	$	114.2		$	108.6
Operation and maintenance expenses	95.6			99.7
Depreciation and amortization	37.2			35.5
Taxes, other than income taxes	23.9			23.1
Less: Gross receipts tax expense	(16.1		)	(15.3		)
Contribution Margin (Non-GAAP)	254.8			251.6
Natural and propane gas costs	65.1			55.4
Gross receipts tax expense	16.1			15.3
Operating Revenues	$	336.0		$	322.3
Net Income	$	65.3		$	62.0

Operating revenues for the nine months ended June 30, 2017 increased $13.7 from the same period last year. The primary drivers were $30.2 in higher GSA gas cost recoveries and a $10.8 benefit to revenue due to RSE and CCM adjustments in the current year, offset by a $28.0 impact due to weather and lower base rates for revenue and margin. Contribution margin increased $3.2 versus the prior period, primarily the result of the $10.8 beneficial RSE adjustments offsetting the $7.6 reduction resulting from the warmer weather and lower base rates for margin, and gas cost recovery. O&M expenses for the nine months ended June 30, 2017 decreased $4.1 from the same period last year primarily driven by decreases in employee-related expenses. Net income for the nine months ended June 30, 2017 was $3.3 higher than the same period last year due to the higher contribution margin and lower O&M expenses, offset partly by higher income taxes.

Temperatures in Alagasco’s service area during the nine months ended June 30, 2017 were 15% warmer than the same period last year and 35% warmer than normal. Alagasco’s total system therms sold and transported were 704.3 million for the nine months ended June 30, 2017, compared with 673.7 million for the same period last year.

For further information on the GSA, CCM and RSE mechanisms, please see Note 1, Summary of Significant Accounting Policies, and Note 3, Regulatory Matters, of Alagasco’s Annual Report on Form 10-K for the year ended September 30, 2016.

REGULATORY AND OTHER MATTERS

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

Laclede Gas

On May 19, 2016, the MoPSC approved an incremental ISRS amount of $5.4 for Laclede Gas’ eastern Missouri service territory and $3.6 for MGE, effective May 31, 2016. On June 30, 2016, the Missouri Office of the Public Counsel (OPC) filed an appeal to Missouri’s Western District Court of Appeals of the MoPSC’s decision permitting Laclede Gas to update its ISRS applications during the pendency of the case. On March 28, 2017, the Court affirmed the MoPSC’s decision approving Laclede Gas’ ISRS update process. On June 27, 2017, the Missouri Supreme Court declined to hear the case, bringing the appeal to conclusion.

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On September 30, 2016, Laclede Gas filed to increase its ISRS revenues, by $5.0 for Laclede Gas’ eastern Missouri service territory and $3.4 for MGE, related to ISRS investments from March 2016 through October 2016. On November 29, 2016, MoPSC staff recommended $4.5 for Laclede Gas’ eastern Missouri service territory and $3.4 for MGE based on updates filed by the company. On January 3, 2017, the MoPSC held a hearing to decide two issues raised by the OPC pertaining to the ISRS eligibility of hydrostatic testing done by MGE and the replacement of plastic interspersed with the cast iron. On January 18, 2017, the MoPSC found in favor of the Missouri Utilities on the interspersed plastics issue, but against MGE on hydrostatic testing, and issued an order setting the ISRS increases at $4.5 and $3.2, respectively, bringing total annualized ISRS revenue to $29.5 for Laclede Gas’ eastern Missouri service territory and $13.4 for MGE’s service territory. Rates were effective January 28, 2017. On March 3, 2017, the OPC filed an appeal to Missouri’s Western District Court of Appeals of the MoPSC’s decision permitting Laclede Gas to include the replacement of interspersed plastic pipe in its ISRS.

On February 3, 2017, Laclede Gas filed to increase its ISRS revenues, by $3.3 for Laclede Gas’ eastern Missouri service territory and $2.9 for MGE, related to ISRS investments from November 2016 through February 2017. Following the submission of updated information, on April 4, 2017 MoPSC staff submitted its recommendation for an increase in rates of $3.1 for Laclede Gas’ eastern Missouri service territory and $3.0 for MGE, for a cumulative of $32.6 and $16.4, respectively. On that same date, the OPC again raised an objection to the ISRS eligibility of replacing plastic portions of main interspersed within cast iron main. On April 18, 2017, the parties filed with the MoPSC a unanimous stipulation and agreement proposing to apply the judicial outcome of the OPC’s March 3, 2017 appeal on the plastics issue to both the ISRS cases on appeal and the current ISRS cases. The agreement was approved by the MoPSC on April 26, 2017. ISRS rates for each of the two service territories were increased by the MoPSC staff-recommended amounts, effective June 1, 2017.

On April 15, 2015, Laclede Gas applied to the MoPSC for a new authorization of long-term financing in the amount of $550.0. On February 10, 2016, the MoPSC issued an order, by a 3-2 vote, authorizing Laclede Gas financing authority of $300.0 for long-term financings placed any time before September 30, 2018. Laclede Gas filed an application for rehearing, which was denied on March 9, 2016. On March 31, 2016, Laclede Gas filed an appeal with Missouri’s Western District Court of Appeals concerning this matter. The parties filed briefs and oral arguments were heard on November 17, 2016. On May 30, 2017, Missouri’s Western District Court of Appeals issued a decision upholding the MoPSC’s February 10, 2016 Order granting Laclede Gas $300.0 million. On July 5, 2017, the Court denied Laclede Gas’ request to transfer the case to the Missouri Supreme Court. Laclede Gas’ appeal directly to the Missouri Supreme Court is pending. Laclede Gas has not yet issued securities under this authorization, but on March 20, 2017, Laclede Gas entered into a bond purchase agreement for $170.0 that will be funded prior to September 15, 2017, and applied against the $300.0 authorization.

On April 11, 2017, both Laclede Gas’ eastern and western Missouri service territories filed for a general rate case, and did so concurrently as agreed to in GM-2013-0254, as part of the acquisition of MGE by Laclede Gas. The request for Laclede Gas’ eastern Missouri territory represents a net rate increase of $25.5. With the $32.6 already being billed in ISRS, the total base rate increase request was $58.1. For the western Missouri territory, MGE’s request represents a net rate increase of $34.0. With the $16.4 already being billed in ISRS, the total base rate increase request was $50.4. The rates were premised upon a 10.35% ROE and the details of the filing can be found in GR-2017-0215 for the eastern Missouri territory, and GR-2017-0216 for the western Missouri territory. An evidentiary hearing has been set for December 4 through 15, 2017, with a MoPSC decision expected by February 2018. Missouri statutes require new rates to be effective within 11 months of the filing, or by March 11, 2018.

Alagasco

Alagasco is subject to regulation by the APSC which established the Rate Stabilization and Equalization (RSE) rate-setting process in 1983. Alagasco’s current RSE order has a term extending beyond September 30, 2018, unless the APSC enters an order to the contrary in a manner consistent with law. In the event of unforeseen circumstances, whether physical or economic, of the nature of force majeure and including a change in control, the APSC and Alagasco will consult in good faith with respect to modifications, if any. Effective January 1, 2014, Alagasco’s allowed range of return on average common equity is 10.5% to 10.95% with an adjusting point of 10.8%. Alagasco is eligible to receive a performance-based adjustment of 5 basis points to the return on equity adjusting point, based on meeting certain customer satisfaction criteria. Under RSE, the APSC conducts quarterly reviews to determine whether Alagasco’s return on average common equity at the end of the rate year will be within the allowed range of return. Reductions in rates can be made quarterly to bring the projected return within the allowed range; increases, however, are allowed only once each rate year, effective December 1, and cannot exceed 4% of prior-year revenues. The RSE reduction for the July 31, 2016 quarterly point of test was $4.8 and went into effect October 1, 2016, and for the quarterly point of test at September 30, 2016, Alagasco recorded a $2.7 RSE reduction effective December 1, 2016. As part of the annual update for RSE, on November 30, 2016, Alagasco filed a reduction for rate year 2017 of

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$2.5 that also became effective December 1, 2016. There was no RSE reduction for the January 31, 2017 and April 30, 2017 points of test. As of June 30, 2017, Alagasco recorded an estimated $1.5 RSE reduction to operating revenues to bring the expected rate of return on average common equity at the end of the year to within the allowed range of return.

The inflation-based Cost Control Mechanism (CCM), established by the APSC, allows for annual increases to O&M expense, with savings below a defined level shared 50/50 with the customer and three-quarters of costs above a defined level returned to customers (see the 2016 Form 10-K for more detail). For GAAP purposes, as of June 30, 2017, Alagasco had accrued an estimated CCM benefit of $7.7 for nine months of Rate Year 2017.

On June 28, 2010, the APSC approved a reduction in depreciation rates, effective June 1, 2010, and a regulatory liability recorded for Alagasco. Refunds from such negative salvage liability will be passed back to eligible customers on a declining basis through lower tariff rates through rate year 2019 pursuant to the terms of the Negative Salvage Rebalancing (NSR) rider (see the 2016 Form 10-K for more detail). For the period December 1, 2016 through June 30, 2017, $6.3 of the customer refund has been returned to customers. As of June 30, 2017, $12.3 is remaining to be refunded to customers.

Spire

In addition to the matters described above, the following regulatory matters affect Spire.

On July 22, 2016, the proposed project of Spire STL Pipeline LLC, a wholly owned subsidiary of Spire, was accepted into the pre-filing process at the FERC. The proposal outlined the plan to build, own, operate, and maintain a pipeline interconnecting with the Rockies Express pipeline to deliver natural gas to the St. Louis, Missouri area. As an interstate project, the Spire STL Pipeline will be reviewed for siting and permitting by the FERC, which will be the lead agency for other federal, state, and local permitting authorities. A precedent agreement between Spire STL Pipeline and Laclede Gas was executed on January 25, 2017. On January 26, 2017, Spire STL Pipeline filed an application with the FERC requesting issuance of a certificate of convenience and necessity authorizing it to construct, own, and operate an interstate pipeline. Several parties have filed interventions and comments regarding the Spire STL Pipeline project. The company is monitoring these closely and has responded where appropriate.

On April 21, 2017, Spire STL Pipeline filed an amended certificate application to adjust the preferred route to include a new six-mile segment rather than an existing line. The change would offer a number of benefits including eliminating potential supply disruption risk for Laclede Gas during construction, eliminating uncertainty regarding upgrade costs, and reducing long-term integrity management costs.

CRITICAL ACCOUNTING ESTIMATES

Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources are based upon our financial statements, which have been prepared in accordance with GAAP. GAAP requires that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates. Our critical accounting estimates used in the preparation of our financial statements are described in Item 7 of the Company’s, Laclede Gas’, and Alagasco’s Annual Reports on Form 10-K for the fiscal year ended September 30, 2016 and include regulatory accounting, goodwill, and employee benefits and postretirement obligations. There were no significant changes to these critical accounting estimates during the nine months ended June 30, 2017.

For discussion of other significant accounting policies, see Note 1 of the Notes to Financial Statements included in this Form 10-Q as well as Note 1 of the Notes to Financial Statements included in the Company’s, Laclede Gas’, and Alagasco’s Annual Reports on Form 10-K for the fiscal year ended September 30, 2016.

ACCOUNTING PRONOUNCEMENTS

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

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FINANCIAL CONDITION

Cash Flows

Spire

The Company’s short-term borrowing requirements typically peak during colder months when the Utilities borrow money to cover the lag between when they purchase natural gas and when their customers pay for that gas. Changes in the wholesale cost of natural gas (including cash payments for margin deposits associated with Laclede Gas’ use of natural gas derivative instruments), variations in the timing of collections of gas cost under the Utilities’ PGA clauses and GSA riders, the seasonality of accounts receivable balances, and the utilization of storage gas inventories cause short-term cash requirements to vary during the year and from year to year, and may cause significant variations in the Company’s cash provided by or used in operating activities.

	Nine Months Ended   June 30,
Cash Flow Summary	2017			2016
Net cash provided by operating activities	$	320.7		$	356.9
Net cash used in investing activities	(293.7		)	(196.8		)
Net cash used in financing activities	(23.9		)	(169.0		)

For the nine months ended June 30, 2017, net cash provided by operating activities declined $36.2 from the corresponding period of fiscal 2016. The change is primarily due to fluctuations in working capital, as mentioned above, largely driven by the relative weather conditions and gas prices during the periods. Cash was provided primarily by increases in net income, depreciation, accounts payable and insurance recoveries. These benefits were more than offset by net increases in advance customer billings and accounts receivable and a smaller decrease in inventory levels compared to the prior year.

For the nine months ended June 30, 2017, net cash used in investing activities was $96.9 more than for the same period in the prior year, driven by a $103.3 increase in capital expenditures. The higher spending to this point in the fiscal year is consistent with the Company’s capital expenditure expectations, and reflects the continued focus on infrastructure upgrades and the addition of EnergySouth. Total capital expenditures for the full fiscal year 2017 are expected to be approximately $445, with approximately $420 in the Utilities.

Lastly, for the nine months ended June 30, 2017, net cash used in financing activities was $145.1 lower than for the nine months ended June 30, 2016. This change primarily reflects the effect of a $91.8 net repayment of short-term and long-term debt this year compared with a $240.4 net repayment last year. Stock issuances in fiscal 2017, which included the conversion of equity units issued in 2014, provided $10.3 more cash than last year, which included the offering to help fund the EnergySouth acquisition. These net cash inflows were partially offset by higher dividend payments and other financing activities this year.

LIQUIDITY AND CAPITAL RESOURCES

Cash and Cash Equivalents

None of Spire, Laclede Gas, or Alagasco had any short-term investments as of or for the nine months ended June 30, 2017.

Bank deposits were used to support working capital needs of the business.

Short-term Debt

The Utilities’ short-term borrowing requirements typically peak during the colder months, while the Company’s needs are less seasonal. 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 December 14, 2016, Spire, Laclede Gas, and Alagasco entered into a new syndicated revolving credit facility pursuant to a loan agreement with 11 banks, expiring December 14, 2021. The largest portion provided by a single bank under the line is 12.3%. The loan agreement replaces Spire’s and Laclede Gas’ existing loan agreements dated as of September 3, 2013 and amended September 3, 2014, which were set to expire on September 3, 2019, and Alagasco’s existing loan agreement dated September 2, 2014, which was set to expire September 2, 2019. All three agreements were terminated on December 14, 2016.

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The loan agreement has an aggregate credit commitment of $975.0, including sublimits of $300.0 for Spire, $475.0 for Laclede Gas, and $200.0 for Alagasco. These sublimits may be reallocated from time to time among the three borrowers within the $975.0 aggregate commitment. Spire may use its line to provide for the funding needs of various subsidiaries. Spire, Laclede Gas, and Alagasco expect to use the loan agreement for general corporate purposes, including short-term borrowings and letters of credit. The agreement also contains financial covenants limiting each borrower’s consolidated total debt, including short-term debt, to no more than 70% of its total capitalization. As defined in the line of credit, on June 30, 2017, total debt was 54% of total capitalization for the consolidated Company, 48% for Laclede Gas, and 29% for Alagasco.

On December 21, 2016, Spire established a commercial paper program (Program) pursuant to which Spire may issue short-term, unsecured commercial paper notes (Notes). Amounts available under the Program may be borrowed, repaid, and re-borrowed from time to time, with the aggregate face or principal amount of the Notes outstanding under the Program at any time not to exceed $975.0. The Notes may have maturities of up to 365 days from date of issue. The net proceeds of the issuances of the Notes are expected to be used for general corporate purposes, including to provide working capital for both utility and non-utility subsidiaries. As of June 30, 2017, Notes outstanding under the Program totaled $450.7.

Information regarding Spire’s consolidated short-term borrowings is presented below. Based on weighted average short-term borrowings outstanding, a 100-basis-point increase in the weighted average interest rate would decrease pre-tax earnings and cash flows by approximately $4.8 on an annual basis, a portion of which may be offset through the Utilities’ application of PGA and GSA carrying costs.

	Spire Short-term Borrowings1	Laclede Gas Commercial Paper Borrowings2	Alagasco Bank Line Borrowings	Total Short-term Borrowings
Nine Months Ended June 30, 2017
Weighted average borrowings outstanding	$321.5	$118.3	$37.8	$477.6
Weighted average interest rate	1.3%	0.9%	1.6%	1.2%
Range of borrowings outstanding	$73.0 - $675.6	$0.0 - $329.7	$0.0 - $102.5	$395.5 - $675.6
As of June 30, 2017
Borrowings outstanding	$450.7	$—	$—	$450.7
Weighted average interest rate	1.5%	—%	—%	1.5%

¹  Spire Short-term Borrowings includes bank line borrowings and, since January 1, 2017, commercial paper. Of Spire’s $450.7 borrowings outstanding as of June 30, 2017, $423.0 was lent to its subsidiaries, including Laclede Gas ($260.2), Alagasco ($114.9), EnergySouth and subsidiaries ($6.6), Spire STL Pipeline LLC ($9.4), and others ($31.9).

²  The commercial paper program for Laclede Gas terminated February 2, 2017.

Long-term Debt and Equity

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

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

Spire

At June 30, 2017, including the current portion but excluding unamortized discounts, debt issuance costs, and net hedging gains, Spire had fixed-rate long-term debt totaling $1,942.0, of which $810.0 was issued by Laclede Gas and $250.0 was issued by Alagasco. The long-term debt issues are fixed-rate and are subject to changes in their fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if the Company were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to the Utilities’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period. Of the Company’s $1,942.0 senior long-term debt, $25.0 has no call options, $1,037.0 has make-whole call options, $875.0 is callable at par one to six months prior to maturity and $5.0 is callable at par currently. None of the debt has any put options.

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On March 10, 2017, Spire redeemed in full at par its $250.0 floating rate notes due August 15, 2017, plus accrued and unpaid interest.

On March 15, 2017, Spire completed the issuance and sale of $100.0 in aggregate principal amount of Senior Notes due March 15, 2027. The notes bear interest at the rate of 3.93% per annum, payable semi-annually. The notes are senior unsecured obligations of the Company. The Company used the proceeds from the sale of the notes for the repayment of other debt.

In 2014, Spire issued 2.875 million equity units as a portion of the Alagasco acquisition financing. The equity units were originally issued at $50 per unit pursuant to the Purchase Contract and Pledge Agreement (purchase contract) dated as of June 11, 2014 between Spire and U.S. Bank National Association, as purchase contract agent, collateral agent, custodial agent and securities intermediary. These units consisted of $143.8 aggregate principal amount of 2014 Series A 2.00% remarketable junior subordinated notes due 2022 (the Junior Notes) and the purchase contract obligating the holder to purchase common shares at a future settlement date (anticipated to be three years in the future and prior to the Junior Notes maturity). The equity unit investments were effectively replaced as planned in a series of transactions outlined below:

– On February 22, 2017, the selling securityholders (as defined below) agreed to purchase the Junior Notes in connection with the remarketing of the junior subordinated notes that comprised a component of the equity units.

– On the same day, Spire entered into two related agreements: (1) a Securities Purchase and Registration Rights Agreement (the SPRRA), among Spire and the several purchasers named therein (the selling securityholders), obligating the selling securityholders to sell the Junior Notes to Spire in exchange for $143.8 aggregate principal amount of Spire’s 3.543% Senior Notes due 2024 (the Senior Notes) and a cash payment, and (2) an underwriting agreement with the selling securityholders and the several underwriters named therein in connection with the public offering of $150.0 aggregate principal amount of Senior Notes consisting of $6.2 principal amount of the Senior Notes issued and sold by Spire and $143.8 principal amount of the Senior Notes sold by the selling securityholders. The SPRRA granted the selling securityholders the right to offer the Senior Notes to the public in secondary public offerings.

– The public offering was completed on February 27, 2017. Spire used its net proceeds from its sale of the Senior Notes to repay short-term debt. Spire did not receive any proceeds from the sale of the Senior Notes by the selling securityholders.

– On April 3, 2017, Spire settled the purchase contracts underlying its 2.875 million equity units by issuing up to 2,504,700 shares of its common stock at a purchase price of $57.3921 per share. Fractional shares were settled in cash at $67.50 per share. The purchase price was funded with the proceeds from the Junior Notes. Under the contract terms, the equity units were converted to common stock at the rate of 0.8712, with a corresponding adjustment to purchase price. Spire received net cash proceeds of approximately $142.0, which it used to repay short-term debt incurred the previous month to redeem the floating rate notes.

On March 20, 2017, Laclede Gas entered into a bond purchase agreement, described more fully under Laclede Gas below, pursuant to which Laclede Gas has committed to issue in a private placement a total of $170.0 of its first mortgage bonds in 15-, 30- and 40-year tranches. The bonds will close on a date of Laclede Gas’ choosing, no later than September 15, 2017. The interest rates on the bonds are dependent on the exact closing date, as described below.

Spire filed a shelf registration statement on Form S-3 with the SEC on June 15, 2017 for the issuance and sale of up to 250,000 shares of its common stock under its Dividend Reinvestment and Direct Stock Purchase Plan. There were 249,836 and 245,346 shares at June 30, 2017 and July 31, 2017, respectively, remaining available for issuance under this Form S-3. Spire also has a shelf registration statement on Form S-3 on file with the SEC for the issuance of equity and debt securities, which expires September 23, 2019. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions.

Consolidated capitalization at June 30, 2017 consisted of 51.3% of Spire common stock equity and 48.7% of long-term debt, compared to 49.3% of Spire common stock equity and 50.7% of long-term debt at September 30, 2016.

Laclede Gas

Of Laclede Gas’ long-term debt (totaling $810.0 principal amount), $25.0 has no call option, $435.0 has make-whole call options, and $350.0 is callable at par one to six months prior to maturity.

On March 20, 2017, Laclede Gas entered into a bond purchase agreement among Laclede Gas and certain institutional purchasers (Bond Purchasers) pursuant to which Laclede Gas has committed to issue in a private

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placement a total of $170.0 of its first mortgage bonds: (i) $50.0 due September 15, 2032 (2032 Bonds), (ii) $70.0 due September 15, 2047 (2047 Bonds) and (iii) $50.0 due September 15, 2057 (2057 Bonds and, together with the 2032 Bonds and 2047 Bonds, the Bonds). Laclede Gas will give the Bond Purchasers at least five (5) business days’ prior written notice of a closing date, which shall occur no later than September 15, 2017. Depending on the closing date, the 2032 Bonds will bear interest at a rate of 3.65% or 3.68% per annum, the 2047 Bonds at a rate of 4.21% or 4.23% per annum and the 2057 Bonds at a rate of 4.36% or 4.38% per annum. The interest on the Bonds is payable semi-annually. Laclede Gas will use the proceeds from the sale of the Bonds to refinance existing indebtedness and for other general corporate purposes.

Laclede Gas has authority from the MoPSC to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock, receive paid-in capital, and enter into capital lease agreements, all for a total of up to $300.0. This authority became effective March 11, 2016, and will expire September 30, 2018. After the settlement of the $170.0 in Bonds discussed above, Laclede Gas will have $130.0 of this authorization remaining.

Laclede Gas filed a shelf registration on Form S-3 with the SEC on September 23, 2016, for issuance of first mortgage bonds, unsecured debt, and preferred stock, which expires on September 23, 2019. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions, as well as future MoPSC authorizations.

Laclede Gas capitalization at June 30, 2017 consisted of 59.2% of common stock equity and 40.8% of long-term debt compared to 57.1% of common stock equity and 42.9% of long-term debt at September 30, 2016.

Alagasco

All of Alagasco’s long-term debt ($250.0 principal amount) has make-whole call options.

Alagasco’s capitalization at June 30, 2017 consisted of 78.1% of common stock equity and 21.9% of long-term debt compared to 77.8% of common stock equity and 22.2% of long-term debt at September 30, 2016.

CONTRACTUAL OBLIGATIONS

During the nine months ended June 30, 2017, there were no material changes outside the ordinary course of business to the estimated contractual obligations from the disclosure provided in the Company’s Form 10-K for the fiscal year ended September 30, 2016.

MARKET RISK

There were no material changes in the Company’s commodity price risk or counterparty credit risk as of June 30, 2017 relative to the corresponding information provided as of September 30, 2016 in the Company’s Annual Report on Form 10-K. Information on concentrations of credit risk, including how Spire Marketing manages these risks, is included in Note 7, Concentrations of Credit Risk, of the Notes to Financial Statements under Item 1.

During the second quarter of fiscal 2016, Spire entered into five-year interest rate swap transactions with a fixed interest rate of 1.776% and a notional amount of $105.0 to protect itself against adverse movement in interest rates in anticipation of the issuance of long-term debt in 2017. During the third quarter of 2016, the Company entered into seven-year swap transactions with an average fixed interest rate of 1.501% and a notional amount of $120.0 to hedge additional debt expected to be issued in 2017. All of these hedge positions were settled during the second quarter of 2017, resulting in a gain of $7.3 which will be amortized over the hedged periods. Also during the second quarter of 2017, Spire entered into a ten-year interest rate swap with a fixed interest rate of 2.658% and a notional amount of $60.0 to protect itself against adverse movements in interest rates on future interest rate payments. The Company recorded a $0.6 mark-to-market loss on these swaps for the nine months ended June 30, 2017. The fair values of related derivative instruments are shown in Note 6, Fair Value Measurements. Information about the Company’s short-term and long-term debt is included under the heading “Liquidity and Capital Resources” in this Item 2.

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ENVIRONMENTAL MATTERS

The Utilities own and operate natural gas distribution, transmission and storage facilities, the operations of which are subject to various environmental laws and regulations, along with their interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s, Laclede Gas’, or Alagasco’s financial position and results of operations. As environmental laws, regulations, and interpretations change, however, the Utilities may be required to incur additional costs. For information relative to environmental matters, see Note 10, Commitments and Contingencies, of the Notes to Financial Statements included in Item 1.

OFF-BALANCE SHEET ARRANGEMENTS

At June 30, 2017, the Company had no off-balance-sheet financing arrangements, other than operating leases and letters of credit entered into in the ordinary course of business. The Company does not expect to engage in any significant off-balance-sheet financing arrangements in the near future.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

For this discussion, see Part I., Item 2., Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk.

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Item 4. Controls and Procedures

Spire

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

Effective September 12, 2016, we acquired EnergySouth, Inc. As the acquisition occurred during the last 12 months, the scope of our assessment of the effectiveness of disclosure controls and procedures does not include the internal control over financial reporting of EnergySouth. This exclusion is in accordance with the SEC’s guidance that management’s evaluation of the effectiveness of disclosure controls and procedures may exclude an assessment of those disclosure controls and procedures of the acquired entity that are subsumed by internal control over financial reporting in the year following the acquisition. EnergySouth’s business constituted 2.8 percent and 4.2 percent of Spire’s net and total assets, respectively, as of June 30, 2017, and 5.5 percent of revenues for the nine months ended June 30, 2017.

As a result of the acquisition of EnergySouth, the Company is evaluating and implementing changes to processes, policies and other components of its internal control over financial reporting with respect to the consolidation of EnergySouth’s operations into the Company’s financial statements. During the period ended June 30, 2017, changes to the Company’s controls occurred as a substantial portion of EnergySouth’s stand-alone financial systems and related processes were integrated with the Company’s existing systems and processes. These changes are not considered to be material to the Company’s internal control over financial reporting.

Management continues to be engaged in efforts to evaluate the effectiveness of our internal control procedures and the design of those control procedures relating to EnergySouth. Except for the activities described above, there were no changes in the Company’s internal control over financial reporting that occurred during the quarter ended June 30, 2017 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Laclede Gas

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

There were no changes in Laclede Gas’ internal control over financial reporting that occurred during the quarter ended June 30, 2017 that have materially affected, or are reasonably likely to materially affect, Laclede Gas’ internal control over financial reporting.

Alagasco

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

There were no changes in Alagasco’s internal control over financial reporting that occurred during the quarter ended June 30, 2017 that have materially affected, or are reasonably likely to materially affect, Alagasco’s internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For a description of environmental matters and legal proceedings, see Note 10, Commitments and Contingencies, of the Notes to Financial Statements in Item 1 of Part 1. For a description of pending regulatory matters, see Regulatory and Other Matters under Part I, Item 2.

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

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

The only repurchase of Spire’s common stock in the quarter were pursuant to elections by employees to have shares of stock withheld to cover employee tax withholding obligations upon the vesting of performance-based and time-vested restricted stock and stock units. The following table provides information on those repurchases.

Period	(a) Total Number of Shares Purchased	(b) Average Price Paid Per Share	(c) Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	(d) Maximum Number of Shares That May Yet be Purchased Under the Plans or Programs
April 1, 2017 - April 30, 2017	386	$67.45	—	—
May 1, 2017 - May 31, 2017	192	$68.25	—	—
June 1, 2017 - June 30, 2017	—	$—	—	—
Total	578	$67.72	—	—

Laclede Gas’ outstanding first mortgage bonds contain restrictions on its ability to pay cash dividends on its common stock. As of June 30, 2017, all of Laclede Gas’ retained earnings were free from such restrictions.

Item 6. Exhibits

See Exhibit Index.

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SIGNATURES

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

		Spire Inc.
Date:	August 2, 2017	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Executive Vice President and Chief Financial Officer
			(Authorized Signatory and Principal Financial Officer)

		Laclede Gas Company
Date:	August 2, 2017	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer
			(Authorized Signatory and Principal Financial Officer)

		Alabama Gas Corporation
Date:	August 2, 2017	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer
			(Authorized Signatory and Principal Financial Officer)

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EXHIBIT INDEX

Exhibit No.	Description
10.1*	Spire Inc. Executive Severance Plan, filed as Exhibit 10.1 to Spire Inc.’s Current Report on Form 8-K filed May 2, 2017.
31.1	CEO and CFO Certifications under Exchange Act Rule 13a-14(a) of Spire Inc.
31.2	CEO and CFO Certifications under Exchange Act Rule 13a-14(a) of Laclede Gas Company.
31.3	CEO and CFO Certifications under Exchange Act Rule 13a-14(a) of Alabama Gas Corporation.
32.1	CEO and CFO Section 1350 Certifications of Spire Inc.
32.2	CEO and CFO Section 1350 Certifications of Laclede Gas Company.
32.3	CEO and CFO Section 1350 Certifications of Alabama Gas Corporation.
101.INS	XBRL Instance Document. (1)
101.SCH	XBRL Taxonomy Extension Schema. (1)
101.CAL	XBRL Taxonomy Extension Calculation Linkbase. (1)
101.DEF	XBRL Taxonomy Extension Definition Linkbase. (1)
101.LAB	XBRL Taxonomy Extension Label Linkbase. (1)
101.PRE	XBRL Taxonomy Extension Presentation Linkbase. (1)

(1) Attached as Exhibit 101 to this Quarterly Report are the following documents for each registrant formatted in extensible business reporting language (XBRL): (i) Document and Entity Information; (ii) unaudited Condensed Consolidated Statements of Income and Condensed Statements of Income for the three and nine months ended June 30, 2017 and 2016; (iii) unaudited Condensed Consolidated Statements of Comprehensive Income and Condensed Statements of Comprehensive Income for the three and nine months ended June 30, 2017 and 2016; (iv) unaudited Condensed Consolidated Balance Sheets and Condensed Balance Sheets at June 30, 2017, September 30, 2016 and June 30, 2016; (v) unaudited Condensed Consolidated Statements of Common Shareholders’ Equity and Condensed Statements of Common Shareholder’s Equity for the nine months ended June 30, 2017 and 2016; (vi) unaudited Condensed Consolidated Statements of Cash Flows and Condensed Statements of Cash Flows for the nine months ended June 30, 2017 and 2016, and (vii) combined Notes to Financial Statements. We also make available on our website the Interactive Data Files submitted as Exhibit 101 to this Quarterly Report.

* Reflects a management contract or compensatory plan, contract or arrangement incorporated herein by reference and made a part hereof. Spire Inc. File No. 1-16681.

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EX-31.1

Exhibit 31.1

CERTIFICATION

I, Suzanne Sitherwood, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Spire Inc.;

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

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

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

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

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

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

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

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

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

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

Date:	August 2, 2017	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			President and Chief Executive Officer

CERTIFICATION

I, Steven P. Rasche, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Spire Inc.;

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

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

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

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

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

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

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

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

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

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

Date:	August 2, 2017	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Executive Vice President and Chief Financial Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Steven L. Lindsey, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 2, 2017	Signature:	/s/ Steven L. Lindsey
			Steven L. Lindsey
			President and Chief Executive Officer

CERTIFICATION

I, Steven P. Rasche, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 2, 2017	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

EX-31.3

Exhibit 31.3

CERTIFICATION

I, Steven L. Lindsey, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 2, 2017	Signature:	/s/ Steven L. Lindsey
			Steven L. Lindsey
			Chief Executive Officer

CERTIFICATION

I, Steven P. Rasche, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:	August 2, 2017	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

EX-32.1

Exhibit 32.1

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Suzanne Sitherwood, President and Chief Executive Officer of Spire Inc., hereby certify that:

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the period ended June 30, 2017 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the period ended June 30, 2017 fairly presents, in all material respects, the financial condition and results of operations of Spire Inc.

Date:	August 2, 2017	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			President and Chief Executive Officer

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Steven P. Rasche, Executive Vice President and Chief Financial Officer of Spire Inc., hereby certify that:

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the period ended June 30, 2017 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the period ended June 30, 2017 fairly presents, in all material respects, the financial condition and results of operations of Spire Inc.

Date:	August 2, 2017	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Executive Vice President and Chief Financial Officer

EX-32.2

Exhibit 32.2

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Steven L. Lindsey, President and Chief Executive Officer of Laclede Gas Company, hereby certify that:

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the period ended June 30, 2017 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the period ended June 30, 2017 fairly presents, in all material respects, the financial condition and results of operations of Laclede Gas Company.

Date:	August 2, 2017	Signature:	/s/ Steven L. Lindsey
			Steven L. Lindsey
			President and Chief Executive Officer

Section 1350 Certification

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

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the period ended June 30, 2017 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the period ended June 30, 2017 fairly presents, in all material respects, the financial condition and results of operations of Laclede Gas Company.

Date:	August 2, 2017	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

EX-32.3

Exhibit 32.3

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Steven L. Lindsey, Chief Executive Officer of Alabama Gas Corporation, hereby certify that:

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the period ended June 30, 2017 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the period ended June 30, 2017 fairly presents, in all material respects, the financial condition and results of operations of Alabama Gas Corporation.

Date:	August 2, 2017	Signature:	/s/ Steven L. Lindsey
			Steven L. Lindsey
			Chief Executive Officer

Section 1350 Certification

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

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the period ended June 30, 2017 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the period ended June 30, 2017 fairly presents, in all material respects, the financial condition and results of operations of Alabama Gas Corporation.

Date:	August 2, 2017	Signature:	/s/ Steven P. Rasche
			Steven P. Rasche
			Chief Financial Officer

XML

Document and Entity Information - shares	9 Months Ended
	Jun. 30, 2017	Jul. 31, 2017
Entity Information [Line Items]
Entity Registrant Name	SPIRE INC
Entity Central Index Key	0001126956
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		48,262,027
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Laclede Gas
Entity Information [Line Items]
Entity Registrant Name	LACLEDE GAS CO
Entity Central Index Key	0000057183
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		24,577
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Alagasco
Entity Information [Line Items]
Entity Registrant Name	ALABAMA GAS CORP
Entity Central Index Key	0000003146
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		1,972,052
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) shares in Millions, $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Operating Revenues:
Gas Utility	$ 305.1	$ 253.2	$ 1,419.1	$ 1,263.5
Gas Marketing and other	18.4	(3.9)	62.9	(5.5)
Total Operating Revenues	323.5	249.3	1,482.0	1,258.0
Gas Utility
Natural and propane gas	76.7	54.1	524.8	463.7
Operation and maintenance	100.8	91.8	298.6	277.7
Depreciation and amortization	38.4	34.2	114.0	101.5
Taxes, other than income taxes	30.5	27.4	112.2	99.5
Total Gas Utility Operating Expenses	246.4	207.5	1,049.6	942.4
Gas Marketing and other	26.8	6.5	112.6	25.6
Total Operating Expenses	273.2	214.0	1,162.2	968.0
Operating Income	50.3	35.3	319.8	290.0
Other Income	1.5	1.6	5.6	3.8
Interest Charges:
Interest on long-term debt	19.0	16.6	57.3	50.2
Other interest charges	2.4	2.8	8.9	7.5
Total Interest Charges	21.4	19.4	66.2	57.7
Income Before Income Taxes	30.4	17.5	259.2	236.1
Income Tax Expense	8.7	6.8	84.3	77.7
Net Income	$ 21.7	$ 10.7	$ 174.9	$ 158.4
Weighted Average Number of Common Shares Outstanding:
Basic (in shares)	48.1	44.4	46.4	43.6
Diluted (in shares)	48.2	44.6	46.6	43.8
Basic Earnings Per Share of Common Stock (in dollars per share)	$ 0.45	$ 0.24	$ 3.76	$ 3.62
Diluted Earnings Per Share of Common Stock (in dollars per share)	0.45	0.24	3.75	3.60
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.53	$ 0.49	$ 1.58	$ 1.47
Laclede Gas
Operating Revenues:
Gas Utility	$ 198.5	$ 179.3	$ 1,009.3	$ 943.2
Total Operating Revenues	198.5	179.3	1,009.3	943.2
Gas Utility
Natural and propane gas	61.9	48.0	494.4	440.6
Operation and maintenance	61.2	58.4	179.2	178.7
Depreciation and amortization	23.2	22.3	68.9	66.0
Taxes, other than income taxes	21.7	21.2	81.6	76.4
Total Operating Expenses	168.0	149.9	824.1	761.7
Operating Income	30.5	29.4	185.2	181.5
Other Income	0.7	1.0	2.7	2.2
Interest Charges:
Interest on long-term debt	8.0	8.1	24.5	24.7
Other interest charges	1.5	1.0	4.4	3.2
Total Interest Charges	9.5	9.1	28.9	27.9
Income Before Income Taxes	21.7	21.3	159.0	155.8
Income Tax Expense	6.2	7.4	48.5	48.2
Net Income	15.5	13.9	110.5	107.6
Alagasco
Operating Revenues:
Gas Utility	90.5	74.0	336.0	322.3
Total Operating Revenues	90.5	74.0	336.0	322.3
Gas Utility
Natural and propane gas	22.5	13.1	65.1	55.4
Operation and maintenance	32.9	33.5	95.6	99.7
Depreciation and amortization	12.6	11.9	37.2	35.5
Taxes, other than income taxes	7.0	6.2	23.9	23.1
Total Operating Expenses	75.0	64.7	221.8	213.7
Operating Income	15.5	9.3	114.2	108.6
Other Income	0.6	0.5	2.1	1.5
Interest Charges:
Interest on long-term debt	2.8	2.8	8.4	8.5
Other interest charges	0.8	0.6	2.3	1.9
Total Interest Charges	3.6	3.4	10.7	10.4
Income Before Income Taxes	12.5	6.4	105.6	99.7
Income Tax Expense	5.1	2.4	40.3	37.7
Net Income	$ 7.4	$ 4.0	$ 65.3	$ 62.0

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Net Income	$ 21.7	$ 10.7	$ 174.9	$ 158.4
Cash flow hedging derivative instruments:
Net hedging (losses) gains arising during the period	(1.0)	(4.3)	11.5	(5.6)
Reclassification adjustment for (gains) losses included in net income	0.0	(1.5)	0.1	0.2
Net unrealized (losses) gains on cash flow hedging derivative instruments	(1.0)	(5.8)	11.6	(5.4)
Net gains on defined benefit pension and other postretirement plans	0.1	0.0	0.2	0.1
Net unrealized losses on available for sale securities	0.0	0.0	(0.1)	0.0
Other Comprehensive Income (Loss), Before Tax	(0.9)	(5.8)	11.7	(5.3)
Income Tax (Benefit) Expense Related to Items of Other Comprehensive Income	(0.4)	(2.2)	4.3	(2.0)
Other Comprehensive Income (Loss), Net of Tax	(0.5)	(3.6)	7.4	(3.3)
Comprehensive Income	21.2	7.1	182.3	155.1
Laclede Gas
Net Income	15.5	13.9	110.5	107.6
Cash flow hedging derivative instruments:
Other Comprehensive Income (Loss), Net of Tax	0.0	0.1	0.0	0.3
Comprehensive Income	$ 15.5	$ 14.0	$ 110.5	$ 107.9

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016
ASSETS
Utility Plant	$ 5,071.4	$ 4,793.6	$ 4,339.5
Less: Accumulated depreciation and amortization	1,609.6	1,506.4	1,311.5
Net Utility Plant	3,461.8	3,287.2	3,028.0
Non-utility Property (net of accumulated depreciation and amortization of $8.4, $8.1 and $7.9 at June 30, 2017, September 30, 2016, and June 30, 2016, respectively)	39.9	13.7	13.8
Goodwill	1,163.9	1,164.9	946.0
Other Property and Investments	63.8	62.1	62.4
Total Other Property and Investments	1,267.6	1,240.7	1,022.2
Current Assets:
Cash and cash equivalents	8.3	5.2	4.9
Accounts receivable:
Utility	141.9	127.8	133.1
Other	124.0	113.4	82.7
Allowance for doubtful accounts	(17.7)	(20.5)	(20.2)
Delayed customer billings	7.0	1.6	3.5
Inventories:
Natural gas	144.4	174.0	116.6
Propane gas	12.0	12.0	12.0
Materials and supplies	18.4	16.3	15.3
Natural gas receivable	6.5	9.7	17.5
Derivative instrument assets	7.3	11.4	9.0
Unamortized purchased gas adjustments	73.9	49.7	5.4
Other regulatory assets	70.7	44.2	37.5
Prepayments and other	32.4	24.8	36.1
Total Current Assets	629.1	569.6	453.4
Deferred Charges:
Regulatory assets	840.5	838.0	730.7
Other	99.2	128.9	64.7
Total Deferred Charges	939.7	966.9	795.4
Total Assets	6,298.2	6,064.4	5,299.0
Capitalization:
Common stock	48.2	45.6	45.6
Paid-in capital	1,323.7	1,175.9	1,173.5
Retained earnings	653.1	550.9	588.6
Accumulated other comprehensive income (loss)	3.2	(4.2)	(5.3)
Total Common Stock Equity	2,028.2	1,768.2	1,802.4
Long-term debt (less current portion)	1,925.3	1,820.7	1,839.8
Total Capitalization	3,953.5	3,588.9	3,642.2
Current Liabilities:
Current portion of long-term debt	0.0	250.0	0.0
Notes payable	450.7	398.7	97.6
Accounts payable	206.4	210.9	135.8
Advance customer billings	15.9	70.2	53.0
Wages and compensation accrued	38.9	39.8	36.5
Dividends payable	26.3	23.5	22.3
Customer deposits	35.0	34.9	31.9
Interest accrued	24.2	14.8	19.7
Taxes accrued	55.6	55.2	41.4
Unamortized purchased gas adjustments	1.0	1.7	0.0
Regulatory liabilities	24.9	28.9	22.4
Other	30.9	32.7	31.2
Total Current Liabilities	909.8	1,161.3	491.8
Deferred Credits and Other Liabilities:
Deferred income taxes	705.3	607.3	574.1
Pension and postretirement benefit costs	300.4	303.7	246.9
Asset retirement obligations	214.7	206.4	164.6
Regulatory liabilities	139.8	130.7	105.7
Other	74.7	66.1	73.7
Total Deferred Credits and Other Liabilities	1,434.9	1,314.2	1,165.0
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	6,298.2	6,064.4	5,299.0
Laclede Gas
ASSETS
Utility Plant	2,914.1	2,718.5	2,659.7
Less: Accumulated depreciation and amortization	670.3	604.5	595.4
Net Utility Plant	2,243.8	2,114.0	2,064.3
Goodwill	210.2	210.2	210.2
Other Property and Investments	58.9	57.3	56.5
Total Other Property and Investments	269.1	267.5	266.7
Current Assets:
Cash and cash equivalents	2.6	2.1	1.5
Accounts receivable:
Utility	94.4	87.9	101.0
Associated companies	1.7	2.2	1.3
Other	13.8	11.4	10.5
Allowance for doubtful accounts	(13.4)	(16.1)	(16.5)
Delayed customer billings	7.0	1.6	3.5
Inventories:
Natural gas	93.6	127.3	78.2
Propane gas	12.0	12.0	12.0
Materials and supplies	11.3	9.2	9.2
Derivative instrument assets	0.7	4.9	5.1
Unamortized purchased gas adjustments	29.0	43.1	0.6
Other regulatory assets	38.2	23.9	23.7
Prepayments and other	21.3	14.5	20.4
Total Current Assets	312.2	324.0	250.5
Deferred Charges:
Regulatory assets	583.4	589.8	562.6
Other	3.1	1.1	5.0
Total Deferred Charges	586.5	590.9	567.6
Total Assets	3,411.6	3,296.4	3,149.1
Capitalization:
Paid-in capital and common stock	755.3	752.0	750.9
Retained earnings	414.0	318.3	333.9
Accumulated other comprehensive income (loss)	(1.8)	(1.8)	(1.4)
Total Common Stock Equity	1,167.5	1,068.5	1,083.4
Long-term debt (less current portion)	804.5	804.1	803.9
Total Capitalization	1,972.0	1,872.6	1,887.3
Current Liabilities:
Notes payable	0.0	243.7	97.6
Notes payable – associated companies	260.2	0.0	38.8
Accounts payable	54.0	67.6	49.7
Accounts payable – associated companies	5.4	5.4	4.1
Advance customer billings	0.7	49.1	35.2
Wages and compensation accrued	29.4	29.9	28.7
Dividends payable	0.0	14.0	22.4
Customer deposits	13.2	13.5	13.3
Interest accrued	9.5	7.7	9.4
Taxes accrued	28.3	29.1	21.0
Regulatory liabilities	2.7	1.3	1.3
Other	7.5	9.9	9.1
Total Current Liabilities	410.9	471.2	330.6
Deferred Credits and Other Liabilities:
Deferred income taxes	620.9	556.9	548.8
Pension and postretirement benefit costs	204.2	211.8	191.9
Asset retirement obligations	77.9	75.2	75.0
Regulatory liabilities	83.6	67.3	65.7
Other	42.1	41.4	49.8
Total Deferred Credits and Other Liabilities	1,028.7	952.6	931.2
Commitments and Contingencies (Note 10)
Total Capitalization and Liabilities	3,411.6	3,296.4	3,149.1
Alagasco
ASSETS
Utility Plant	1,809.0	1,729.6	1,679.8
Less: Accumulated depreciation and amortization	791.2	756.6	716.1
Net Utility Plant	1,017.8	973.0	963.7
Current Assets:
Cash and cash equivalents	0.1	0.0	0.0
Accounts receivable:
Utility	40.6	34.0	32.2
Associated companies	0.2	0.0	0.0
Other	5.8	7.2	5.3
Allowance for doubtful accounts	(2.2)	(3.3)	(3.7)
Inventories:
Natural gas	29.0	34.6	28.3
Materials and supplies	5.9	5.9	6.0
Deferred income taxes	0.0	0.0	5.0
Unamortized purchased gas adjustments	44.9	5.6	4.8
Other regulatory assets	17.3	14.9	13.8
Prepayments and other	6.6	5.1	6.1
Total Current Assets	148.2	104.0	97.8
Deferred Charges:
Regulatory assets	228.7	230.7	167.5
Deferred income taxes	181.1	221.4	211.0
Other	63.2	60.8	57.7
Total Deferred Charges	473.0	512.9	436.2
Total Assets	1,639.0	1,589.9	1,497.7
Capitalization:
Paid-in capital and common stock	420.9	451.9	451.9
Retained earnings	463.5	415.4	432.2
Total Common Stock Equity	884.4	867.3	884.1
Long-term debt (less current portion)	247.7	247.6	247.6
Total Capitalization	1,132.1	1,114.9	1,131.7
Current Liabilities:
Notes payable	0.0	82.0	0.0
Notes payable – associated companies	114.9	0.0	37.8
Accounts payable	45.1	34.3	26.6
Accounts payable – associated companies	1.4	0.4	1.3
Advance customer billings	15.2	21.1	17.8
Wages and compensation accrued	7.5	7.8	7.8
Customer deposits	18.1	18.2	18.6
Interest accrued	3.5	3.3	3.6
Taxes accrued	20.5	21.6	19.8
Regulatory liabilities	17.8	22.7	21.1
Other	3.4	6.3	5.1
Total Current Liabilities	247.4	217.7	159.5
Deferred Credits and Other Liabilities:
Pension and postretirement benefit costs	77.9	74.3	55.0
Asset retirement obligations	125.4	120.1	89.4
Regulatory liabilities	34.4	41.7	40.0
Other	21.8	21.2	22.1
Total Deferred Credits and Other Liabilities	259.5	257.3	206.5
Total Capitalization and Liabilities	$ 1,639.0	$ 1,589.9	$ 1,497.7

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016
Assets
Non-utility property, accumulated depreciation and amortization	$ 8.4	$ 8.1	$ 7.9
Capitalization:
Common stock, par value (in dollars per share)	$ 1.00	$ 1.00	$ 1.00
Common stock, authorized (in shares)	70,000,000.0	70,000,000.0	70,000,000.0
Common stock, issued (in shares)	48,300,000	45,600,000	45,600,000
Common stock, outstanding (in shares)	48,300,000	45,600,000	45,600,000
Laclede Gas
Capitalization:
Common stock, par value (in dollars per share)	$ 1.00	$ 1.00	$ 1.00
Common stock, authorized (in shares)	50,000	50,000	50,000
Common stock, issued (in shares)	24,577	24,577	24,577
Common stock, outstanding (in shares)	24,577	24,577	24,577
Alagasco
Capitalization:
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01	$ 0.01
Common stock, authorized (in shares)	3,000,000	3,000,000	3,000,000.0
Common stock, issued (in shares)	2,000,000	2,000,000	2,000,000
Common stock, outstanding (in shares)	2,000,000	2,000,000	2,000,000

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CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY (UNAUDITED) - USD ($) $ in Millions	Total	Common Stock Outstanding	Paid-in Capital	Retained Earnings	AOCI	Laclede Gas	Laclede Gas Common Stock Outstanding	Laclede Gas Paid-in Capital	Laclede Gas Retained Earnings	Laclede Gas AOCI	Alagasco	Alagasco Common Stock Outstanding	Alagasco Paid-in Capital	Alagasco Retained Earnings
Beginning Balance at Sep. 30, 2015	$ 1,573.6	$ 43.3	$ 1,038.1	$ 494.2	$ (2.0)	$ 1,037.8	$ 0.1	$ 748.2	$ 291.2	$ (1.7)	$ 874.6	$ 0.0	$ 480.9	$ 393.7
Beginning Balance, (in shares) at Sep. 30, 2015		43,335,012					24,577					1,972,052
Stockholders' Equity Rollforward
Net income	158.4			158.4		107.6			107.6		62.0			62.0
Common stock offering (in shares)		2,185,000
Common stock offering	133.2	$ 2.2	131.0
Dividend reinvestment plan	1.0		1.0
Dividend reinvestment plan (in shares)		17,454
Stock-based compensation costs	4.6		4.6			2.6		2.6
Stock issued under stock-based compensation plans	0.6	$ 0.1	0.5
Stock issued under stock-based compensation plans (in shares)		127,489
Employee’s tax withholding for stock-based compensation	(1.7)		(1.7)
Employee's tax withholding for stock-based compensation (in shares)		(29,227)
Return of capital to Spire											(29.0)		(29.0)
Dividends declared	(64.0)			(64.0)		(64.9)			(64.9)		(23.5)			(23.5)
Other comprehensive income (loss), net of tax	(3.3)				(3.3)	0.3				0.3
Ending Balance at Jun. 30, 2016	1,802.4	$ 45.6	1,173.5	588.6	(5.3)	1,083.4	$ 0.1	750.8	333.9	(1.4)	884.1	$ 0.0	451.9	432.2
Ending Balance, (in shares) at Jun. 30, 2016		45,635,728					24,577					1,972,052
Beginning Balance at Sep. 30, 2016	1,768.2	$ 45.6	1,175.9	550.9	(4.2)	1,068.5	$ 0.1	751.9	318.3	(1.8)	867.3	$ 0.0	451.9	415.4
Beginning Balance, (in shares) at Sep. 30, 2016		45,650,642					24,577					1,972,052
Stockholders' Equity Rollforward
Net income	174.9			174.9		110.5			110.5		65.3			65.3
Common stock offering (in shares)		2,504,684
Common stock offering	145.5	$ 2.5	143.0
Dividend reinvestment plan	1.2		1.2
Dividend reinvestment plan (in shares)		18,025
Stock-based compensation costs	6.8		5.9	0.9		3.3		3.3
Stock issued under stock-based compensation plans	0.0	$ 0.1	(0.1)
Stock issued under stock-based compensation plans (in shares)		119,660
Employee’s tax withholding for stock-based compensation	(2.2)		(2.2)
Employee's tax withholding for stock-based compensation (in shares)		(35,167)
Return of capital to Spire											(31.0)		(31.0)
Dividends declared	(73.6)			(73.6)		(14.8)			(14.8)		(17.2)			(17.2)
Other comprehensive income (loss), net of tax	7.4				7.4	0.0
Ending Balance at Jun. 30, 2017	$ 2,028.2	$ 48.2	$ 1,323.7	$ 653.1	$ 3.2	$ 1,167.5	$ 0.1	$ 755.2	$ 414.0	$ (1.8)	$ 884.4	$ 0.0	$ 420.9	$ 463.5
Ending Balance, (in shares) at Jun. 30, 2017		48,257,844					24,577					1,972,052

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Operating Activities:
Net Income	$ 174.9	$ 158.4
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	114.4	102.0
Deferred income taxes and investment tax credits	84.1	77.7
Changes in assets and liabilities:
Accounts receivable	(33.1)	6.7
Unamortized purchased gas adjustments	(26.1)	(11.3)
Accounts payable	14.8	(6.4)
Delayed/advance customer billings – net	(59.7)	7.8
Taxes accrued	(4.8)	(10.9)
Inventories	27.5	71.5
Other assets and liabilities	24.2	(38.5)
Other	4.5	(0.1)
Net cash provided by operating activities	320.7	356.9
Investing Activities:
Capital expenditures	(298.6)	(195.3)
Settlement for acquisition of EnergySouth	3.8	0.0
Other	1.1	(1.5)
Net cash used in investing activities	(293.7)	(196.8)
Financing Activities:
Issuance of long-term debt	250.0	80.0
Repayment of long-term debt	(393.8)	(80.0)
Issuance (repayment) of short-term debt - net	52.0	(240.4)
Issuance of common stock	146.4	136.1
Dividends paid	(70.9)	(62.9)
Other	(7.6)	(1.8)
Net cash used in financing activities	(23.9)	(169.0)
Net Increase (Decrease) in Cash and Cash Equivalents	3.1	(8.9)
Cash and Cash Equivalents at Beginning of Period	5.2	13.8
Cash and Cash Equivalents at End of Period	8.3	4.9
Supplemental disclosure of cash (paid) refunded for:
Interest	(54.5)	(48.2)
Income taxes	(0.7)	3.9
Laclede Gas
Operating Activities:
Net Income	110.5	107.6
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	68.9	66.0
Deferred income taxes and investment tax credits	48.5	48.2
Changes in assets and liabilities:
Accounts receivable	(11.0)	24.6
Unamortized purchased gas adjustments	12.8	21.7
Accounts payable	(6.2)	(7.3)
Delayed/advance customer billings – net	(53.8)	9.1
Taxes accrued	(0.7)	(4.5)
Inventories	31.6	60.1
Other assets and liabilities	0.5	(29.4)
Other	1.4	0.7
Net cash provided by operating activities	202.5	296.8
Investing Activities:
Capital expenditures	(189.5)	(138.8)
Other	0.7	0.9
Net cash used in investing activities	(188.8)	(137.9)
Financing Activities:
Repayment of short-term debt - net	(243.7)	(135.4)
Borrowings from Spire - net	260.2	38.8
Dividends paid	(28.7)	(62.5)
Other	(1.0)	0.0
Net cash used in financing activities	(13.2)	(159.1)
Net Increase (Decrease) in Cash and Cash Equivalents	0.5	(0.2)
Cash and Cash Equivalents at Beginning of Period	2.1	1.7
Cash and Cash Equivalents at End of Period	2.6	1.5
Supplemental disclosure of cash (paid) refunded for:
Interest	(26.9)	(22.1)
Income taxes	0.0	2.1
Alagasco
Operating Activities:
Net Income	65.3	62.0
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization, and accretion	37.2	35.5
Deferred income taxes and investment tax credits	40.3	37.7
Changes in assets and liabilities:
Accounts receivable	(12.4)	(6.4)
Unamortized purchased gas adjustments	(39.3)	(33.0)
Accounts payable	10.7	4.3
Delayed/advance customer billings – net	(5.9)	(1.3)
Taxes accrued	(1.1)	(6.2)
Inventories	5.6	11.5
Other assets and liabilities	(4.1)	(7.0)
Other	(0.3)	(0.7)
Net cash provided by operating activities	96.0	96.4
Investing Activities:
Capital expenditures	(80.2)	(56.1)
Other	0.0	(1.8)
Net cash used in investing activities	(80.2)	(57.9)
Financing Activities:
Issuance of long-term debt	0.0	80.0
Repayment of long-term debt	0.0	(80.0)
Repayment of short-term debt - net	(82.0)	(31.0)
Return of capital to Spire	(31.0)	(29.0)
Borrowings from Spire - net	114.9	37.8
Dividends paid	(17.2)	(23.5)
Other	(0.4)	0.0
Net cash used in financing activities	(15.7)	(45.7)
Net Increase (Decrease) in Cash and Cash Equivalents	0.1	(7.2)
Cash and Cash Equivalents at Beginning of Period	0.0	7.2
Cash and Cash Equivalents at End of Period	0.1	0.0
Supplemental disclosure of cash (paid) refunded for:
Interest	(9.3)	(9.2)
Income taxes	$ 0.0	$ 0.8

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION –These notes are an integral part of the accompanying unaudited financial statements of Spire Inc. (Spire or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Laclede Gas, Alagasco and the subsidiaries of EnergySouth, Inc. (EnergySouth) are collectively referred to as the Utilities. The subsidiaries of EnergySouth are Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas & Oil Company (Willmut Gas).

The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial information with the instructions to Form 10-Q and Rule 10-01 of Regulation S‑X. Accordingly, they do not include all of the disclosures required for complete financial statements. In the opinion of management, the accompanying unaudited financial statements include all adjustments (consisting of only normal recurring adjustments) necessary for the fair presentation of the results of operations for the periods presented. This Form 10-Q should be read in conjunction with the Notes to Financial Statements contained in Spire’s, Laclede Gas’, and Alagasco’s Annual Reports on Form 10-K for the fiscal year ended September 30, 2016.

The consolidated financial position, results of operations, and cash flows of Spire are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between Laclede Gas and Alagasco and their affiliates, as well as intercompany balances on their balance sheets, have not been eliminated from their separate financial statements. Results of operations of EnergySouth are included in Spire’s results of operations since the September 12, 2016 acquisition and impact the comparability of financial statement periods presented for the Company.

NATURE OF OPERATIONS – Spire Inc. (NYSE: SR), headquartered in St. Louis, Missouri, is a public utility holding company. The Company has two reportable segments: Gas Utility and Gas Marketing. The Gas Utility segment consists of the regulated natural gas distribution operations of the Company and is the core business segment of Spire in terms of revenue and earnings generation. The Gas Utility segment is comprised of the operations of: the Missouri Utilities, serving St. Louis and eastern Missouri, Kansas City and western Missouri (through MGE); Alagasco, serving central and northern Alabama; and the subsidiaries of EnergySouth, serving southern Alabama and south-central Mississippi. Spire’s primary non-utility business, Spire Marketing Inc. (Spire Marketing) was formerly known as Laclede Energy Resources, Inc., which changed its name on December 12, 2016. Spire Marketing is included in the Gas Marketing segment and provides non-regulated natural gas services. The activities of other subsidiaries are described in Note 9, Information by Operating Segment, and are reported as Other. Laclede Gas and Alagasco each have a single reportable segment.

The Company’s earnings are primarily derived from its Gas Utility segment. Due to the seasonal nature of the Utilities’ business, earnings are typically concentrated during the heating season of November through April each fiscal year. As a result, the interim statements of income for Spire, Laclede Gas and Alagasco are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year.

GOODWILL – Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. The changes in the carrying amount of goodwill by reportable segment are shown below, reflecting the effect of a $3.8 cash payment to Spire related to the EnergySouth acquisition, offset by net adjustments to acquired insurance receivable and prepaid assets.

	Gas Utility		Gas Marketing		Other			Total
Balance as of September 30, 2016	$	210.2	$	—	$	954.7		$	1,164.9
Adjustments related to the acquisition of EnergySouth	—		—		(1.0		)	(1.0		)
Balance as of June 30, 2017	$	210.2	$	—	$	953.7		$	1,163.9

REVENUE RECOGNITION – The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues for Laclede Gas at June 30, 2017, September 30, 2016, and June 30, 2016 were $31.9, $26.1, and $28.5, respectively.

Alagasco records natural gas distribution revenues in accordance with the tariff established by the Alabama Public Service Commission (APSC). Unbilled revenues for Alagasco, which are not recorded as revenue until billed, at June 30, 2017, September 30, 2016, and June 30, 2016 were $6.0, $5.9, and $6.4, respectively.

The subsidiaries of EnergySouth record natural gas revenues in accordance with tariffs established by the APSC and the Mississippi Public Service Commission (MSPSC). Their unbilled revenues are accrued as described for Laclede Gas above.

Spire’s other subsidiaries, including Spire Marketing, record revenues when earned, either when the product is delivered or when services are performed.

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

GROSS RECEIPTS TAXES – Gross receipts taxes associated with the Company’s natural gas utility services are imposed on the Utilities and billed to their customers. The revenue and expense amounts are recorded gross in the “Operating Revenues” and “Taxes, other than income taxes” lines, respectively, in the statements of income. The following table presents gross receipts taxes recorded as revenues.

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Spire	$	18.0	$	14.8	$	71.7	$	65.0
Laclede Gas	12.4		11.1		52.0		49.7
Alagasco	4.2		3.7		16.1		15.3

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

As authorized by the Missouri Public Service Commission (MoPSC), MSPSC and APSC, the Purchased Gas Adjustment (PGA) clauses and Gas Supply Adjustment (GSA) riders allow the Utilities to pass through to customers the cost of purchased gas supplies. Regulatory assets and liabilities related to the PGA clauses and the GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. See additional information about regulatory assets and liabilities in Note 3, Regulatory Matters.

TRANSACTIONS WITH AFFILIATES –Transactions between affiliates of the Company have been eliminated from the consolidated financial statements of Spire. Laclede Gas and Alagasco borrowed funds from the Company and incurred related interest, as reflected in their separate financial statements, and participated in normal intercompany shared services transactions. Laclede Gas’ and Alagasco’s other transactions with affiliates included:

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Laclede Gas
Purchases of natural gas from Spire Marketing	$	11.8	$	6.7	$	53.3	$	31.5
Sales of natural gas to Spire Marketing	1.5		—		7.8		1.7
Insurance services received from Laclede Insurance Risk Services	0.5		0.2		1.6		0.7
Transportation services received from Laclede Pipeline Company	0.3		0.3		0.8		0.8
Alagasco
Insurance services received from Laclede Insurance Risk Services	0.5		—		1.5		—

ACCRUED CAPITAL EXPENDITURES – Accrued capital expenditures, shown in the following table, are excluded from capital expenditures in the statements of cash flows.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	26.5	$	21.6	$	9.9
Laclede Gas	16.5		14.8		5.3
Alagasco	7.9		6.8		4.6

RECLASSIFICATIONS – Certain prior period amounts have been reclassified to conform to the current period presentation. Net income and total equity were not affected by these reclassifications.

NEW ACCOUNTING PRONOUNCEMENTS – In April 2015, the FASB issued Accounting Standards Update (ASU) No. 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs. Under prior GAAP, debt issuance costs were recorded as a deferred charge (asset), while debt discount and debt premium costs were recorded as a liability adjustment. This amendment requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Spire, Laclede Gas and Alagasco adopted this ASU as of December 31, 2016. Retrospective adjustments have been made to the previous year balance sheets as of September 30, 2016 and June 30, 2016. The amounts reclassified from other deferred charges to reduce long-term debt are shown in the following table. The ASU does not address the presentation of debt issuance costs related to line-of-credit arrangements, and those continue to be reported as deferred charges.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	14.9	$	13.0	$	11.9
Laclede Gas	4.0		4.2		4.4
Alagasco	2.3		2.4		2.4

In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation: Improvements to Employee Share-Based Payment Accounting. The standard is intended to simplify several areas of accounting for share-based compensation arrangements, including the income tax impact, classification on the statement of cash flows and forfeitures. Spire, Laclede Gas and Alagasco adopted this ASU in the interim quarterly reporting period ended June 30, 2017. Amendments related to the timing of when excess tax benefits are recognized, minimum statutory withholding requirements, and forfeitures were applied using a modified retrospective transition method by means of a cumulative-effect adjustment to retained earnings as of October 1, 2016, and amendments requiring recognition of excess tax benefits and tax deficiencies in the income statement were applied prospectively as of that date. Amendments related to the presentation of excess tax benefits on the statement of cash flows and the presentation of employee taxes paid on the statement of cash flows when an employer withholds shares to meet the minimum statutory withholding requirement were applied retrospectively. There were no material impacts on the financial statements of the Company, Laclede Gas, or Alagasco, all of which adopted a policy of accounting for forfeitures when they occur.

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers. Under the new standard, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. In doing so, companies may need to use more judgment and make more estimates than under current guidance. ASU No. 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. Entities have the option of using either a full retrospective or modified retrospective approach to adopting this guidance. In August 2015, the FASB issued ASU No. 2015-14, which made the guidance in ASU No. 2014-09 effective for fiscal years beginning after December 15, 2017 and interim periods within those years. In 2016, the FASB issued related ASU Nos. 2016-08, 2016-10, 2016-11, 2016-12, and 2016-20 which further modified the standards for accounting for revenue. The Company, Laclede Gas and Alagasco are currently evaluating their sources of revenue and related contracts, the available transition methods, and the potential impacts of the updates. The conclusions of these assessments are contingent, in part, upon the completion of deliberations currently in progress by the power and utilities industry, notably in connection with efforts to produce an accounting guide being developed by the American Institute of Certified Public Accountants (AICPA). In association with this undertaking, the AICPA formed a number of industry task forces, including a Power & Utilities Task Force. Industry representatives and organizations, the largest auditing firms, the AICPA’s Revenue Recognition Working Group and its Financial Reporting Executive Committee have undertaken, and continue to undertake, consideration of several items relevant to our industry as further discussed below. Where applicable or necessary, the FASB’s Transition Resource Group is also participating. Currently, the industry is working to finalize conclusions in several areas including 1) the accounting for funds received from third parties to partially or fully reimburse the cost of construction of an asset, 2) determination of stand-alone selling price for commodities, and 3) the accounting for alternative revenue programs, such as performance-based ratemaking. Existing alternative revenue program guidance, though excluded by the FASB in updating specific guidance associated with revenue from contracts with customers, was relocated without substantial modification to accounting guidance for rate-regulated entities. It will require separate presentation of such revenues (subject to the above-noted deliberations) in the statement of income. Pending the completion of the industry deliberations and internal assessments later this year, the Company, Laclede Gas and Alagasco are currently unable to determine the effect the new guidance will have on their financial position, results of operations, cash flows, and business processes or the transition method they will utilize to adopt the new guidance in the first quarter of fiscal year 2019 (or earlier).

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments – Overall: Recognition and Measurement of Financial Assets and Financial Liabilities, which provides revised guidance concerning certain matters involving the recognition, measurement, and disclosure of financial instruments. It is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Unrealized gains and losses on equity securities previously classified as available-for-sale will be recognized immediately in earnings rather than recorded in other comprehensive income. Entities will record a cumulative-effect adjustment as of the beginning of the fiscal year in which the guidance is adopted, which requires amounts reported in accumulated other comprehensive income for such equity securities to be reclassified to retained earnings. Based on an assessment of their current financial instruments, the Company, Laclede Gas and Alagasco expect to adopt this standard in the first quarter of fiscal year 2019 with no significant impact.

In February 2016, the FASB issued ASU No. 2016-02, Leases. The new standard requires lessees to recognize a right-of-use asset and lease liability for almost all lease contracts based on the present value of lease payments. There is an exemption for short-term leases. The ASU provides new guidelines for identifying and classifying a lease, and classification affects the pattern and income statement line item for the related expense. This update will be applied using a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The ASU is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2020.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses: Measurement of Credit Losses on Financial Instruments. The standard introduces new guidance for the accounting for credit losses on instruments within its scope, including trade receivables. It is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years, and may be adopted a year earlier. The new guidance will be initially applied through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2021.

In March 2017, the FASB issued ASU No. 2017-07, Compensation – Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amended guidance requires that the service cost component of pension and postretirement benefit costs be presented within the same line item in the income statement as other compensation costs (except for the amount being capitalized), while other components are to be presented outside the subtotal of operating income and are no longer eligible for capitalization. The ASU is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The amended guidance will be applied retrospectively for income statement presentation and prospectively for capitalization. The Company, Laclede Gas and Alagasco are currently assessing the regulatory and other impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2019.

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EARNINGS PER COMMON SHARE

9 Months Ended

Jun. 30, 2017

Earnings Per Share [Abstract]

EARNINGS PER COMMON SHARE

EARNINGS PER COMMON SHARE

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Basic EPS:
Net Income	$	21.7	$	10.7	$	174.9	$	158.4
Less: Income allocated to participating securities	0.1		—		0.4		0.5
Net Income Available to Common Shareholders	$	21.6	$	10.7	$	174.5	$	157.9
Weighted Average Shares Outstanding (in millions)	48.1		44.4		46.4		43.6
Basic Earnings Per Share of Common Stock	$	0.45	$	0.24	$	3.76	$	3.62
Diluted EPS:
Net Income	$	21.7	$	10.7	$	174.9	$	158.4
Less: Income allocated to participating securities	0.1		—		0.4		0.5
Net Income Available to Common Shareholders	$	21.6	$	10.7	$	174.5	$	157.9
Weighted Average Shares Outstanding (in millions)	48.1		44.4		46.4		43.6
Dilutive Effect of Restricted Stock, Restricted Stock Units, and Stock Options (in millions)*	0.1		0.2		0.2		0.2
Weighted Average Diluted Shares (in millions)	48.2		44.6		46.6		43.8
Diluted Earnings Per Share of Common Stock	$	0.45	$	0.24	$	3.75	$	3.60
* Calculation excludes certain outstanding shares (shown in millions by period at the right) attributable to stock units subject to performance or market conditions and restricted stock, which could have a dilutive effect in the future	0.4		0.5		0.4		0.5

Spire’s 2.875 million equity units issued in June 2014 were anti-dilutive for the three and nine months ended June 30, 2016; accordingly, they were excluded from the calculation of weighted average diluted shares for those periods. On April 3, 2017, Spire settled the purchase contracts underlying those equity units, by issuing approximately 2.5 million shares of its common stock.

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REGULATORY MATTERS

9 Months Ended

Jun. 30, 2017

Regulated Operations [Abstract]

REGULATORY MATTERS

REGULATORY MATTERS

As explained in Note 1, Summary of Significant Accounting Policies, Laclede Gas and Alagasco account for regulated operations in accordance with FASB ASC Topic 980, “Regulated Operations.” The following regulatory assets and regulatory liabilities, including purchased gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of June 30, 2017, September 30, 2016 and June 30, 2016.

	June 30,		September 30,		June 30,
Spire	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	41.7	$	27.0	$	26.9
Unamortized purchased gas adjustments	73.9		49.7		5.4
Other	29.0		17.2		10.6
Total Regulatory Assets (current)	144.6		93.9		42.9
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	453.4		487.9		434.4
Cost of removal	135.4		130.6		81.2
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	43.4		30.1		29.6
Total Regulatory Assets (non-current)	840.5		838.0		730.7
Total Regulatory Assets	$	985.1	$	931.9	$	773.6
Regulatory Liabilities:
Current:
Rate Stabilization and Equalization (RSE) adjustment	$	1.2	$	7.5	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Unamortized purchased gas adjustments	1.0		1.7		—
Other	9.5		6.2		3.8
Total Regulatory Liabilities (current)	25.9		30.6		22.4
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Accrued cost of removal	74.6		74.8		55.4
Other	34.1		17.6		13.8
Total Regulatory Liabilities (non-current)	139.8		130.7		105.7
Total Regulatory Liabilities	$	165.7	$	161.3	$	128.1

	June 30,		September 30,		June 30,
Laclede Gas	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	34.9	$	20.2	$	20.2
Unamortized purchased gas adjustments	29.0		43.1		0.6
Other	3.3		3.7		3.5
Total Regulatory Assets (current)	67.2		67.0		24.3
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	352.3		375.7		352.1
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	22.8		24.7		25.0
Total Regulatory Assets (non-current)	583.4		589.8		562.6
Total Regulatory Assets	$	650.6	$	656.8	$	586.9
Regulatory Liabilities:
Current:
Other	$	2.7	$	1.3	$	1.3
Total Regulatory Liabilities (current)	2.7		1.3		1.3
Non-current:
Accrued cost of removal	54.8		55.1		55.4
Other	28.8		12.2		10.3
Total Regulatory Liabilities (non-current)	83.6		67.3		65.7
Total Regulatory Liabilities	$	86.3	$	68.6	$	67.0

	June 30,		September 30,		June 30,
Alagasco	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	6.8	$	6.8	$	6.7
Unamortized purchased gas adjustments	44.9		5.6		4.8
Other	10.5		8.1		7.1
Total Regulatory Assets (current)	62.2		20.5		18.6
Non-current:
Pension and postretirement benefit costs	92.2		98.9		82.3
Cost of removal	135.4		130.6		81.2
Other	1.1		1.2		4.0
Total Regulatory Assets (non-current)	228.7		230.7		167.5
Total Regulatory Assets	$	290.9	$	251.2	$	186.1
Regulatory Liabilities:
Current:
RSE adjustment	$	1.2	$	5.0	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Other	2.4		2.5		2.5
Total Regulatory Liabilities (current)	17.8		22.7		21.1
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Other	3.3		3.4		3.5
Total Regulatory Liabilities (non-current)	34.4		41.7		40.0
Total Regulatory Liabilities	$	52.2	$	64.4	$	61.1

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

	Spire						Laclede Gas
	June 30,		September 30,		June 30,		June 30,		September 30,		June 30,
	2017		2016		2016		2017		2016		2016
Future income taxes due from customers	$	166.6	$	151.3	$	146.4	$	166.6	$	151.3	$	146.4
Pension and postretirement benefit costs	231.0		240.6		203.8		231.0		240.6		203.8
Other	11.4		12.9		13.2		11.4		12.9		13.2
Total Regulatory Assets Not Earning a Return	$	409.0	$	404.8	$	363.4	$	409.0	$	404.8	$	363.4

Like all the Company’s regulatory assets, these regulatory assets are expected to be recovered from customers in future rates. The recovery period for the future income taxes due from customers and pension and postretirement benefit costs could be as long as 20 years, based on current Internal Revenue Service guidelines and average remaining service life of active participants, respectively. The other items not earning a return are expected to be recovered over a period not to exceed 15 years, consistent with precedent set by the MoPSC. Alagasco does not have any regulatory assets that are not earning a return.

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FINANCING ARRANGEMENTS AND LONG-TERM DEBT

9 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

FINANCING ARRANGEMENTS AND LONG-TERM DEBT

FINANCING ARRANGEMENTS AND LONG-TERM DEBT

On December 14, 2016, Spire, Laclede Gas, and Alagasco entered into a new syndicated revolving credit facility pursuant to a loan agreement with 11 banks, expiring December 14, 2021. The largest portion provided by a single bank under the line is 12.3%. The loan agreement replaces Spire’s and Laclede Gas’ existing loan agreements dated as of September 3, 2013 and amended September 3, 2014, which were set to expire on September 3, 2019, and Alagasco’s existing loan agreement dated September 2, 2014, which was set to expire September 2, 2019. All three agreements were terminated on December 14, 2016.

The loan agreement has an aggregate credit commitment of $975.0, including sublimits of $300.0 for Spire, $475.0 for Laclede Gas, and $200.0 for Alagasco. These sublimits may be reallocated from time to time among the three borrowers within the $975.0 aggregate commitment. Spire may use its line to provide for the funding needs of various subsidiaries. Spire, Laclede Gas, and Alagasco expect to use the loan agreement for general corporate purposes, including short-term borrowings and letters of credit. The agreement also contains financial covenants limiting each borrower’s consolidated total debt, including short-term debt, to no more than 70% of its total capitalization. As defined in the line of credit, on June 30, 2017, total debt was 54% of total capitalization for the consolidated Company, 48% for Laclede Gas, and 29% for Alagasco.

On December 21, 2016, Spire established a commercial paper program (Program) pursuant to which Spire may issue short-term, unsecured commercial paper notes (Notes). Amounts available under the Program may be borrowed, repaid, and re-borrowed from time to time, with the aggregate face or principal amount of the Notes outstanding under the Program at any time not to exceed $975.0. The Notes may have maturities of up to 365 days from date of issue. The net proceeds of the issuances of the Notes are expected to be used for general corporate purposes, including to provide working capital for both utility and non-utility subsidiaries. As of June 30, 2017, Notes outstanding under the Program totaled $450.7. Of that amount, $260.2 and $114.9 were lent to Laclede Gas and Alagasco, respectively, at Spire’s cost.

On March 10, 2017, Spire redeemed in full at par its $250.0 floating rate notes due August 15, 2017, plus accrued and unpaid interest.

On March 15, 2017, Spire completed the issuance and sale of $100.0 in aggregate principal amount of Senior Notes due March 15, 2027. The notes bear interest at the rate of 3.93% per annum, payable semi-annually. The notes are senior unsecured obligations of the Company. Spire used the proceeds from the sale of the notes for the repayment of other debt.

In 2014, Spire issued 2.875 million equity units as a portion of the Alagasco acquisition financing. The equity units were originally issued at $50 per unit pursuant to the Purchase Contract and Pledge Agreement (purchase contract) dated as of June 11, 2014 between Spire and U.S. Bank National Association, as purchase contract agent, collateral agent, custodial agent and securities intermediary. These units consisted of $143.8 aggregate principal amount of 2014 Series A 2.00% remarketable junior subordinated notes due 2022 (the Junior Notes) and the purchase contract obligating the holder to purchase common shares at a future settlement date (set to be three years in the future and prior to the Junior Notes maturity). The equity unit investments were effectively replaced as planned in a series of transactions outlined below:

– On February 22, 2017, the selling securityholders (as defined below) agreed to purchase the Junior Notes in connection with the remarketing of the junior subordinated notes that comprised a component of the equity units.

– On the same day, Spire entered into two related agreements: (1) a Securities Purchase and Registration Rights Agreement (the SPRRA), among Spire and the several purchasers named therein (the selling securityholders), obligating the selling securityholders to sell the Junior Notes to Spire in exchange for $143.8 aggregate principal amount of Spire’s 3.543% Senior Notes due 2024 (the Senior Notes) and a cash payment, and (2) an underwriting agreement with the selling securityholders and the several underwriters named therein in connection with the public offering of $150.0 aggregate principal amount of Senior Notes consisting of $6.2 principal amount of the Senior Notes issued and sold by Spire and $143.8 principal amount of the Senior Notes sold by the selling securityholders. The SPRRA granted the selling securityholders the right to offer the Senior Notes to the public in secondary public offerings.

– The public offering was completed on February 27, 2017. Spire used its net proceeds from its sale of the Senior Notes to repay short-term debt. Spire did not receive any proceeds from the sale of the Senior Notes by the selling securityholders.

– On April 3, 2017, Spire settled the purchase contracts underlying its 2.875 million equity units by issuing approximately 2.5 million shares of its common stock at a purchase price of $57.3921 per share. Fractional shares were settled in cash at $67.50 per share. The purchase price was funded with the proceeds from the Junior Notes. Under the contract terms, the equity units were converted to common stock at the rate of 0.8712, with a corresponding adjustment to purchase price. Spire received net cash proceeds of approximately $142.0, which it used to repay short-term debt incurred the previous month to redeem the floating rate notes.

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FAIR VALUE OF FINANCIAL INSTRUMENTS

9 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts of cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. Refer to Note 6, Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis.

The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis are shown below and classified according to the fair value hierarchy. There were no such instruments classified as Level 3 (significant unobservable inputs) as of June 30, 2017, September 30, 2016, or June 30, 2016.

		Classification of Estimated Fair Value
Carrying Amount	Fair Value	Quoted Prices in Active Markets (Level 1)	Significant Observable Inputs (Level 2)

Spire

As of June 30, 2017
Cash and cash equivalents	$	8.3	$	8.3	$	8.3	$	—
Short-term debt	450.7		450.7		—		450.7
Long-term debt	1,925.3		2,033.0		—		2,033.0
As of September 30, 2016
Cash and cash equivalents	$	5.2	$	5.2	$	5.2	$	—
Short-term debt	398.7		398.7		—		398.7
Long-term debt, including current portion	2,070.7		2,257.1		—		2,257.1
As of June 30, 2016
Cash and cash equivalents	$	4.9	$	4.9	$	4.9	$	—
Short-term debt	97.6		97.6		—		97.6
Long-term debt	1,839.8		2,014.3		—		2,014.3

Laclede Gas

As of June 30, 2017
Cash and cash equivalents	$	2.6	$	2.6	$	2.6	$	—
Short-term debt	260.2		260.2		—		260.2
Long-term debt	804.5		883.9		—		883.9
As of September 30, 2016
Cash and cash equivalents	$	2.1	$	2.1	$	2.1	$	—
Short-term debt	243.7		243.7		—		243.7
Long-term debt	804.1		900.4		—		900.4
As of June 30, 2016
Cash and cash equivalents	$	1.5	$	1.5	$	1.5	$	—
Short-term debt	136.4		136.4		—		136.4
Long-term debt	803.9		901.8		—		901.8

					Classification of Estimated Fair Value
	Carrying Amount		Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)
Alagasco
As of June 30, 2017
Cash and cash equivalents	$	0.1	$	0.1	$	0.1	$	—
Short-term debt	114.9		114.9		—		114.9
Long-term debt	247.7		267.6		—		267.6
As of September 30, 2016
Short-term debt	$	82.0	$	82.0	$	—	$	82.0
Long-term debt	247.6		275.5		—		275.5
As of June 30, 2016
Short-term debt	$	37.8	$	37.8	$	—	$	37.8
Long-term debt	247.6		272.5		—		272.5

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FAIR VALUE MEASUREMENTS

9 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

The information presented below 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.

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

Derivative instruments included in Level 1 are valued using quoted market prices on the New York Mercantile Exchange (NYMEX) or the Intercontinental Exchange (ICE). Derivative instruments classified in Level 2 include physical commodity derivatives that are valued using Over-the-Counter Bulletin Board (OTCBB), broker, or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. Also included in Level 2 are certain derivative instruments that have values that are similar to, and correlate with, quoted prices for exchange-traded instruments in active markets and derivative instruments with settlement dates more than one year into the future. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. The Level 3 balances as of June 30, 2017, September 30, 2016 and June 30, 2016 consisted of gas commodity contracts. The Company’s and the Utilities’ policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer.

The mutual funds are included in “Other Investments” on the Company’s balance sheets and in “Other Property and Investments” on Laclede Gas’ balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exists between the Company, Laclede Gas, or Alagasco and the counterparty to a derivative contract.

Spire

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of June 30, 2017
ASSETS
Gas Utility
US stock/bond mutual funds	$	18.0	$	4.1		$	—	$	—		$	22.1
NYMEX/ICE natural gas contracts	1.9		—			—		(1.3		)	0.6
Gasoline and heating oil contracts	0.1		—			—		—			0.1
Subtotal	20.0		4.1			—		(1.3		)	22.8
Gas Marketing
NYMEX/ICE natural gas contracts	1.5		3.2			—		(2.6		)	2.1
Natural gas commodity contracts	—		6.1			0.6		(1.7		)	5.0
Total	$	21.5	$	13.4		$	0.6	$	(5.6	)	$	29.9
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	1.3	$	—		$	—	$	(1.3	)	$	—
Gas Marketing
NYMEX/ICE natural gas contracts	0.8		1.8			—		(2.6		)	—
Natural gas commodity contracts	—		6.7			—		(1.7		)	5.0
Other
Interest rate swaps	—		(0.6		)	—		—			(0.6		)
Total	$	2.1	$	7.9		$	—	$	(5.6	)	$	4.4

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of September 30, 2016
ASSETS
Gas Utility
US stock/bond mutual funds	$	16.8	$	4.1	$	—	$	—		$	20.9
NYMEX/ICE natural gas contracts	5.3		—		—		(0.4		)	4.9
NYMEX gasoline and heating oil contracts	0.4		—		—		(0.3		)	0.1
Subtotal	22.5		4.1		—		(0.7		)	25.9
Gas Marketing
NYMEX/ICE natural gas contracts	0.4		3.4		—		(3.4		)	0.4
Natural gas commodity contracts	—		8.7		0.2		(0.9		)	8.0
Total	$	22.9	$	16.2	$	0.2	$	(5.0	)	$	34.3
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	1.6	$	—	$	—	$	(1.6	)	$	—
OTCBB natural gas contracts	—		0.2		—		—			0.2
Subtotal	1.6		0.2		—		(1.6		)	0.2
Gas Marketing
NYMEX/ICE natural gas contracts	3.5		1.6		—		(5.1		)	—
Natural gas commodity contracts	—		2.6		—		(0.9		)	1.7
Other
Interest rate swaps	—		3.0		—		—			3.0
Total	$	5.1	$	7.4	$	—	$	(7.6	)	$	4.9
As of June 30, 2016
ASSETS
Gas Utility
US stock/bond mutual funds	$	16.4	$	4.0	$	—	$	—		$	20.4
NYMEX/ICE natural gas contracts	8.2		—		—		(3.1		)	5.1
Subtotal	24.6		4.0		—		(3.1		)	25.5
Gas Marketing
NYMEX/ICE natural gas contracts	0.6		5.5		—		(5.6		)	0.5
Natural gas commodity contracts	—		6.3		0.3		(0.6		)	6.0
Total	$	25.2	$	15.8	$	0.3	$	(9.3	)	$	32.0
LIABILITIES
Gas Utility
OTCBB natural gas contracts	$	—	$	0.6	$	—	$	—		$	0.6
Subtotal	—		0.6		—		—			0.6
Gas Marketing
NYMEX/ICE natural gas contracts	6.5		2.5		—		(9.0		)	—
Natural gas commodity contracts	—		3.4		—		(0.5		)	2.9
Other
Interest Rate Swaps	—		4.0		—		—			4.0
Total	$	6.5	$	10.5	$	—	$	(9.5	)	$	7.5

Laclede Gas

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of June 30, 2017
ASSETS
US stock/bond mutual funds	$	18.0	$	4.1	$	—	$	—		$	22.1
NYMEX/ICE natural gas contracts	1.9		—		—		(1.3		)	0.6
NYMEX gasoline and heating oil contracts	0.1		—		—		—			0.1
Total	$	20.0	$	4.1	$	—	$	(1.3	)	$	22.8
LIABILITIES
NYMEX/ICE natural gas contracts	$	1.3	$	—	$	—	$	(1.3	)	$	—
Total	$	1.3	$	—	$	—	$	(1.3	)	$	—

As of September 30, 2016
ASSETS
US stock/bond mutual funds	$	16.8	$	4.1	$	—	$	—		$	20.9
NYMEX/ICE natural gas contracts	5.3		—		—		(0.4		)	4.9
NYMEX gasoline and heating oil contracts	0.3		—		—		(0.3		)	—
Total	$	22.4	$	4.1	$	—	$	(0.7	)	$	25.8
LIABILITIES
NYMEX/ICE natural gas contracts	$	1.6	$	—	$	—	$	(1.6	)	$	—
OTCBB natural gas contracts	—		0.2		—		—			0.2
Total	$	1.6	$	0.2	$	—	$	(1.6	)	$	0.2

As of June 30, 2016
ASSETS
US stock/bond mutual funds	$	16.4	$	4.0	$	—	$	—		$	20.4
NYMEX/ICE natural gas contracts	8.2		—		—		(3.1		)	5.1
Total	$	24.6	$	4.0	$	—	$	(3.1	)	$	25.5
LIABILITIES
OTCBB natural gas contracts	$	—	$	0.6	$	—	$	—		$	0.6
Total	$	—	$	0.6	$	—	$	—		$	0.6

Alagasco

During the fiscal second quarter of 2016 Alagasco commenced a gasoline derivative program to stabilize the cost of fuel used in operations. As of June 30, 2017, September 30, 2016, and June 30, 2016, the fair value of related gasoline contracts was not significant.

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CONCENTRATIONS OF CREDIT RISK

9 Months Ended

Jun. 30, 2017

Risks and Uncertainties [Abstract]

CONCENTRATION OF CREDIT RISK

CONCENTRATIONS OF CREDIT RISK

Other than in Spire Marketing, Spire has no significant concentrations of credit risk.

A significant portion of Spire Marketing’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. The concentration of transactions with these counterparties has the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. To manage this risk, as well as credit risk from significant counterparties in these and other industries, Spire Marketing has established procedures to determine the creditworthiness of its counterparties. These procedures include obtaining credit ratings and credit reports, analyzing counterparty financial statements to assess financial condition, and considering the industry environment in which the counterparty operates. This information is monitored on an ongoing basis. In some instances, Spire Marketing may require credit assurances such as prepayments, letters of credit, or parental guarantees. In addition, Spire Marketing may enter into netting arrangements to mitigate credit risk with counterparties in the energy industry with whom it conducts both sales and purchases of natural gas. Sales are typically made on an unsecured credit basis with payment due the month following delivery. Accounts receivable amounts are closely monitored and provisions for uncollectible amounts are accrued when losses are probable. Spire Marketing records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in its accounts receivable attributable to energy producers and their marketing affiliates totaled $10.6 at June 30, 2017 ($5.6 reflecting netting arrangements). Spire Marketing’s accounts receivable attributable to utility companies and their marketing affiliates were $63.8 at June 30, 2017 ($60.0 reflecting netting arrangements).

Spire Marketing also has concentrations of credit risk with certain individually significant counterparties and with pipeline companies associated with its natural gas receivable amounts. At June 30, 2017, the amounts included in accounts receivable from its five largest counterparties (in terms of net accounts receivable exposure) totaled $30.7 ($29.0 reflecting netting arrangements). Four of these five counterparties are investment-grade rated companies. The fifth is not rated.

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

9 Months Ended

Jun. 30, 2017

Defined Contribution Plan [Abstract]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

Pension Plans

The pension plans of Spire consist of plans for employees at the Missouri Utilities, plans covering employees of Alagasco, and plans for employees of EnergySouth since September 12, 2016.

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

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

The net periodic pension cost included the following components:

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Spire
Service cost – benefits earned during the period	$	5.0		$	3.8		$	15.5		$	11.5
Interest cost on projected benefit obligation	7.0			6.9			20.8			21.0
Expected return on plan assets	(9.4		)	(8.6		)	(29.0		)	(26.3		)
Amortization of prior service cost	0.2			0.1			0.7			0.3
Amortization of actuarial loss	3.0			1.9			9.6			5.9
Loss on lump-sum settlements	—			0.2			11.9			2.4
Special termination benefits	—			—			—			1.6
Subtotal	5.8			4.3			29.5			16.4
Regulatory adjustment	3.1			4.4			0.3			11.1
Net pension cost	$	8.9		$	8.7		$	29.8		$	27.5

Laclede Gas
Service cost – benefits earned during the period	$	3.0		$	2.5		$	9.6		$	7.5
Interest cost on projected benefit obligation	4.8			5.4			14.5			16.2
Expected return on plan assets	(6.8		)	(6.7		)	(21.2		)	(20.1		)
Amortization of prior service cost	0.2			0.1			0.7			0.3
Amortization of actuarial loss	2.5			1.9			8.2			5.9
Loss on lump-sum settlements	—			—			11.5			—
Special termination benefits	—			—			—			1.6
Subtotal	3.7			3.2			23.3			11.4
Regulatory adjustment	1.3			3.0			(4.5		)	8.8
Net pension cost	$	5.0		$	6.2		$	18.8		$	20.2

Alagasco
Service cost – benefits earned during the period	$	1.6		$	1.3		$	4.7		$	4.0
Interest cost on projected benefit obligation	1.6			1.5			4.6			4.8
Expected return on plan assets	(1.8		)	(1.9		)	(5.4		)	(6.2		)
Amortization of actuarial loss	0.5			—			1.4			—
Loss on lump-sum settlements	—			0.2			0.4			2.4
Subtotal	1.9			1.1			5.7			5.0
Regulatory adjustment	1.6			1.4			4.3			2.3
Net pension cost	$	3.5		$	2.5		$	10.0		$	7.3

Pursuant to the provisions of the Missouri Utilities’ and Alagasco’s pension plans, pension obligations may be satisfied by monthly annuities, lump-sum cash payments, or special termination benefits. Lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs in a specific year. Special termination benefits, when offered, are also recognized as settlements which can result in gains or losses. In the quarter ended March 31, 2017, the Laclede Gas plan and one of the Alagasco plans met the criteria for settlement recognition, resulting in the remeasurement of the obligation of the plans using updated census data and assumptions for discount and mortality. The total lump-sum payments recognized as settlements for plan remeasurement were $36.3 and $1.9 for the Laclede plan and Alagasco plan, respectively. The lump-sum settlements resulted in losses of $11.5 and $0.4 for the Laclede plan and Alagasco plan, respectively. In the quarters ended March 31 and June 30, 2016, an Alagasco plan met the criteria for settlement recognition. The lump-sum payments recognized as settlements for the Alagasco remeasurements totaled $12.6. The lump-sum settlement resulted in a loss of $2.2 and $0.2 in the quarters ended March 31 and June 30, 2016, respectively. In the quarter ended December 31, 2015, the Laclede Gas pension plans provided qualified employees with voluntary early retirement packages that qualified as special termination benefits, resulting in a charge of $1.6. All gains and losses on lump-sum settlements were recorded with a regulatory adjustment and did not impact income.

The funding policy of the Utilities is to contribute an amount not less than the minimum required by government funding standards, nor more than the maximum deductible amount for federal income tax purposes. Fiscal year 2017 contributions to Laclede Gas’ pension plans through June 30, 2017 were $22.5 to the qualified trusts and $0.2 to non-qualified plans. There were no fiscal 2017 contributions to the Alagasco pension plans through June 30, 2017.

Contributions to the Missouri Utilities’ pension plans for the remainder of fiscal 2017 are anticipated to be $6.5 to the qualified trusts and $0.4 to the non-qualified plans. No contributions to Alagasco’s pension plans are expected to be required for the remainder of fiscal 2017, but a voluntary contribution is likely in September.

Postretirement Benefits

The Utilities provide certain life insurance benefits at retirement. Laclede Gas plans provide for medical insurance after early retirement until age 65. For retirements prior to January 1, 2015, the MGE plans provided medical insurance after retirement until death. For retirements after January 1, 2015, the MGE plans provide medical insurance after early retirement until age 65. Under the Alagasco plans, medical insurance is currently available upon retirement until death for certain retirees depending on the type of employee and the date the employee was originally hired.

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

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Spire
Service cost – benefits earned during the period	$	2.7		$	2.7		$	8.2		$	8.2
Interest cost on accumulated postretirement benefit obligation	2.2			2.6			6.5			7.6
Expected return on plan assets	(3.5		)	(3.3		)	(10.3		)	(10.1		)
Amortization of prior service credit	—			0.1			—			0.2
Amortization of actuarial loss	0.6			0.9			1.8			2.7
Special termination benefits	—			—			—			2.6
Subtotal	2.0			3.0			6.2			11.2
Regulatory adjustment	(0.8		)	(1.7		)	(2.4		)	(7.6		)
Net postretirement benefit cost	$	1.2		$	1.3		$	3.8		$	3.6

Laclede Gas
Service cost – benefits earned during the period	$	2.6		$	2.6		$	7.8		$	7.9
Interest cost on accumulated postretirement benefit obligation	1.7			2.1			5.1			6.1
Expected return on plan assets	(2.3		)	(2.1		)	(6.8		)	(6.4		)
Amortization of prior service credit	0.1			0.1			0.2			0.2
Amortization of actuarial loss	0.6			1.0			1.9			2.9
Special termination benefits	—			—			—			2.6
Subtotal	2.7			3.7			8.2			13.3
Regulatory adjustment	(0.4		)	(1.2		)	(1.1		)	(6.2		)
Net postretirement benefit cost	$	2.3		$	2.5		$	7.1		$	7.1

Alagasco
Service cost – benefits earned during the period	$	—		$	0.1		$	0.2		$	0.3
Interest cost on accumulated postretirement benefit obligation	0.4			0.5			1.2			1.5
Expected return on plan assets	(1.1		)	(1.2		)	(3.3		)	(3.7		)
Amortization of prior service credit	(0.1		)	—			(0.2		)	—
Amortization of actuarial gain	—			(0.1		)	(0.1		)	(0.2		)
Subtotal	(0.8		)	(0.7		)	(2.2		)	(2.1		)
Regulatory adjustment	(0.5		)	(0.5		)	(1.4		)	(1.4		)
Net postretirement benefit income	$	(1.3	)	$	(1.2	)	$	(3.6	)	$	(3.5	)

Missouri and Alabama state law provide for the recovery in rates of costs accrued pursuant to GAAP provided that such costs are funded through an independent, external funding mechanism. The Utilities have established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi Trusts as external funding mechanisms. The assets of the VEBA and Rabbi Trusts consist primarily of money market securities and mutual funds invested in stocks and bonds. During the quarter ended December 31, 2015, the Laclede Gas postretirement plan offered qualified employees voluntary enhanced early retirement packages that resulted in a special termination benefits charge of $2.6.

The Utilities’ funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. Year-to-date contributions to the postretirement plans through June 30, 2017 totaled $8.8 for the Missouri Utilities. Contributions to the postretirement plans for the remainder of fiscal year 2017 are anticipated to be $5.1 to the qualified trusts and $0.4 paid directly to participants from the Missouri Utilities’ funds. For Alagasco, there were no contributions to the postretirement plans during the nine months of fiscal year 2017, and none are expected to be required for the remainder of the fiscal year.

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INFORMATION BY OPERATING SEGMENT

9 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

INFORMATION BY OPERATING SEGMENT

INFORMATION BY OPERATING SEGMENT

The Company has two reportable segments: Gas Utility and Gas Marketing. The Gas Utility segment is the aggregation of the regulated operations of the Utilities. The Gas Marketing segment includes the results of Spire Marketing, a subsidiary engaged in the non-regulated marketing of natural gas and related activities, including utilizing natural gas storage contracts for providing natural gas sales. In addition, other non-utility activities of the Company include:

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

• Spire STL Pipeline LLC, a subsidiary of Spire planning construction of a proposed 65-mile Federal Energy Regulatory Commission (FERC)-regulated pipeline to deliver natural gas into eastern Missouri; and

• Spire’s subsidiaries engaged in the operation of a propane pipeline, compression of natural gas and risk management, among other activities. All subsidiaries are wholly owned.

Accounting policies are described in Note 1, Summary of Significant Accounting Policies. Intersegment transactions include sales of natural gas from Spire Marketing to Laclede Gas and from Laclede Gas to Spire Marketing, insurance services provided by Laclede Insurance Risk Services to Laclede Gas and Alagasco, and propane transportation services provided by Laclede Pipeline Company to Laclede Gas.

Management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impacts of net unrealized gains and losses and other timing differences associated with energy-related transactions. Net economic earnings also exclude the after-tax impacts related to acquisition, divestiture, and restructuring activities.

	Gas Utility		Gas Marketing			Other			Eliminations			Consolidated
Three Months Ended June 30, 2017
Operating Revenues:
Revenues from external customers	$	305.1	$	17.9		$	0.5		$	—		$	323.5
Intersegment revenues	1.5		—			1.6			(3.1		)	—
Total Operating Revenues	306.6		17.9			2.1			(3.1		)	323.5
Operating Expenses:
Gas Utility
Natural and propane gas	88.7		—			—			(12.0		)	76.7
Operation and maintenance	101.9		—			—			(1.1		)	100.8
Depreciation and amortization	38.4		—			—			—			38.4
Taxes, other than income taxes	30.5		—			—			—			30.5
Total Gas Utility Operating Expenses	259.5		—			—			(13.1		)	246.4
Gas Marketing and Other	—		12.0			4.8			10.0			26.8
Total Operating Expenses	259.5		12.0			4.8			(3.1		)	273.2
Operating Income (Loss)	$	47.1	$	5.9		$	(2.7	)	$	—		$	50.3
Net Economic Earnings (Loss)	$	23.3	$	2.3		$	(4.0	)	$	—		$	21.6
Three Months Ended June 30, 2016
Operating Revenues:
Revenues from external customers	$	253.2	$	(4.3	)	$	0.4		$	—		$	249.3
Intersegment revenues	0.1		6.6			0.5			(7.2		)	—
Total Operating Revenues	253.3		2.3			0.9			(7.2		)	249.3
Operating Expenses:
Gas Utility
Natural and propane gas	61.1		—			—			(7.0		)	54.1
Operation and maintenance	91.9		—			—			(0.1		)	91.8
Depreciation and amortization	34.2		—			—			—			34.2
Taxes, other than income taxes	27.4		—			—			—			27.4
Total Gas Utility Operating Expenses	214.6		—			—			(7.1		)	207.5
Gas Marketing and Other	—		3.9			2.7			(0.1		)	6.5
Total Operating Expenses	214.6		3.9			2.7			(7.2		)	214.0
Operating Income (Loss)	$	38.7	$	(1.6	)	$	(1.8	)	$	—		$	35.3
Net Economic Earnings (Loss)	$	18.0	$	1.8		$	(5.2	)	$	—		$	14.6

	Gas Utility		Gas Marketing			Other			Eliminations			Consolidated
Nine Months Ended June 30, 2017
Operating Revenues:
Revenues from external customers	$	1,419.1	$	61.8		$	1.1		$	—		$	1,482.0
Intersegment revenues	7.9		—			4.6			(12.5		)	—
Total Operating Revenues	1,427.0		61.8			5.7			(12.5		)	1,482.0
Operating Expenses:
Gas Utility
Natural and propane gas	578.8		—			—			(54.0		)	524.8
Operation and maintenance	301.7		—			—			(3.1		)	298.6
Depreciation and amortization	114.0		—			—			—			114.0
Taxes, other than income taxes	112.2		—			—			—			112.2
Total Gas Utility Operating Expenses	1,106.7		—			—			(57.1		)	1,049.6
Gas Marketing and Other	—		58.9			9.1			44.6			112.6
Total Operating Expenses	1,106.7		58.9			9.1			(12.5		)	1,162.2
Operating Income (Loss)	$	320.3	$	2.9		$	(3.4	)	$	—		$	319.8
Net Economic Earnings (Loss)	$	187.3	$	3.7		$	(12.9	)	$	—		$	178.1
Nine Months Ended June 30, 2016
Operating Revenues:
Revenues from external customers	$	1,263.5	$	(6.7	)	$	1.2		$	—		$	1,258.0
Intersegment revenues	2.0		29.8			1.4			(33.2		)	—
Total Operating Revenues	1,265.5		23.1			2.6			(33.2		)	1,258.0
Operating Expenses:
Gas Utility
Natural and propane gas	496.0		—			—			(32.3		)	463.7
Operation and maintenance	278.4		—			—			(0.7		)	277.7
Depreciation and amortization	101.5		—			—			—			101.5
Taxes, other than income taxes	99.5		—			—			—			99.5
Total Gas Utility Operating Expenses	975.4		—			—			(33.0		)	942.4
Gas Marketing and Other	—		18.4			7.4			(0.2		)	25.6
Total Operating Expenses	975.4		18.4			7.4			(33.2		)	968.0
Operating Income (Loss)	$	290.1	$	4.7		$	(4.8	)	$	—		$	290.0
Net Economic Earnings (Loss)	$	170.5	$	4.5		$	(11.8	)	$	—		$	163.2

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

	June 30,			September 30,			June 30,
	2017			2016			2016
Total Assets:
Gas Utility	$	5,323.1		$	5,184.7		$	4,646.9
Gas Marketing	223.6			205.0			167.8
Other	2,171.8			1,836.6			1,592.6
Eliminations	(1,420.3		)	(1,161.9		)	(1,108.3		)
Total Assets	$	6,298.2		$	6,064.4		$	5,299.0

The following table reconciles the Company’s net economic earnings to net income.

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Net Income	$	21.7		$	10.7		$	174.9		$	158.4
Adjustments, pre-tax:
Unrealized (gain) loss on energy-related derivative contracts	(2.2		)	4.9			3.2			2.9
Lower of cost or market inventory adjustments	—			(0.1		)	—			0.6
Realized gain on economic hedges prior to sale of the physical commodity	—			(0.3		)	(0.2		)	(0.9		)
Acquisition, divestiture and restructuring activities	1.9			1.8			2.1			5.1
Income tax effect of adjustments	0.2			(2.4		)	(1.9		)	(2.9		)
Net Economic Earnings	$	21.6		$	14.6		$	178.1		$	163.2

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COMMITMENTS AND CONTINGENCIES

9 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

Commitments

The Company and the Utilities have entered into contracts with various counterparties, expiring on dates through 2031, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at June 30, 2017 are estimated at approximately $1,311.6, $518.7, and $296.5 for the Company, Laclede Gas, and Alagasco, respectively. Additional contracts are generally entered into prior to or during the heating season of November through April. The Utilities recover their costs from customers in accordance with their PGA clauses or GSA riders.

Contingencies

The Company and Utilities account for environmental liabilities and other contingencies in accordance with accounting standards under the loss contingency guidance of ASC Topic 450, “Contingencies,” when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated.

The Company and the Utilities own and operate natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Utilities’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, the Company or the Utilities may incur additional environmental liabilities that may result in additional costs, which may be material.

In addition to matters noted below, the Company, Laclede Gas, and Alagasco are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome will not have a material effect on the consolidated statements of income, balance sheets, and statements of cash flows of the Company, Laclede Gas, or Alagasco. However, there is uncertainty in the valuation of pending claims and prediction of litigation results.

In the natural gas industry, many gas distribution companies have incurred environmental liabilities associated with sites they or their predecessor companies formerly owned or operated where manufactured gas operations took place. The Utilities each have former manufactured gas plant (MGP) operations in their respective service territories.

Laclede Gas

Laclede Gas has identified four former MGP sites in eastern Missouri where costs have been incurred and claims have been asserted: one in Shrewsbury, Missouri and three in the city of St. Louis, Missouri (City). Laclede Gas has enrolled two of the sites in the City in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP). The third site in the City is the result of a new claim assertion by the United States Environmental Protection Agency (EPA) and such claim is currently being investigated. In Laclede Gas’ western service area, MGE has enrolled all of its owned former MGP sites in the BVCP.

With regard to the former MGP site located in Shrewsbury, Missouri, Laclede Gas and state and federal environmental regulators agreed upon certain remedial actions to a portion of the site in a 1999 Administrative Order on Consent (AOC), which actions have been completed. On September 22, 2008, the EPA Region VII issued a letter of Termination and Satisfaction terminating the AOC. However, if after this termination of the AOC, regulators require additional remedial actions, or additional claims are asserted, Laclede Gas may incur additional costs.

In conjunction with redevelopment of one of the sites located in the City, Laclede Gas and another former owner of the site entered into an agreement (Remediation Agreement) with the City development agencies, the developer, and an environmental consultant that obligates one of the City agencies and the environmental consultant to remediate the site and obtain a No Further Action letter from the Missouri Department of Natural Resources (MDNR). The Remediation Agreement also provides for a release of Laclede Gas and the other former site owner from certain liabilities related to the past and current environmental condition of the site and requires the developer and the environmental consultant to maintain certain insurance coverage, including remediation cost containment, premises pollution liability, and professional liability. The operative provisions of the Remediation Agreement were triggered on December 20, 2010, on which date Laclede Gas and the other former site owner, as full consideration under the Remediation Agreement, paid a small percentage of the cost of remediation of the site. The amount paid by Laclede Gas did not materially impact the financial condition, results of operations, or cash flows of the Company.

Laclede Gas has not owned the second site located in the City for many years. In a letter dated June 29, 2011, the Attorney General for the state of Missouri informed Laclede Gas that the MDNR had completed an investigation of the site. The Attorney General requested that Laclede Gas participate in the follow up investigations of the site. In a letter dated January 10, 2012, Laclede Gas stated that it would participate in future environmental response activities at the site in conjunction with other potentially responsible parties (PRPs) that are willing to contribute to such efforts in a meaningful and equitable fashion. Accordingly, Laclede Gas entered into a cost sharing agreement for remedial investigation with other PRPs. Pending MDNR approval, which has not occurred to date, the remedial investigation of the site will begin.

Additionally, in correspondence dated November 30, 2016, Region 7 of the EPA has asserted that Laclede Gas is liable under Section 107(a) of the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (CERCLA) for alleged coal gas waste contamination at a third site in the northern portion of the City on which Laclede Gas operated a MGP. Laclede Gas has not owned or operated the site (also known as Station “B”) for over 70 years. Laclede Gas and the site owner have met with the EPA and reviewed its assertions. Both Laclede and the site owner have notified EPA that the information and data provided by EPA to date does not rise to the level of documenting a threat to the public health or environment. As such, Laclede Gas is requesting more information from the EPA, some of which will also be utilized to identify other former owners and operators of the site that could be added as PRPs. To date, Laclede has not received a response from the EPA.

Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the MGP sites. While some of the insurers have denied coverage and reserved their rights, Laclede Gas continues to discuss potential reimbursements with them.

On March 10, 2015, Laclede Gas received a Section 104(e) information request from EPA Region 7 regarding the former Thompson Chemical/Superior Solvents site in the City. In turn, Laclede Gas issued a Freedom of Information Act (FOIA) request to the EPA on April 3, 2015, in an effort to identify the basis of the inquiry. The FOIA response from the EPA was received on July 15, 2015 and a response was provided to the EPA on August 15, 2015. Laclede Gas has received no further inquiry from the EPA regarding this matter.

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 area, Kansas City Coal Gas Station A North, Kansas City Coal Gas Station A South, and Independence MGP #2. Source removal has been conducted at all of the owned sites since 2003 with the exception of Joplin. On September 15, 2016, a request was made with the MDNR for a restrictive covenant use limitation with respect to Joplin. Remediation efforts at the seven sites are at various stages of completion, ranging from groundwater monitoring and sampling following source removal activities to the aforementioned request in respect to Joplin. As part of its participation in the BVCP, MGE communicates regularly with the MDNR with respect to its remediation efforts and monitoring activities at these sites. On May 11, 2015, MDNR approved the next phase of investigation at the Kansas City Station A North and Railroad areas.

To date, costs incurred for all Missouri Utilities’ MGP sites for investigation, remediation and monitoring these sites have not been material. However, the amount of costs relative to future remedial actions at these and other sites is unknown and may be material. The actual future costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remediation actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and government regulations, the ultimate ability of other PRPs to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries.

In 2013, Laclede Gas retained an outside consultant to conduct probabilistic cost modeling of 19 former MGP sites owned or operated by Laclede Gas in eastern Missouri or MGE in western Missouri. The purpose of this analysis was to develop an estimated range of probabilistic future liability for each site. That analysis, completed in August 2014, provided a range of demonstrated possible future expenditures to investigate, monitor and remediate all 19 MGP sites. Laclede Gas has recorded its best estimate of the probable expenditures that relate to these matters. The amount is not material.

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

Alagasco

Alagasco is in the chain of title of nine former MGP sites, four of which it still owns, and five former manufactured gas distribution sites, one of which it still owns. As of June 30, 2017, Alagasco does not foresee a probable or reasonably estimable loss associated with these nine former MGP sites. Alagasco and the Company do not expect potential liabilities that may arise from remediating these sites to have a material impact on their future financial condition or results of operations.

In 2012, Alagasco responded to an EPA Request for Information Pursuant to Section 104 of CERCLA relating to the 35th Avenue Superfund Site located in North Birmingham, Jefferson County, Alabama. Alagasco was identified as a PRP under CERCLA for the cleanup of the site or costs the EPA incurs in cleaning up the site. At this point, Alagasco has not been provided information that would allow it to determine the extent, if any, of its potential liability with respect to the 35th Avenue Superfund Site and vigorously denies its inclusion as a PRP.

On December 17, 2013, an incident occurred at a Housing Authority apartment complex in Birmingham, Alabama that resulted in one fatality, personal injuries and property damage. Alagasco cooperated with the National Transportation Safety Board (NTSB) which investigated the incident. The NTSB report of findings was issued on March 30, 2016 and no safety recommendations, fines, or penalties were contained therein. Alagasco has been named as a defendant in several lawsuits arising from the incident, and additional lawsuits and claims may be filed against Alagasco.

Mobile Gas

Mobile Gas is in the chain of title of one former MGP site which it still owns in Mobile, Alabama. On September 15, 2010, Mobile Gas filed an application to enroll the site into the Alabama Department of Environmental Management’s (ADEM) Voluntary Cleanup Program (VCP). This application was accepted by ADEM on November 16, 2010. Investigation and testing have been completed. Mobile Gas received an approved remediation plan from ADEM and the remedial actions taken under the plan were completed by June 30, 2017. Mobile Gas and the Company do not expect potential liabilities that may arise from remediating this site to have a material impact on their future financial condition or results of operations.

Since April 2012, a total of 14 lawsuits have been filed against Mobile Gas in Mobile County Circuit Court alleging that in the first half of 2008, Mobile Gas spilled tert-butyl mercaptan, an odorant added to natural gas for safety reasons, in Eight Mile, Alabama. Eleven of the lawsuits have been settled. The remaining three lawsuits, which include approximately 270 individual plaintiffs, allege nuisance, fraud and negligence causes of actions, and seek unspecified compensatory and punitive damages. A claim has been made against the insurance carriers requesting reimbursement for costs accrued in respect to this spill, and a related receivable has been recorded. The Company does not expect potential liabilities that may arise from these lawsuits to have a material impact on its future financial condition or results of operations.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

BASIS OF PRESENTATION

BASIS OF PRESENTATION –These notes are an integral part of the accompanying unaudited financial statements of Spire Inc. (Spire or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Laclede Gas, Alagasco and the subsidiaries of EnergySouth, Inc. (EnergySouth) are collectively referred to as the Utilities. The subsidiaries of EnergySouth are Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas & Oil Company (Willmut Gas).

The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial information with the instructions to Form 10-Q and Rule 10-01 of Regulation S‑X. Accordingly, they do not include all of the disclosures required for complete financial statements. In the opinion of management, the accompanying unaudited financial statements include all adjustments (consisting of only normal recurring adjustments) necessary for the fair presentation of the results of operations for the periods presented. This Form 10-Q should be read in conjunction with the Notes to Financial Statements contained in Spire’s, Laclede Gas’, and Alagasco’s Annual Reports on Form 10-K for the fiscal year ended September 30, 2016.

The consolidated financial position, results of operations, and cash flows of Spire are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between Laclede Gas and Alagasco and their affiliates, as well as intercompany balances on their balance sheets, have not been eliminated from their separate financial statements. Results of operations of EnergySouth are included in Spire’s results of operations since the September 12, 2016 acquisition and impact the comparability of financial statement periods presented for the Company.

GOODWILL

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

REVENUE RECOGNITION

REVENUE RECOGNITION – The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues for Laclede Gas at June 30, 2017, September 30, 2016, and June 30, 2016 were $31.9, $26.1, and $28.5, respectively.

Alagasco records natural gas distribution revenues in accordance with the tariff established by the Alabama Public Service Commission (APSC). Unbilled revenues for Alagasco, which are not recorded as revenue until billed, at June 30, 2017, September 30, 2016, and June 30, 2016 were $6.0, $5.9, and $6.4, respectively.

The subsidiaries of EnergySouth record natural gas revenues in accordance with tariffs established by the APSC and the Mississippi Public Service Commission (MSPSC). Their unbilled revenues are accrued as described for Laclede Gas above.

Spire’s other subsidiaries, including Spire Marketing, record revenues when earned, either when the product is delivered or when services are performed.

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

GROSS RECEIPTS TAXES

GROSS RECEIPTS TAXES – Gross receipts taxes associated with the Company’s natural gas utility services are imposed on the Utilities and billed to their customers. The revenue and expense amounts are recorded gross in the “Operating Revenues” and “Taxes, other than income taxes” lines, respectively, in the statements of income.

REGULATED OPERATIONS

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

As authorized by the Missouri Public Service Commission (MoPSC), MSPSC and APSC, the Purchased Gas Adjustment (PGA) clauses and Gas Supply Adjustment (GSA) riders allow the Utilities to pass through to customers the cost of purchased gas supplies. Regulatory assets and liabilities related to the PGA clauses and the GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. See additional information about regulatory assets and liabilities in Note 3, Regulatory Matters.

NEW ACCOUNTING PRONOUNCEMENTS

NEW ACCOUNTING PRONOUNCEMENTS – In April 2015, the FASB issued Accounting Standards Update (ASU) No. 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs. Under prior GAAP, debt issuance costs were recorded as a deferred charge (asset), while debt discount and debt premium costs were recorded as a liability adjustment. This amendment requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Spire, Laclede Gas and Alagasco adopted this ASU as of December 31, 2016. Retrospective adjustments have been made to the previous year balance sheets as of September 30, 2016 and June 30, 2016. The amounts reclassified from other deferred charges to reduce long-term debt are shown in the following table. The ASU does not address the presentation of debt issuance costs related to line-of-credit arrangements, and those continue to be reported as deferred charges.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	14.9	$	13.0	$	11.9
Laclede Gas	4.0		4.2		4.4
Alagasco	2.3		2.4		2.4

In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation: Improvements to Employee Share-Based Payment Accounting. The standard is intended to simplify several areas of accounting for share-based compensation arrangements, including the income tax impact, classification on the statement of cash flows and forfeitures. Spire, Laclede Gas and Alagasco adopted this ASU in the interim quarterly reporting period ended June 30, 2017. Amendments related to the timing of when excess tax benefits are recognized, minimum statutory withholding requirements, and forfeitures were applied using a modified retrospective transition method by means of a cumulative-effect adjustment to retained earnings as of October 1, 2016, and amendments requiring recognition of excess tax benefits and tax deficiencies in the income statement were applied prospectively as of that date. Amendments related to the presentation of excess tax benefits on the statement of cash flows and the presentation of employee taxes paid on the statement of cash flows when an employer withholds shares to meet the minimum statutory withholding requirement were applied retrospectively. There were no material impacts on the financial statements of the Company, Laclede Gas, or Alagasco, all of which adopted a policy of accounting for forfeitures when they occur.

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers. Under the new standard, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. In doing so, companies may need to use more judgment and make more estimates than under current guidance. ASU No. 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. Entities have the option of using either a full retrospective or modified retrospective approach to adopting this guidance. In August 2015, the FASB issued ASU No. 2015-14, which made the guidance in ASU No. 2014-09 effective for fiscal years beginning after December 15, 2017 and interim periods within those years. In 2016, the FASB issued related ASU Nos. 2016-08, 2016-10, 2016-11, 2016-12, and 2016-20 which further modified the standards for accounting for revenue. The Company, Laclede Gas and Alagasco are currently evaluating their sources of revenue and related contracts, the available transition methods, and the potential impacts of the updates. The conclusions of these assessments are contingent, in part, upon the completion of deliberations currently in progress by the power and utilities industry, notably in connection with efforts to produce an accounting guide being developed by the American Institute of Certified Public Accountants (AICPA). In association with this undertaking, the AICPA formed a number of industry task forces, including a Power & Utilities Task Force. Industry representatives and organizations, the largest auditing firms, the AICPA’s Revenue Recognition Working Group and its Financial Reporting Executive Committee have undertaken, and continue to undertake, consideration of several items relevant to our industry as further discussed below. Where applicable or necessary, the FASB’s Transition Resource Group is also participating. Currently, the industry is working to finalize conclusions in several areas including 1) the accounting for funds received from third parties to partially or fully reimburse the cost of construction of an asset, 2) determination of stand-alone selling price for commodities, and 3) the accounting for alternative revenue programs, such as performance-based ratemaking. Existing alternative revenue program guidance, though excluded by the FASB in updating specific guidance associated with revenue from contracts with customers, was relocated without substantial modification to accounting guidance for rate-regulated entities. It will require separate presentation of such revenues (subject to the above-noted deliberations) in the statement of income. Pending the completion of the industry deliberations and internal assessments later this year, the Company, Laclede Gas and Alagasco are currently unable to determine the effect the new guidance will have on their financial position, results of operations, cash flows, and business processes or the transition method they will utilize to adopt the new guidance in the first quarter of fiscal year 2019 (or earlier).

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments – Overall: Recognition and Measurement of Financial Assets and Financial Liabilities, which provides revised guidance concerning certain matters involving the recognition, measurement, and disclosure of financial instruments. It is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. Unrealized gains and losses on equity securities previously classified as available-for-sale will be recognized immediately in earnings rather than recorded in other comprehensive income. Entities will record a cumulative-effect adjustment as of the beginning of the fiscal year in which the guidance is adopted, which requires amounts reported in accumulated other comprehensive income for such equity securities to be reclassified to retained earnings. Based on an assessment of their current financial instruments, the Company, Laclede Gas and Alagasco expect to adopt this standard in the first quarter of fiscal year 2019 with no significant impact.

In February 2016, the FASB issued ASU No. 2016-02, Leases. The new standard requires lessees to recognize a right-of-use asset and lease liability for almost all lease contracts based on the present value of lease payments. There is an exemption for short-term leases. The ASU provides new guidelines for identifying and classifying a lease, and classification affects the pattern and income statement line item for the related expense. This update will be applied using a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The ASU is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2020.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses: Measurement of Credit Losses on Financial Instruments. The standard introduces new guidance for the accounting for credit losses on instruments within its scope, including trade receivables. It is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years, and may be adopted a year earlier. The new guidance will be initially applied through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2021.

In March 2017, the FASB issued ASU No. 2017-07, Compensation – Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amended guidance requires that the service cost component of pension and postretirement benefit costs be presented within the same line item in the income statement as other compensation costs (except for the amount being capitalized), while other components are to be presented outside the subtotal of operating income and are no longer eligible for capitalization. The ASU is effective for annual periods beginning after December 15, 2017, including interim periods within those annual periods. The amended guidance will be applied retrospectively for income statement presentation and prospectively for capitalization. The Company, Laclede Gas and Alagasco are currently assessing the regulatory and other impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2019.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

9 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

Schedule of goodwill by reportable segment

The changes in the carrying amount of goodwill by reportable segment are shown below, reflecting the effect of a $3.8 cash payment to Spire related to the EnergySouth acquisition, offset by net adjustments to acquired insurance receivable and prepaid assets.

	Gas Utility		Gas Marketing		Other			Total
Balance as of September 30, 2016	$	210.2	$	—	$	954.7		$	1,164.9
Adjustments related to the acquisition of EnergySouth	—		—		(1.0		)	(1.0		)
Balance as of June 30, 2017	$	210.2	$	—	$	953.7		$	1,163.9

Schedule of gross receipts taxes

The following table presents gross receipts taxes recorded as revenues.

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Spire	$	18.0	$	14.8	$	71.7	$	65.0
Laclede Gas	12.4		11.1		52.0		49.7
Alagasco	4.2		3.7		16.1		15.3

Schedule of inter-company transactions

Laclede Gas’ and Alagasco’s other transactions with affiliates included:

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Laclede Gas
Purchases of natural gas from Spire Marketing	$	11.8	$	6.7	$	53.3	$	31.5
Sales of natural gas to Spire Marketing	1.5		—		7.8		1.7
Insurance services received from Laclede Insurance Risk Services	0.5		0.2		1.6		0.7
Transportation services received from Laclede Pipeline Company	0.3		0.3		0.8		0.8
Alagasco
Insurance services received from Laclede Insurance Risk Services	0.5		—		1.5		—

Schedule of Capital Expenditure Excluded from Statement of Cash Flow

Accrued capital expenditures, shown in the following table, are excluded from capital expenditures in the statements of cash flows.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	26.5	$	21.6	$	9.9
Laclede Gas	16.5		14.8		5.3
Alagasco	7.9		6.8		4.6

Schedule of New Accounting Pronouncements and Changes in Accounting Principles

The ASU does not address the presentation of debt issuance costs related to line-of-credit arrangements, and those continue to be reported as deferred charges.

	June 30,		September 30,		June 30,
	2017		2016		2016
Spire	$	14.9	$	13.0	$	11.9
Laclede Gas	4.0		4.2		4.4
Alagasco	2.3		2.4		2.4

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EARNINGS PER COMMON SHARE (Tables)

9 Months Ended

Jun. 30, 2017

Earnings Per Share [Abstract]

Earnings Per Common Share

	Three Months Ended June 30,				Nine Months Ended June 30,
	2017		2016		2017		2016
Basic EPS:
Net Income	$	21.7	$	10.7	$	174.9	$	158.4
Less: Income allocated to participating securities	0.1		—		0.4		0.5
Net Income Available to Common Shareholders	$	21.6	$	10.7	$	174.5	$	157.9
Weighted Average Shares Outstanding (in millions)	48.1		44.4		46.4		43.6
Basic Earnings Per Share of Common Stock	$	0.45	$	0.24	$	3.76	$	3.62
Diluted EPS:
Net Income	$	21.7	$	10.7	$	174.9	$	158.4
Less: Income allocated to participating securities	0.1		—		0.4		0.5
Net Income Available to Common Shareholders	$	21.6	$	10.7	$	174.5	$	157.9
Weighted Average Shares Outstanding (in millions)	48.1		44.4		46.4		43.6
Dilutive Effect of Restricted Stock, Restricted Stock Units, and Stock Options (in millions)*	0.1		0.2		0.2		0.2
Weighted Average Diluted Shares (in millions)	48.2		44.6		46.6		43.8
Diluted Earnings Per Share of Common Stock	$	0.45	$	0.24	$	3.75	$	3.60
* Calculation excludes certain outstanding shares (shown in millions by period at the right) attributable to stock units subject to performance or market conditions and restricted stock, which could have a dilutive effect in the future	0.4		0.5		0.4		0.5

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REGULATORY MATTERS (Tables)

9 Months Ended

Jun. 30, 2017

Regulated Operations [Abstract]

Schedule of regulatory assets

The following regulatory assets and regulatory liabilities, including purchased gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of June 30, 2017, September 30, 2016 and June 30, 2016.

	June 30,		September 30,		June 30,
Spire	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	41.7	$	27.0	$	26.9
Unamortized purchased gas adjustments	73.9		49.7		5.4
Other	29.0		17.2		10.6
Total Regulatory Assets (current)	144.6		93.9		42.9
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	453.4		487.9		434.4
Cost of removal	135.4		130.6		81.2
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	43.4		30.1		29.6
Total Regulatory Assets (non-current)	840.5		838.0		730.7
Total Regulatory Assets	$	985.1	$	931.9	$	773.6
Regulatory Liabilities:
Current:
Rate Stabilization and Equalization (RSE) adjustment	$	1.2	$	7.5	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Unamortized purchased gas adjustments	1.0		1.7		—
Other	9.5		6.2		3.8
Total Regulatory Liabilities (current)	25.9		30.6		22.4
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Accrued cost of removal	74.6		74.8		55.4
Other	34.1		17.6		13.8
Total Regulatory Liabilities (non-current)	139.8		130.7		105.7
Total Regulatory Liabilities	$	165.7	$	161.3	$	128.1

	June 30,		September 30,		June 30,
Laclede Gas	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	34.9	$	20.2	$	20.2
Unamortized purchased gas adjustments	29.0		43.1		0.6
Other	3.3		3.7		3.5
Total Regulatory Assets (current)	67.2		67.0		24.3
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	352.3		375.7		352.1
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	22.8		24.7		25.0
Total Regulatory Assets (non-current)	583.4		589.8		562.6
Total Regulatory Assets	$	650.6	$	656.8	$	586.9
Regulatory Liabilities:
Current:
Other	$	2.7	$	1.3	$	1.3
Total Regulatory Liabilities (current)	2.7		1.3		1.3
Non-current:
Accrued cost of removal	54.8		55.1		55.4
Other	28.8		12.2		10.3
Total Regulatory Liabilities (non-current)	83.6		67.3		65.7
Total Regulatory Liabilities	$	86.3	$	68.6	$	67.0

	June 30,		September 30,		June 30,
Alagasco	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	6.8	$	6.8	$	6.7
Unamortized purchased gas adjustments	44.9		5.6		4.8
Other	10.5		8.1		7.1
Total Regulatory Assets (current)	62.2		20.5		18.6
Non-current:
Pension and postretirement benefit costs	92.2		98.9		82.3
Cost of removal	135.4		130.6		81.2
Other	1.1		1.2		4.0
Total Regulatory Assets (non-current)	228.7		230.7		167.5
Total Regulatory Assets	$	290.9	$	251.2	$	186.1
Regulatory Liabilities:
Current:
RSE adjustment	$	1.2	$	5.0	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Other	2.4		2.5		2.5
Total Regulatory Liabilities (current)	17.8		22.7		21.1
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Other	3.3		3.4		3.5
Total Regulatory Liabilities (non-current)	34.4		41.7		40.0
Total Regulatory Liabilities	$	52.2	$	64.4	$	61.1

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

	Spire						Laclede Gas
	June 30,		September 30,		June 30,		June 30,		September 30,		June 30,
	2017		2016		2016		2017		2016		2016
Future income taxes due from customers	$	166.6	$	151.3	$	146.4	$	166.6	$	151.3	$	146.4
Pension and postretirement benefit costs	231.0		240.6		203.8		231.0		240.6		203.8
Other	11.4		12.9		13.2		11.4		12.9		13.2
Total Regulatory Assets Not Earning a Return	$	409.0	$	404.8	$	363.4	$	409.0	$	404.8	$	363.4

Schedule of regulatory liabilities

The following regulatory assets and regulatory liabilities, including purchased gas adjustments, were reflected in the balance sheets of the Company and the Utilities as of June 30, 2017, September 30, 2016 and June 30, 2016.

	June 30,		September 30,		June 30,
Spire	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	41.7	$	27.0	$	26.9
Unamortized purchased gas adjustments	73.9		49.7		5.4
Other	29.0		17.2		10.6
Total Regulatory Assets (current)	144.6		93.9		42.9
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	453.4		487.9		434.4
Cost of removal	135.4		130.6		81.2
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	43.4		30.1		29.6
Total Regulatory Assets (non-current)	840.5		838.0		730.7
Total Regulatory Assets	$	985.1	$	931.9	$	773.6
Regulatory Liabilities:
Current:
Rate Stabilization and Equalization (RSE) adjustment	$	1.2	$	7.5	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Unamortized purchased gas adjustments	1.0		1.7		—
Other	9.5		6.2		3.8
Total Regulatory Liabilities (current)	25.9		30.6		22.4
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Accrued cost of removal	74.6		74.8		55.4
Other	34.1		17.6		13.8
Total Regulatory Liabilities (non-current)	139.8		130.7		105.7
Total Regulatory Liabilities	$	165.7	$	161.3	$	128.1

	June 30,		September 30,		June 30,
Laclede Gas	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	34.9	$	20.2	$	20.2
Unamortized purchased gas adjustments	29.0		43.1		0.6
Other	3.3		3.7		3.5
Total Regulatory Assets (current)	67.2		67.0		24.3
Non-current:
Future income taxes due from customers	166.6		151.3		146.4
Pension and postretirement benefit costs	352.3		375.7		352.1
Unamortized purchased gas adjustments	13.9		12.6		14.7
Energy efficiency	27.8		25.5		24.4
Other	22.8		24.7		25.0
Total Regulatory Assets (non-current)	583.4		589.8		562.6
Total Regulatory Assets	$	650.6	$	656.8	$	586.9
Regulatory Liabilities:
Current:
Other	$	2.7	$	1.3	$	1.3
Total Regulatory Liabilities (current)	2.7		1.3		1.3
Non-current:
Accrued cost of removal	54.8		55.1		55.4
Other	28.8		12.2		10.3
Total Regulatory Liabilities (non-current)	83.6		67.3		65.7
Total Regulatory Liabilities	$	86.3	$	68.6	$	67.0

	June 30,		September 30,		June 30,
Alagasco	2017		2016		2016
Regulatory Assets:
Current:
Pension and postretirement benefit costs	$	6.8	$	6.8	$	6.7
Unamortized purchased gas adjustments	44.9		5.6		4.8
Other	10.5		8.1		7.1
Total Regulatory Assets (current)	62.2		20.5		18.6
Non-current:
Pension and postretirement benefit costs	92.2		98.9		82.3
Cost of removal	135.4		130.6		81.2
Other	1.1		1.2		4.0
Total Regulatory Assets (non-current)	228.7		230.7		167.5
Total Regulatory Assets	$	290.9	$	251.2	$	186.1
Regulatory Liabilities:
Current:
RSE adjustment	$	1.2	$	5.0	$	2.9
Unbilled service margin	6.0		5.9		6.4
Refundable negative salvage	8.2		9.3		9.3
Other	2.4		2.5		2.5
Total Regulatory Liabilities (current)	17.8		22.7		21.1
Non-current:
Pension and postretirement benefit costs	27.0		28.9		27.2
Refundable negative salvage	4.1		9.4		9.3
Other	3.3		3.4		3.5
Total Regulatory Liabilities (non-current)	34.4		41.7		40.0
Total Regulatory Liabilities	$	52.2	$	64.4	$	61.1

XML

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

9 Months Ended

Jun. 30, 2017

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

Fair value of financial instruments

The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis are shown below and classified according to the fair value hierarchy. There were no such instruments classified as Level 3 (significant unobservable inputs) as of June 30, 2017, September 30, 2016, or June 30, 2016.

		Classification of Estimated Fair Value
Carrying Amount	Fair Value	Quoted Prices in Active Markets (Level 1)	Significant Observable Inputs (Level 2)

Spire

As of June 30, 2017
Cash and cash equivalents	$	8.3	$	8.3	$	8.3	$	—
Short-term debt	450.7		450.7		—		450.7
Long-term debt	1,925.3		2,033.0		—		2,033.0
As of September 30, 2016
Cash and cash equivalents	$	5.2	$	5.2	$	5.2	$	—
Short-term debt	398.7		398.7		—		398.7
Long-term debt, including current portion	2,070.7		2,257.1		—		2,257.1
As of June 30, 2016
Cash and cash equivalents	$	4.9	$	4.9	$	4.9	$	—
Short-term debt	97.6		97.6		—		97.6
Long-term debt	1,839.8		2,014.3		—		2,014.3

Laclede Gas

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

Fair value of financial instruments

As of June 30, 2017
Cash and cash equivalents	$	2.6	$	2.6	$	2.6	$	—
Short-term debt	260.2		260.2		—		260.2
Long-term debt	804.5		883.9		—		883.9
As of September 30, 2016
Cash and cash equivalents	$	2.1	$	2.1	$	2.1	$	—
Short-term debt	243.7		243.7		—		243.7
Long-term debt	804.1		900.4		—		900.4
As of June 30, 2016
Cash and cash equivalents	$	1.5	$	1.5	$	1.5	$	—
Short-term debt	136.4		136.4		—		136.4
Long-term debt	803.9		901.8		—		901.8

Alagasco

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

Fair value of financial instruments

					Classification of Estimated Fair Value
	Carrying Amount		Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)
Alagasco
As of June 30, 2017
Cash and cash equivalents	$	0.1	$	0.1	$	0.1	$	—
Short-term debt	114.9		114.9		—		114.9
Long-term debt	247.7		267.6		—		267.6
As of September 30, 2016
Short-term debt	$	82.0	$	82.0	$	—	$	82.0
Long-term debt	247.6		275.5		—		275.5
As of June 30, 2016
Short-term debt	$	37.8	$	37.8	$	—	$	37.8
Long-term debt	247.6		272.5		—		272.5

XML

FAIR VALUE MEASUREMENTS (Tables)

9 Months Ended

Jun. 30, 2017

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

Fair Value Measurements, Measured on Recurring Basis

The information presented below 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.

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

Derivative instruments included in Level 1 are valued using quoted market prices on the New York Mercantile Exchange (NYMEX) or the Intercontinental Exchange (ICE). Derivative instruments classified in Level 2 include physical commodity derivatives that are valued using Over-the-Counter Bulletin Board (OTCBB), broker, or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. Also included in Level 2 are certain derivative instruments that have values that are similar to, and correlate with, quoted prices for exchange-traded instruments in active markets and derivative instruments with settlement dates more than one year into the future. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. The Level 3 balances as of June 30, 2017, September 30, 2016 and June 30, 2016 consisted of gas commodity contracts. The Company’s and the Utilities’ policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer.

The mutual funds are included in “Other Investments” on the Company’s balance sheets and in “Other Property and Investments” on Laclede Gas’ balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exists between the Company, Laclede Gas, or Alagasco and the counterparty to a derivative contract.

Spire

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of June 30, 2017
ASSETS
Gas Utility
US stock/bond mutual funds	$	18.0	$	4.1		$	—	$	—		$	22.1
NYMEX/ICE natural gas contracts	1.9		—			—		(1.3		)	0.6
Gasoline and heating oil contracts	0.1		—			—		—			0.1
Subtotal	20.0		4.1			—		(1.3		)	22.8
Gas Marketing
NYMEX/ICE natural gas contracts	1.5		3.2			—		(2.6		)	2.1
Natural gas commodity contracts	—		6.1			0.6		(1.7		)	5.0
Total	$	21.5	$	13.4		$	0.6	$	(5.6	)	$	29.9
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	1.3	$	—		$	—	$	(1.3	)	$	—
Gas Marketing
NYMEX/ICE natural gas contracts	0.8		1.8			—		(2.6		)	—
Natural gas commodity contracts	—		6.7			—		(1.7		)	5.0
Other
Interest rate swaps	—		(0.6		)	—		—			(0.6		)
Total	$	2.1	$	7.9		$	—	$	(5.6	)	$	4.4

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of September 30, 2016
ASSETS
Gas Utility
US stock/bond mutual funds	$	16.8	$	4.1	$	—	$	—		$	20.9
NYMEX/ICE natural gas contracts	5.3		—		—		(0.4		)	4.9
NYMEX gasoline and heating oil contracts	0.4		—		—		(0.3		)	0.1
Subtotal	22.5		4.1		—		(0.7		)	25.9
Gas Marketing
NYMEX/ICE natural gas contracts	0.4		3.4		—		(3.4		)	0.4
Natural gas commodity contracts	—		8.7		0.2		(0.9		)	8.0
Total	$	22.9	$	16.2	$	0.2	$	(5.0	)	$	34.3
LIABILITIES
Gas Utility
NYMEX/ICE natural gas contracts	$	1.6	$	—	$	—	$	(1.6	)	$	—
OTCBB natural gas contracts	—		0.2		—		—			0.2
Subtotal	1.6		0.2		—		(1.6		)	0.2
Gas Marketing
NYMEX/ICE natural gas contracts	3.5		1.6		—		(5.1		)	—
Natural gas commodity contracts	—		2.6		—		(0.9		)	1.7
Other
Interest rate swaps	—		3.0		—		—			3.0
Total	$	5.1	$	7.4	$	—	$	(7.6	)	$	4.9
As of June 30, 2016
ASSETS
Gas Utility
US stock/bond mutual funds	$	16.4	$	4.0	$	—	$	—		$	20.4
NYMEX/ICE natural gas contracts	8.2		—		—		(3.1		)	5.1
Subtotal	24.6		4.0		—		(3.1		)	25.5
Gas Marketing
NYMEX/ICE natural gas contracts	0.6		5.5		—		(5.6		)	0.5
Natural gas commodity contracts	—		6.3		0.3		(0.6		)	6.0
Total	$	25.2	$	15.8	$	0.3	$	(9.3	)	$	32.0
LIABILITIES
Gas Utility
OTCBB natural gas contracts	$	—	$	0.6	$	—	$	—		$	0.6
Subtotal	—		0.6		—		—			0.6
Gas Marketing
NYMEX/ICE natural gas contracts	6.5		2.5		—		(9.0		)	—
Natural gas commodity contracts	—		3.4		—		(0.5		)	2.9
Other
Interest Rate Swaps	—		4.0		—		—			4.0
Total	$	6.5	$	10.5	$	—	$	(9.5	)	$	7.5

Laclede Gas

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

Fair Value Measurements, Measured on Recurring Basis

	Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Effects of Netting and Cash Margin Receivables /Payables			Total
As of June 30, 2017
ASSETS
US stock/bond mutual funds	$	18.0	$	4.1	$	—	$	—		$	22.1
NYMEX/ICE natural gas contracts	1.9		—		—		(1.3		)	0.6
NYMEX gasoline and heating oil contracts	0.1		—		—		—			0.1
Total	$	20.0	$	4.1	$	—	$	(1.3	)	$	22.8
LIABILITIES
NYMEX/ICE natural gas contracts	$	1.3	$	—	$	—	$	(1.3	)	$	—
Total	$	1.3	$	—	$	—	$	(1.3	)	$	—

As of September 30, 2016
ASSETS
US stock/bond mutual funds	$	16.8	$	4.1	$	—	$	—		$	20.9
NYMEX/ICE natural gas contracts	5.3		—		—		(0.4		)	4.9
NYMEX gasoline and heating oil contracts	0.3		—		—		(0.3		)	—
Total	$	22.4	$	4.1	$	—	$	(0.7	)	$	25.8
LIABILITIES
NYMEX/ICE natural gas contracts	$	1.6	$	—	$	—	$	(1.6	)	$	—
OTCBB natural gas contracts	—		0.2		—		—			0.2
Total	$	1.6	$	0.2	$	—	$	(1.6	)	$	0.2

As of June 30, 2016
ASSETS
US stock/bond mutual funds	$	16.4	$	4.0	$	—	$	—		$	20.4
NYMEX/ICE natural gas contracts	8.2		—		—		(3.1		)	5.1
Total	$	24.6	$	4.0	$	—	$	(3.1	)	$	25.5
LIABILITIES
OTCBB natural gas contracts	$	—	$	0.6	$	—	$	—		$	0.6
Total	$	—	$	0.6	$	—	$	—		$	0.6

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS (Tables)

9 Months Ended

Jun. 30, 2017

Pension Plans

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

Net Periodic Cost

The net periodic pension cost included the following components:

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Spire
Service cost – benefits earned during the period	$	5.0		$	3.8		$	15.5		$	11.5
Interest cost on projected benefit obligation	7.0			6.9			20.8			21.0
Expected return on plan assets	(9.4		)	(8.6		)	(29.0		)	(26.3		)
Amortization of prior service cost	0.2			0.1			0.7			0.3
Amortization of actuarial loss	3.0			1.9			9.6			5.9
Loss on lump-sum settlements	—			0.2			11.9			2.4
Special termination benefits	—			—			—			1.6
Subtotal	5.8			4.3			29.5			16.4
Regulatory adjustment	3.1			4.4			0.3			11.1
Net pension cost	$	8.9		$	8.7		$	29.8		$	27.5

Postretirement Plans

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

Net Periodic Cost

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

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Spire
Service cost – benefits earned during the period	$	2.7		$	2.7		$	8.2		$	8.2
Interest cost on accumulated postretirement benefit obligation	2.2			2.6			6.5			7.6
Expected return on plan assets	(3.5		)	(3.3		)	(10.3		)	(10.1		)
Amortization of prior service credit	—			0.1			—			0.2
Amortization of actuarial loss	0.6			0.9			1.8			2.7
Special termination benefits	—			—			—			2.6
Subtotal	2.0			3.0			6.2			11.2
Regulatory adjustment	(0.8		)	(1.7		)	(2.4		)	(7.6		)
Net postretirement benefit cost	$	1.2		$	1.3		$	3.8		$	3.6

Laclede Gas | Pension Plans

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

Net Periodic Cost

Laclede Gas
Service cost – benefits earned during the period	$	3.0		$	2.5		$	9.6		$	7.5
Interest cost on projected benefit obligation	4.8			5.4			14.5			16.2
Expected return on plan assets	(6.8		)	(6.7		)	(21.2		)	(20.1		)
Amortization of prior service cost	0.2			0.1			0.7			0.3
Amortization of actuarial loss	2.5			1.9			8.2			5.9
Loss on lump-sum settlements	—			—			11.5			—
Special termination benefits	—			—			—			1.6
Subtotal	3.7			3.2			23.3			11.4
Regulatory adjustment	1.3			3.0			(4.5		)	8.8
Net pension cost	$	5.0		$	6.2		$	18.8		$	20.2

Laclede Gas | Postretirement Plans

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

Net Periodic Cost

Laclede Gas
Service cost – benefits earned during the period	$	2.6		$	2.6		$	7.8		$	7.9
Interest cost on accumulated postretirement benefit obligation	1.7			2.1			5.1			6.1
Expected return on plan assets	(2.3		)	(2.1		)	(6.8		)	(6.4		)
Amortization of prior service credit	0.1			0.1			0.2			0.2
Amortization of actuarial loss	0.6			1.0			1.9			2.9
Special termination benefits	—			—			—			2.6
Subtotal	2.7			3.7			8.2			13.3
Regulatory adjustment	(0.4		)	(1.2		)	(1.1		)	(6.2		)
Net postretirement benefit cost	$	2.3		$	2.5		$	7.1		$	7.1

Alagasco | Pension Plans

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

Net Periodic Cost

Alagasco
Service cost – benefits earned during the period	$	1.6		$	1.3		$	4.7		$	4.0
Interest cost on projected benefit obligation	1.6			1.5			4.6			4.8
Expected return on plan assets	(1.8		)	(1.9		)	(5.4		)	(6.2		)
Amortization of actuarial loss	0.5			—			1.4			—
Loss on lump-sum settlements	—			0.2			0.4			2.4
Subtotal	1.9			1.1			5.7			5.0
Regulatory adjustment	1.6			1.4			4.3			2.3
Net pension cost	$	3.5		$	2.5		$	10.0		$	7.3

Alagasco | Postretirement Plans

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

Net Periodic Cost

Alagasco
Service cost – benefits earned during the period	$	—		$	0.1		$	0.2		$	0.3
Interest cost on accumulated postretirement benefit obligation	0.4			0.5			1.2			1.5
Expected return on plan assets	(1.1		)	(1.2		)	(3.3		)	(3.7		)
Amortization of prior service credit	(0.1		)	—			(0.2		)	—
Amortization of actuarial gain	—			(0.1		)	(0.1		)	(0.2		)
Subtotal	(0.8		)	(0.7		)	(2.2		)	(2.1		)
Regulatory adjustment	(0.5		)	(0.5		)	(1.4		)	(1.4		)
Net postretirement benefit income	$	(1.3	)	$	(1.2	)	$	(3.6	)	$	(3.5	)

XML

INFORMATION BY OPERATING SEGMENT (Tables)

9 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Schedule of operating segment information

	Gas Utility		Gas Marketing			Other			Eliminations			Consolidated
Three Months Ended June 30, 2017
Operating Revenues:
Revenues from external customers	$	305.1	$	17.9		$	0.5		$	—		$	323.5
Intersegment revenues	1.5		—			1.6			(3.1		)	—
Total Operating Revenues	306.6		17.9			2.1			(3.1		)	323.5
Operating Expenses:
Gas Utility
Natural and propane gas	88.7		—			—			(12.0		)	76.7
Operation and maintenance	101.9		—			—			(1.1		)	100.8
Depreciation and amortization	38.4		—			—			—			38.4
Taxes, other than income taxes	30.5		—			—			—			30.5
Total Gas Utility Operating Expenses	259.5		—			—			(13.1		)	246.4
Gas Marketing and Other	—		12.0			4.8			10.0			26.8
Total Operating Expenses	259.5		12.0			4.8			(3.1		)	273.2
Operating Income (Loss)	$	47.1	$	5.9		$	(2.7	)	$	—		$	50.3
Net Economic Earnings (Loss)	$	23.3	$	2.3		$	(4.0	)	$	—		$	21.6
Three Months Ended June 30, 2016
Operating Revenues:
Revenues from external customers	$	253.2	$	(4.3	)	$	0.4		$	—		$	249.3
Intersegment revenues	0.1		6.6			0.5			(7.2		)	—
Total Operating Revenues	253.3		2.3			0.9			(7.2		)	249.3
Operating Expenses:
Gas Utility
Natural and propane gas	61.1		—			—			(7.0		)	54.1
Operation and maintenance	91.9		—			—			(0.1		)	91.8
Depreciation and amortization	34.2		—			—			—			34.2
Taxes, other than income taxes	27.4		—			—			—			27.4
Total Gas Utility Operating Expenses	214.6		—			—			(7.1		)	207.5
Gas Marketing and Other	—		3.9			2.7			(0.1		)	6.5
Total Operating Expenses	214.6		3.9			2.7			(7.2		)	214.0
Operating Income (Loss)	$	38.7	$	(1.6	)	$	(1.8	)	$	—		$	35.3
Net Economic Earnings (Loss)	$	18.0	$	1.8		$	(5.2	)	$	—		$	14.6

	Gas Utility		Gas Marketing			Other			Eliminations			Consolidated
Nine Months Ended June 30, 2017
Operating Revenues:
Revenues from external customers	$	1,419.1	$	61.8		$	1.1		$	—		$	1,482.0
Intersegment revenues	7.9		—			4.6			(12.5		)	—
Total Operating Revenues	1,427.0		61.8			5.7			(12.5		)	1,482.0
Operating Expenses:
Gas Utility
Natural and propane gas	578.8		—			—			(54.0		)	524.8
Operation and maintenance	301.7		—			—			(3.1		)	298.6
Depreciation and amortization	114.0		—			—			—			114.0
Taxes, other than income taxes	112.2		—			—			—			112.2
Total Gas Utility Operating Expenses	1,106.7		—			—			(57.1		)	1,049.6
Gas Marketing and Other	—		58.9			9.1			44.6			112.6
Total Operating Expenses	1,106.7		58.9			9.1			(12.5		)	1,162.2
Operating Income (Loss)	$	320.3	$	2.9		$	(3.4	)	$	—		$	319.8
Net Economic Earnings (Loss)	$	187.3	$	3.7		$	(12.9	)	$	—		$	178.1
Nine Months Ended June 30, 2016
Operating Revenues:
Revenues from external customers	$	1,263.5	$	(6.7	)	$	1.2		$	—		$	1,258.0
Intersegment revenues	2.0		29.8			1.4			(33.2		)	—
Total Operating Revenues	1,265.5		23.1			2.6			(33.2		)	1,258.0
Operating Expenses:
Gas Utility
Natural and propane gas	496.0		—			—			(32.3		)	463.7
Operation and maintenance	278.4		—			—			(0.7		)	277.7
Depreciation and amortization	101.5		—			—			—			101.5
Taxes, other than income taxes	99.5		—			—			—			99.5
Total Gas Utility Operating Expenses	975.4		—			—			(33.0		)	942.4
Gas Marketing and Other	—		18.4			7.4			(0.2		)	25.6
Total Operating Expenses	975.4		18.4			7.4			(33.2		)	968.0
Operating Income (Loss)	$	290.1	$	4.7		$	(4.8	)	$	—		$	290.0
Net Economic Earnings (Loss)	$	170.5	$	4.5		$	(11.8	)	$	—		$	163.2

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

	June 30,			September 30,			June 30,
	2017			2016			2016
Total Assets:
Gas Utility	$	5,323.1		$	5,184.7		$	4,646.9
Gas Marketing	223.6			205.0			167.8
Other	2,171.8			1,836.6			1,592.6
Eliminations	(1,420.3		)	(1,161.9		)	(1,108.3		)
Total Assets	$	6,298.2		$	6,064.4		$	5,299.0

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

The following table reconciles the Company’s net economic earnings to net income.

	Three Months Ended June 30,						Nine Months Ended June 30,
	2017			2016			2017			2016
Net Income	$	21.7		$	10.7		$	174.9		$	158.4
Adjustments, pre-tax:
Unrealized (gain) loss on energy-related derivative contracts	(2.2		)	4.9			3.2			2.9
Lower of cost or market inventory adjustments	—			(0.1		)	—			0.6
Realized gain on economic hedges prior to sale of the physical commodity	—			(0.3		)	(0.2		)	(0.9		)
Acquisition, divestiture and restructuring activities	1.9			1.8			2.1			5.1
Income tax effect of adjustments	0.2			(2.4		)	(1.9		)	(2.9		)
Net Economic Earnings	$	21.6		$	14.6		$	178.1		$	163.2

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) $ in Millions		9 Months Ended		12 Months Ended
	Sep. 12, 2016 USD ($)	Jun. 30, 2017 USD ($) reporting_unit	Jun. 30, 2016 USD ($)	Sep. 30, 2016 USD ($)
Related Party Transaction [Line Items]
Number of operating segments | reporting_unit		2
Proceeds from settlement for acquisition of EnergySouth		$ 3.8	$ 0.0
Accruals for capital expenditures		26.5	9.9	$ 21.6
Laclede Gas
Related Party Transaction [Line Items]
Accrued unbilled revenues		31.9	28.5	26.1
Accruals for capital expenditures		$ 16.5	5.3	14.8
Alagasco
Related Party Transaction [Line Items]
Threshold Period Past Due for Collection		90 days
Accrued unbilled revenues		$ 6.0	6.4	5.9
Accruals for capital expenditures		$ 7.9	4.6	6.8
Alagasco | Financing Receivables, Equal to Greater than 90 Days Past Due
Related Party Transaction [Line Items]
Financing receivable, recorded investment, past due			$ 0.4	$ 0.4
EnergySouth
Related Party Transaction [Line Items]
Proceeds from settlement for acquisition of EnergySouth	$ 3.8

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Goodwill (Details) $ in Millions	9 Months Ended
	Jun. 30, 2017 USD ($)
Goodwill [Roll Forward]
Balance as of September 30, 2016	$ 1,164.9
Adjustments related to the acquisition of EnergySouth	(1.0)
Balance as of June 30, 2017	1,163.9
Operating Segments | Gas Utility
Goodwill [Roll Forward]
Balance as of September 30, 2016	210.2
Adjustments related to the acquisition of EnergySouth	0.0
Balance as of June 30, 2017	210.2
Operating Segments | Gas Marketing
Goodwill [Roll Forward]
Balance as of September 30, 2016	0.0
Adjustments related to the acquisition of EnergySouth	0.0
Balance as of June 30, 2017	0.0
Other
Goodwill [Roll Forward]
Balance as of September 30, 2016	954.7
Adjustments related to the acquisition of EnergySouth	(1.0)
Balance as of June 30, 2017	$ 953.7

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Gross Receipts Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Schedule of Gross Receipts Taxes [Line Items]
Gross Receipts taxes recorded in regulated gas distribution operating revenues	$ 18.0	$ 14.8	$ 71.7	$ 65.0
Laclede Gas
Schedule of Gross Receipts Taxes [Line Items]
Gross Receipts taxes recorded in regulated gas distribution operating revenues	12.4	11.1	52.0	49.7
Alagasco
Schedule of Gross Receipts Taxes [Line Items]
Gross Receipts taxes recorded in regulated gas distribution operating revenues	$ 4.2	$ 3.7	$ 16.1	$ 15.3

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Inter-company Transactions (Details) - Affiliated Entity - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Regulated Operation | Alagasco [Member] | Laclede Risk Insurance Services [Member]
Related Party Transaction [Line Items]
Insurance services received from Laclede Insurance Risk Services	$ 0.5	$ 0.0	$ 1.5	$ 0.0
Regulated Operation | Laclede Gas | Spire Marketing
Related Party Transaction [Line Items]
Purchases of natural gas from Spire Marketing	11.8	6.7	53.3	31.5
Regulated Operation | Laclede Gas | Laclede Risk Insurance Services [Member]
Related Party Transaction [Line Items]
Insurance services received from Laclede Insurance Risk Services	0.5	0.2	1.6	0.7
Regulated Operation | Spire Marketing | Laclede Gas
Related Party Transaction [Line Items]
Sales of natural gas to Spire Marketing	1.5	0.0	7.8	1.7
Unregulated Operation | Laclede Gas | Laclede Pipeline Company
Related Party Transaction [Line Items]
Transportation services received from Laclede Pipeline Company	$ 0.3	$ 0.3	$ 0.8	$ 0.8

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - New Accounting Pronouncements (Details) - Accounting Standards Update 2015-03 - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016
Spire | Deferred charges
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	$ 14.8	$ 13.0	$ 12.3
Spire | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	14.9	13.0	11.9
Laclede Gas | Deferred charges
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	4.1	4.2	4.5
Laclede Gas | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	4.0	4.2	4.4
Alagasco | Deferred charges
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	2.3	2.4	2.4
Alagasco | Long-term debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Debt issuance costs	$ 2.3	$ 2.4	$ 2.4

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EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		3 Months Ended		9 Months Ended
	Apr. 03, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Basic EPS:
Net Income		$ 21.7	$ 10.7	$ 174.9	$ 158.4
Less: Income allocated to participating securities		0.1	0.0	0.4	0.5
Net Income Available to Common Shareholders		$ 21.6	$ 10.7	$ 174.5	$ 157.9
Weighted Average Shares Outstanding, Basic (in Shares)		48,100	44,400	46,400	43,600
Basic Earnings Per Share of Common Stock (in dollars per share)		$ 0.45	$ 0.24	$ 3.76	$ 3.62
Diluted EPS:
Net Income		$ 21.7	$ 10.7	$ 174.9	$ 158.4
Less: Income allocated to participating securities		0.1	0.0	0.4	0.5
Net Income Available to Common Shareholders		$ 21.6	$ 10.7	$ 174.5	$ 157.9
Weighted Average Shares Outstanding, Basic (in Shares)		48,100	44,400	46,400	43,600
Dilutive Effect of Stock Options, Restricted Stock and Restricted Stock Units (in shares)		100	200	200	200
Weighted Average Diluted Shares (in shares)		48,200	44,600	46,600	43,800
Diluted Earnings Per Share of Common Stock (in dollars per share)		$ 0.45	$ 0.24	$ 3.75	$ 3.60
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock, issued (in shares)	2,500				2,875
Restricted stock and stock units subject to performance and/or market conditions
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Outstanding shares excluded from calculation of diluted EPS (in shares)		400	500	400	500

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REGULATORY MATTERS - Schedule of Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016
Regulatory Assets [Line Items]
Regulatory Assets: Current	$ 70.7	$ 44.2	$ 37.5
Regulatory Assets: Non-current	840.5	838.0	730.7
Total Regulatory Assets	985.1	931.9	773.6
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	24.9	28.9	22.4
Regulatory Liabilities: Non-current	139.8	130.7	105.7
Total Regulatory Liabilities	165.7	161.3	128.1
Rate Stabilization and Equalization (RSE) adjustment
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	1.2	7.5	2.9
Unbilled service margin
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	6.0	5.9	6.4
Pension and postretirement benefit costs
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	27.0	28.9	27.2
Refundable negative salvage
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	8.2	9.3	9.3
Regulatory Liabilities: Non-current	4.1	9.4	9.3
Unamortized purchased gas adjustments
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	1.0	1.7	0.0
Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	9.5	6.2	3.8
Regulatory Liabilities: Non-current	34.1	17.6	13.8
Accrued cost of removal
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	74.6	74.8	55.4
Total Regulatory Liabilities (current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	25.9	30.6	22.4
Total Regulatory Liabilities (non-current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	139.8	130.7	105.7
Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets: Current	41.7	27.0	26.9
Regulatory Assets: Non-current	453.4	487.9	434.4
Unamortized purchased gas adjustments
Regulatory Assets [Line Items]
Regulatory Assets: Current	73.9	49.7	5.4
Regulatory Assets: Non-current	13.9	12.6	14.7
Other
Regulatory Assets [Line Items]
Regulatory Assets: Current	29.0	17.2	10.6
Regulatory Assets: Non-current	43.4	30.1	29.6
Total Regulatory Assets (current)
Regulatory Assets [Line Items]
Regulatory Assets: Current	144.6	93.9	42.9
Future income taxes due from customers
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	166.6	151.3	146.4
Accrued cost of removal
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	135.4	130.6	81.2
Energy efficiency
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	27.8	25.5	24.4
Total Regulatory Assets (non-current)
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	840.5	838.0	730.7
Laclede Gas
Regulatory Assets [Line Items]
Regulatory Assets: Current	38.2	23.9	23.7
Regulatory Assets: Non-current	583.4	589.8	562.6
Total Regulatory Assets	650.6	656.8	586.9
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	2.7	1.3	1.3
Regulatory Liabilities: Non-current	83.6	67.3	65.7
Total Regulatory Liabilities	86.3	68.6	67.0
Laclede Gas | Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	2.7	1.3	1.3
Regulatory Liabilities: Non-current	28.8	12.2	10.3
Laclede Gas | Accrued cost of removal
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	54.8	55.1	55.4
Laclede Gas | Total Regulatory Liabilities (current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	2.7	1.3	1.3
Laclede Gas | Total Regulatory Liabilities (non-current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	83.6	67.3	65.7
Laclede Gas | Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets: Current	34.9	20.2	20.2
Regulatory Assets: Non-current	352.3	375.7	352.1
Laclede Gas | Unamortized purchased gas adjustments
Regulatory Assets [Line Items]
Regulatory Assets: Current	29.0	43.1	0.6
Regulatory Assets: Non-current	13.9	12.6	14.7
Laclede Gas | Other
Regulatory Assets [Line Items]
Regulatory Assets: Current	3.3	3.7	3.5
Regulatory Assets: Non-current	22.8	24.7	25.0
Laclede Gas | Total Regulatory Assets (current)
Regulatory Assets [Line Items]
Regulatory Assets: Current	67.2	67.0	24.3
Laclede Gas | Future income taxes due from customers
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	166.6	151.3	146.4
Laclede Gas | Energy efficiency
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	27.8	25.5	24.4
Laclede Gas | Total Regulatory Assets (non-current)
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	583.4	589.8	562.6
Alagasco
Regulatory Assets [Line Items]
Regulatory Assets: Current	17.3	14.9	13.8
Regulatory Assets: Non-current	228.7	230.7	167.5
Total Regulatory Assets	290.9	251.2	186.1
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	17.8	22.7	21.1
Regulatory Liabilities: Non-current	34.4	41.7	40.0
Total Regulatory Liabilities	52.2	64.4	61.1
Alagasco | Rate Stabilization and Equalization (RSE) adjustment
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	1.2	5.0	2.9
Alagasco | Unbilled service margin
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	6.0	5.9	6.4
Alagasco | Pension and postretirement benefit costs
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	27.0	28.9	27.2
Alagasco | Refundable negative salvage
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	8.2	9.3	9.3
Regulatory Liabilities: Non-current	4.1	9.4	9.3
Alagasco | Other
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	2.4	2.5	2.5
Regulatory Liabilities: Non-current	3.3	3.4	3.5
Alagasco | Total Regulatory Liabilities (current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Current	17.8	22.7	21.1
Alagasco | Total Regulatory Liabilities (non-current)
Regulatory Liabilities [Line Items]
Regulatory Liabilities: Non-current	34.4	41.7	40.0
Alagasco | Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Regulatory Assets: Current	6.8	6.8	6.7
Regulatory Assets: Non-current	92.2	98.9	82.3
Alagasco | Unamortized purchased gas adjustments
Regulatory Assets [Line Items]
Regulatory Assets: Current	44.9	5.6	4.8
Alagasco | Other
Regulatory Assets [Line Items]
Regulatory Assets: Current	10.5	8.1	7.1
Regulatory Assets: Non-current	1.1	1.2	4.0
Alagasco | Total Regulatory Assets (current)
Regulatory Assets [Line Items]
Regulatory Assets: Current	62.2	20.5	18.6
Alagasco | Accrued cost of removal
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	135.4	130.6	81.2
Alagasco | Total Regulatory Assets (non-current)
Regulatory Assets [Line Items]
Regulatory Assets: Non-current	$ 228.7	$ 230.7	$ 167.5

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REGULATORY MATTERS - Schedule of Regulatory Assets Not Earnings a Return (Details) - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	$ 409.0	$ 404.8	$ 363.4
Future income taxes due from customers
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	166.6	151.3	146.4
Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	231.0	240.6	203.8
Other
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	11.4	12.9	13.2
Laclede Gas
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	409.0	404.8	363.4
Laclede Gas | Future income taxes due from customers
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	166.6	151.3	146.4
Laclede Gas | Pension and postretirement benefit costs
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	231.0	240.6	203.8
Laclede Gas | Other
Regulatory Assets [Line Items]
Total Regulatory Assets Not Earning a Return	$ 11.4	$ 12.9	$ 13.2

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REGULATORY MATTERS (Details)	9 Months Ended
	Jun. 30, 2017
Regulated Operations [Abstract]
Remaining recovery period for certain regulatory assets for which no return on investment during recovery period is provided (in years)	20 years
Remaining recovery period for regulatory assets for which no return on investment during recovery period is provided (in years)	15 years

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FINANCING ARRANGEMENTS AND LONG-TERM DEBT (Details) $ / shares in Units, shares in Thousands					3 Months Ended	9 Months Ended		12 Months Ended
	Apr. 03, 2017 USD ($) shares $ / shares	Feb. 22, 2017 USD ($)	Dec. 14, 2016 USD ($) agreement bank borrower	Jun. 11, 2014 USD ($) $ / shares	Dec. 31, 2016	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($) shares	Sep. 30, 2014 equity_units	Mar. 15, 2017 USD ($)	Mar. 10, 2017 USD ($)
Line of Credit Facility [Line Items]
Number of terminated loan agreements | agreement			3
Debt covenant, short-term debt to capital requirement, maximum			70.00%
Common stock, issued (in shares) | shares	2,500						2,875
Shares issued, price per share (usd per share) | $ / shares	$ 57.3921
Payment to Purchase Share, Price Per Share | $ / shares	$ 67.50
Conversion to common stock, rate per share (percentage)	0.8712
Repayment of short-term debt - net	$ 142,000,000
Laclede Gas
Line of Credit Facility [Line Items]
Repayment of short-term debt - net						$ 243,700,000	$ 135,400,000
Line of Credit | Revolving Credit Facility
Line of Credit Facility [Line Items]
Number of banks in loan agreement | bank			11
Maximum borrowing capacity			$ 975,000,000.0
Line of Credit | Revolving Credit Facility | Spire
Line of Credit Facility [Line Items]
Maximum borrowing capacity			300,000,000.0
Ratio of short-term debt to total capital						0.54
Line of Credit | Revolving Credit Facility | Laclede Gas
Line of Credit Facility [Line Items]
Maximum borrowing capacity			$ 475,000,000.0
Number of borrowers under loan agreement | borrower			3
Ratio of short-term debt to total capital						0.48
Line of Credit | Revolving Credit Facility | Alagasco
Line of Credit Facility [Line Items]
Maximum borrowing capacity			$ 200,000,000.0
Ratio of short-term debt to total capital						0.29
Line of Credit | Revolving Credit Facility | Credit Availability Concentration Risk
Line of Credit Facility [Line Items]
Concentration risk					12.30%
Senior Notes
Line of Credit Facility [Line Items]
Maximum aggregate face amount		$ 6,200,000
Proceeds from issuance of debt		150,000,000
Notes Payable
Line of Credit Facility [Line Items]
Debt instrument, repurchase amount										$ 100,000,000
Alagasco
Line of Credit Facility [Line Items]
Number of equity instruments | equity_units								2,875,000
Corporate units, stated value per unit (usd per share) | $ / shares				$ 50
Interest rate (percentage)				2.00%
Alagasco | Junior Subordinated Debt
Line of Credit Facility [Line Items]
Proceeds from debt				$ 143,800,000
Senor Notes Due in 2024 | Senior Notes
Line of Credit Facility [Line Items]
Maximum aggregate face amount		$ 143,800,000
Interest rate (percentage)		3.543%
Senior Notes Due March15, 2027 | Senior Notes
Line of Credit Facility [Line Items]
Maximum aggregate face amount									$ 250,000,000.0
Interest rate (percentage)									3.93%
Securities Subject to Mandatory Redemption [Member]
Line of Credit Facility [Line Items]
Number of equity instruments | shares	2,875

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FINANCING ARRANGEMENTS AND LONG-TERM DEBT Short-Term Debt (Details) - USD ($) $ in Millions	Dec. 21, 2016	Jun. 30, 2017
Short-term Debt [Line Items]
Short-term Debt		$ 450.7
Commercial Paper Notes
Short-term Debt [Line Items]
Maximum aggregate face amount	$ 975.0
Debt maturity	365 days
Laclede Gas
Short-term Debt [Line Items]
Short-term Debt		260.2
Alagasco
Short-term Debt [Line Items]
Short-term Debt		$ 114.9

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 8.3	$ 5.2	$ 4.9	$ 13.8
Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	2.6	2.1	1.5	1.7
Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.1	0.0	0.0	$ 7.2
Quoted Prices in Active Markets (Level 1)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	8.3	5.2	4.9
Short-term debt	0.0	0.0	0.0
Long-term debt, including current portion	0.0	0.0	0.0
Quoted Prices in Active Markets (Level 1) | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	2.6	2.1	1.5
Short-term debt	0.0	0.0	0.0
Long-term debt, including current portion	0.0	0.0	0.0
Quoted Prices in Active Markets (Level 1) | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.1
Short-term debt	0.0	0.0	0.0
Long-term debt, including current portion	0.0	0.0	0.0
Significant Observable Inputs (Level 2)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.0	0.0	0.0
Short-term debt	450.7	398.7	97.6
Long-term debt, including current portion	2,033.0	2,257.1	2,014.3
Significant Observable Inputs (Level 2) | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.0	0.0	0.0
Short-term debt	260.2	243.7	136.4
Long-term debt, including current portion	883.9	900.4	901.8
Significant Observable Inputs (Level 2) | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.0
Short-term debt	114.9	82.0	37.8
Long-term debt, including current portion	267.6	275.5	272.5
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	8.3	5.2	4.9
Short-term debt	450.7	398.7	97.6
Long-term debt, including current portion	1,925.3	2,070.7	1,839.8
Carrying Amount | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	2.6	2.1	1.5
Short-term debt	260.2	243.7	136.4
Long-term debt, including current portion	804.5	804.1	803.9
Carrying Amount | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.1
Short-term debt	114.9	82.0	37.8
Long-term debt, including current portion	247.7	247.6	247.6
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	8.3	5.2	4.9
Short-term debt	450.7	398.7	97.6
Long-term debt, including current portion	2,033.0	2,257.1	2,014.3
Fair Value | Laclede Gas
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	2.6	2.1	1.5
Short-term debt	260.2	243.7	136.4
Long-term debt, including current portion	883.9	900.4	901.8
Fair Value | Alagasco
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0.1
Short-term debt	114.9	82.0	37.8
Long-term debt, including current portion	$ 267.6	$ 275.5	$ 272.5

XML

FAIR VALUE MEASUREMENTS (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	$ (5.6)	$ (7.6)
Derivative liability	4.4	4.9
Laclede Gas
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(0.7)	$ (3.1)
Derivative asset	22.8	25.8	25.5
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(1.6)	0.0
Derivative liability	0.0	0.2	0.6
Quoted Prices in Active Markets (Level 1)
LIABILITIES
Derivative liability before netting adjustment	2.1	5.1
Quoted Prices in Active Markets (Level 1) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	20.0	22.4	24.6
LIABILITIES
Derivative liability before netting adjustment	1.3	1.6	0.0
Significant Observable Inputs (Level 2)
LIABILITIES
Derivative liability before netting adjustment	7.9	7.4
Significant Observable Inputs (Level 2) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	4.1	4.1	4.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.2	0.6
Significant Unobservable Inputs (Level 3)
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0
Significant Unobservable Inputs (Level 3) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0	0.0
US stock/bond mutual funds | Laclede Gas
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	0.0	0.0	0.0
Derivative asset	22.1	20.9	20.4
US stock/bond mutual funds | Quoted Prices in Active Markets (Level 1) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	18.0	16.8	16.4
US stock/bond mutual funds | Significant Observable Inputs (Level 2) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	4.1	4.1	4.0
US stock/bond mutual funds | Significant Unobservable Inputs (Level 3) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
NYMEX/ICE natural gas contracts | Laclede Gas
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(0.4)	(3.1)
Derivative asset	0.6	4.9	5.1
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(1.6)
Derivative liability	0.0	0.0
NYMEX/ICE natural gas contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	1.9	5.3	8.2
LIABILITIES
Derivative liability before netting adjustment	1.3	1.6
NYMEX/ICE natural gas contracts | Significant Observable Inputs (Level 2) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0
NYMEX/ICE natural gas contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0
Gasoline and heating oil contracts | Laclede Gas
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	0.0	(0.3)
Derivative asset	0.1	0.0
Gasoline and heating oil contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.1	0.3
Gasoline and heating oil contracts | Significant Observable Inputs (Level 2) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.0	0.0
Gasoline and heating oil contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas
ASSETS
Derivative asset before netting adjustment	0.0	0.0
OTCBB natural gas contracts | Laclede Gas
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables		0.0	0.0
Derivative liability		0.2	0.6
OTCBB natural gas contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
OTCBB natural gas contracts | Significant Observable Inputs (Level 2) | Laclede Gas
LIABILITIES
Derivative liability before netting adjustment		0.2	0.6
OTCBB natural gas contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
Interest rate swaps
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	0.0
Derivative liability	(0.6)
Interest rate swaps | Quoted Prices in Active Markets (Level 1)
LIABILITIES
Derivative liability before netting adjustment	0.0
Interest rate swaps | Significant Observable Inputs (Level 2)
LIABILITIES
Derivative liability before netting adjustment	(0.6)
Interest rate swaps | Significant Unobservable Inputs (Level 3)
LIABILITIES
Derivative liability before netting adjustment	0.0
Other | Interest rate swaps
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables		0.0	0.0
Derivative liability		3.0	4.0
Other | Interest rate swaps | Quoted Prices in Active Markets (Level 1)
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
Other | Interest rate swaps | Significant Observable Inputs (Level 2)
LIABILITIES
Derivative liability before netting adjustment		3.0	4.0
Other | Interest rate swaps | Significant Unobservable Inputs (Level 3)
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
Gas Utility
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(0.7)	(3.1)
Derivative asset	22.8	25.9	25.5
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables		(1.6)	0.0
Derivative liability		0.2	0.6
Gas Utility | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	20.0	22.5	24.6
LIABILITIES
Derivative liability before netting adjustment		1.6	0.0
Gas Utility | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	4.1	4.1	4.0
LIABILITIES
Derivative liability before netting adjustment		0.2	0.6
Gas Utility | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
Gas Utility | US stock/bond mutual funds
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	0.0	0.0	0.0
Derivative asset	22.1	20.9	20.4
Gas Utility | US stock/bond mutual funds | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	18.0	16.8	16.4
Gas Utility | US stock/bond mutual funds | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	4.1	4.1	4.0
Gas Utility | US stock/bond mutual funds | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
Gas Utility | NYMEX/ICE natural gas contracts
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(0.4)	(3.1)
Derivative asset	0.6	4.9	5.1
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	(1.3)	(1.6)
Derivative liability	0.0	0.0
Gas Utility | NYMEX/ICE natural gas contracts | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	1.9	5.3	8.2
LIABILITIES
Derivative liability before netting adjustment	1.3	1.6
Gas Utility | NYMEX/ICE natural gas contracts | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0
Gas Utility | NYMEX/ICE natural gas contracts | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0
Gas Utility | Gasoline and heating oil contracts
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	0.0	(0.3)
Derivative asset	0.1	0.1
Gas Utility | Gasoline and heating oil contracts | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	0.1	0.4
Gas Utility | Gasoline and heating oil contracts | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	0.0	0.0
Gas Utility | Gasoline and heating oil contracts | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.0	0.0
Gas Utility | OTCBB natural gas contracts
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables		0.0	0.0
Derivative liability		0.2	0.6
Gas Utility | OTCBB natural gas contracts | Quoted Prices in Active Markets (Level 1)
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
Gas Utility | OTCBB natural gas contracts | Significant Observable Inputs (Level 2)
LIABILITIES
Derivative liability before netting adjustment		0.2	0.6
Gas Utility | OTCBB natural gas contracts | Significant Unobservable Inputs (Level 3)
LIABILITIES
Derivative liability before netting adjustment		0.0	0.0
Gas Marketing
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(5.6)
Derivative asset	29.9
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables			(9.5)
Derivative liability			7.5
Gas Marketing | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	21.5
LIABILITIES
Derivative liability before netting adjustment			6.5
Gas Marketing | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	13.4
LIABILITIES
Derivative liability before netting adjustment			10.5
Gas Marketing | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.6
LIABILITIES
Derivative liability before netting adjustment			0.0
Gas Marketing | US stock/bond mutual funds
ASSETS
Effects of Netting and Cash Margin Receivables /Payables		(5.0)	(9.3)
Derivative asset		34.3	32.0
Gas Marketing | US stock/bond mutual funds | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment		22.9	25.2
Gas Marketing | US stock/bond mutual funds | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment		16.2	15.8
Gas Marketing | US stock/bond mutual funds | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment		0.2	0.3
Gas Marketing | NYMEX/ICE natural gas contracts
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(2.6)	(3.4)	(5.6)
Derivative asset	2.1	0.4	0.5
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	(2.6)	(5.1)	(9.0)
Derivative liability	0.0	0.0	0.0
Gas Marketing | NYMEX/ICE natural gas contracts | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	1.5	0.4	0.6
LIABILITIES
Derivative liability before netting adjustment	0.8	3.5	6.5
Gas Marketing | NYMEX/ICE natural gas contracts | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	3.2	3.4	5.5
LIABILITIES
Derivative liability before netting adjustment	1.8	1.6	2.5
Gas Marketing | NYMEX/ICE natural gas contracts | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0	0.0
Gas Marketing | Natural gas commodity contracts
ASSETS
Effects of Netting and Cash Margin Receivables /Payables	(1.7)	(0.9)	(0.6)
Derivative asset	5.0	8.0	6.0
LIABILITIES
Effects of Netting and Cash Margin Receivables /Payables	(1.7)	(0.9)	(0.5)
Derivative liability	5.0	1.7	2.9
Gas Marketing | Natural gas commodity contracts | Quoted Prices in Active Markets (Level 1)
ASSETS
Derivative asset before netting adjustment	0.0	0.0	0.0
LIABILITIES
Derivative liability before netting adjustment	0.0	0.0	0.0
Gas Marketing | Natural gas commodity contracts | Significant Observable Inputs (Level 2)
ASSETS
Derivative asset before netting adjustment	6.1	8.7	6.3
LIABILITIES
Derivative liability before netting adjustment	6.7	2.6	3.4
Gas Marketing | Natural gas commodity contracts | Significant Unobservable Inputs (Level 3)
ASSETS
Derivative asset before netting adjustment	0.6	0.2	0.3
LIABILITIES
Derivative liability before netting adjustment	$ 0.0	$ 0.0	$ 0.0

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CONCENTRATIONS OF CREDIT RISK (Details) $ in Millions	9 Months Ended
	Jun. 30, 2017 USD ($) subsegment counterparty
Concentration Risk [Line Items]
Number of groups with potential to affect overall exposure | subsegment	3
Number of large counterparties for which credit risk is disclosed | counterparty	5
Number of counterparties with investment-grade rating | counterparty	4
Energy Producers And Their Affiliates
Concentration Risk [Line Items]
Accounts receivable	$ 10.6
Net receivable amount	5.6
Utility Companies And Their Affiliates
Concentration Risk [Line Items]
Accounts receivable	63.8
Net receivable amount	60.0
Largest Counterparties
Concentration Risk [Line Items]
Accounts receivable	30.7
Net receivable amount	$ 29.0

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Narrative (Details) - USD ($)	3 Months Ended				9 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2017	Jun. 30, 2016
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Extent of lump-sum payments recognized, percentage					100.00%
Lump-sum payments recognized as settlement					$ 12,600,000
Contributions made by employer					$ 8,800,000
Medical insurance available until age is reached after early retirement					65 years
Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Gain (Loss) on lump-sum settlements	$ 0	$ 2,200,000	$ 200,000		$ 11,900,000	$ 2,400,000
Special termination benefits	0		0		0	1,600,000
Pension Plans | Alagasco
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Lump-sum payments recognized as settlement	1,900,000
Gain (Loss) on lump-sum settlements	0	400,000	200,000		400,000	2,400,000
Contributions made by employer					0
Pension Plans | Laclede Gas
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Lump-sum payments recognized as settlement	36,300,000
Gain (Loss) on lump-sum settlements	0	$ 11,500,000	0		11,500,000	0
Special termination benefits	0		0	$ 1,600,000	0	1,600,000
Contributions made by employer					22,500,000
Anticipated contributions to pension plans for qualified trust	6,500,000				6,500,000
Nonqualified Pension Plans | Laclede Gas
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Contributions made by employer					200,000
Anticipated contributions to pension plans for qualified trust	400,000				400,000
Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Special termination benefits	0		0	$ 2,600,000	0	2,600,000
Anticipated contributions to pension plans for qualified trust	5,100,000				5,100,000
Anticipated payment directly to participants in postretirement plan					400,000
Postretirement Plans | Laclede Gas
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Special termination benefits	$ 0		$ 0		$ 0	$ 2,600,000

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Net Periodic Cost (Details) - USD ($) $ in Millions	3 Months Ended				9 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2017	Jun. 30, 2016
Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	$ 5.0		$ 3.8		$ 15.5	$ 11.5
Interest cost on projected benefit obligation	7.0		6.9		20.8	21.0
Expected return on plan assets	(9.4)		(8.6)		(29.0)	(26.3)
Amortization of prior service credit	0.2		0.1		0.7	0.3
Amortization of actuarial gain (loss)	3.0		1.9		9.6	5.9
Loss on lump-sum settlements	0.0	$ 2.2	0.2		11.9	2.4
Special termination benefits	0.0		0.0		0.0	1.6
Subtotal	5.8		4.3		29.5	16.4
Regulatory adjustment	3.1		4.4		0.3	11.1
Net pension cost (income)	8.9		8.7		29.8	27.5
Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	2.7		2.7		8.2	8.2
Interest cost on projected benefit obligation	2.2		2.6		6.5	7.6
Expected return on plan assets	(3.5)		(3.3)		(10.3)	(10.1)
Amortization of prior service credit	0.0		0.1		0.0	0.2
Amortization of actuarial gain (loss)	0.6		0.9		1.8	2.7
Special termination benefits	0.0		0.0	$ 2.6	0.0	2.6
Subtotal	2.0		3.0		6.2	11.2
Regulatory adjustment	(0.8)		(1.7)		(2.4)	(7.6)
Net pension cost (income)	1.2		1.3		3.8	3.6
Laclede Gas | Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	3.0		2.5		9.6	7.5
Interest cost on projected benefit obligation	4.8		5.4		14.5	16.2
Expected return on plan assets	(6.8)		(6.7)		(21.2)	(20.1)
Amortization of prior service credit	0.2		0.1		0.7	0.3
Amortization of actuarial gain (loss)	2.5		1.9		8.2	5.9
Loss on lump-sum settlements	0.0	11.5	0.0		11.5	0.0
Special termination benefits	0.0		0.0	$ 1.6	0.0	1.6
Subtotal	3.7		3.2		23.3	11.4
Regulatory adjustment	1.3		3.0		(4.5)	8.8
Net pension cost (income)	5.0		6.2		18.8	20.2
Laclede Gas | Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	2.6		2.6		7.8	7.9
Interest cost on projected benefit obligation	1.7		2.1		5.1	6.1
Expected return on plan assets	(2.3)		(2.1)		(6.8)	(6.4)
Amortization of prior service credit	0.1		0.1		0.2	0.2
Amortization of actuarial gain (loss)	0.6		1.0		1.9	2.9
Special termination benefits	0.0		0.0		0.0	2.6
Subtotal	2.7		3.7		8.2	13.3
Regulatory adjustment	(0.4)		(1.2)		(1.1)	(6.2)
Net pension cost (income)	2.3		2.5		7.1	7.1
Alagasco | Pension Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	1.6		1.3		4.7	4.0
Interest cost on projected benefit obligation	1.6		1.5		4.6	4.8
Expected return on plan assets	(1.8)		(1.9)		(5.4)	(6.2)
Amortization of actuarial gain (loss)	0.5		0.0		1.4	0.0
Loss on lump-sum settlements	0.0	$ 0.4	0.2		0.4	2.4
Subtotal	1.9		1.1		5.7	5.0
Regulatory adjustment	1.6		1.4		4.3	2.3
Net pension cost (income)	3.5		2.5		10.0	7.3
Alagasco | Postretirement Plans
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost – benefits earned during the period	0.0		0.1		0.2	0.3
Interest cost on projected benefit obligation	0.4		0.5		1.2	1.5
Expected return on plan assets	(1.1)		(1.2)		(3.3)	(3.7)
Amortization of prior service credit	(0.1)		0.0		(0.2)	0.0
Amortization of actuarial gain (loss)	0.0		(0.1)		(0.1)	(0.2)
Subtotal	(0.8)		(0.7)		(2.2)	(2.1)
Regulatory adjustment	(0.5)		(0.5)		(1.4)	(1.4)
Net pension cost (income)	$ (1.3)		$ (1.2)		$ (3.6)	$ (3.5)

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INFORMATION BY OPERATING SEGMENT - Schedule of Operating Segment Information (Details) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($) reporting_unit	Jun. 30, 2016 USD ($)	Sep. 30, 2016 USD ($)
Segment Reporting [Abstract]
Number of operating segments | reporting_unit			2
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	$ 323.5	$ 249.3	$ 1,482.0	$ 1,258.0
Total Operating Revenues	323.5	249.3	1,482.0	1,258.0
Gas Utility
Natural and propane gas	76.7	54.1	524.8	463.7
Operation and maintenance	100.8	91.8	298.6	277.7
Depreciation and amortization	38.4	34.2	114.0	101.5
Taxes, other than income taxes	30.5	27.4	112.2	99.5
Total Gas Utility Operating Expenses	246.4	207.5	1,049.6	942.4
Gas Marketing and Other	26.8	6.5	112.6	25.6
Total Operating Expenses	273.2	214.0	1,162.2	968.0
Operating Income	50.3	35.3	319.8	290.0
Net Economic Earnings (Loss)	21.6	14.6	178.1	163.2
ASSETS
Total Assets	6,298.2	5,299.0	6,298.2	5,299.0	$ 6,064.4
Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0.0	0.0	0.0	0.0
Other
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0.5	0.4	1.1	1.2
Total Operating Revenues	2.1	0.9	5.7	2.6
Gas Utility
Natural and propane gas	0.0	0.0	0.0	0.0
Operation and maintenance	0.0	0.0	0.0	0.0
Depreciation and amortization	0.0	0.0	0.0	0.0
Taxes, other than income taxes	0.0	0.0	0.0	0.0
Total Gas Utility Operating Expenses	0.0	0.0	0.0	0.0
Gas Marketing and Other	4.8	2.7	9.1	7.4
Total Operating Expenses	4.8	2.7	9.1	7.4
Operating Income	(2.7)	(1.8)	(3.4)	(4.8)
Net Economic Earnings (Loss)	(4.0)	(5.2)	(12.9)	(11.8)
ASSETS
Total Assets	2,171.8	1,592.6	2,171.8	1,592.6	1,836.6
Other | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	1.6	0.5	4.6	1.4
Eliminations
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	0.0	0.0	0.0	0.0
Total Operating Revenues	(3.1)	(7.2)	(12.5)	(33.2)
Gas Utility
Natural and propane gas	(12.0)	(7.0)	(54.0)	(32.3)
Operation and maintenance	(1.1)	(0.1)	(3.1)	(0.7)
Depreciation and amortization	0.0	0.0	0.0	0.0
Taxes, other than income taxes	0.0	0.0	0.0	0.0
Total Gas Utility Operating Expenses	(13.1)	(7.1)	(57.1)	(33.0)
Gas Marketing and Other	10.0	(0.1)	44.6	(0.2)
Total Operating Expenses	(3.1)	(7.2)	(12.5)	(33.2)
Operating Income	0.0	0.0	0.0	0.0
Net Economic Earnings (Loss)	0.0	0.0	0.0	0.0
ASSETS
Total Assets	(1,420.3)	(1,108.3)	(1,420.3)	(1,108.3)	(1,161.9)
Eliminations | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	(3.1)	(7.2)	(12.5)	(33.2)
Gas Utility | Operating Segments
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	305.1	253.2	1,419.1	1,263.5
Total Operating Revenues	306.6	253.3	1,427.0	1,265.5
Gas Utility
Natural and propane gas	88.7	61.1	578.8	496.0
Operation and maintenance	101.9	91.9	301.7	278.4
Depreciation and amortization	38.4	34.2	114.0	101.5
Taxes, other than income taxes	30.5	27.4	112.2	99.5
Total Gas Utility Operating Expenses	259.5	214.6	1,106.7	975.4
Gas Marketing and Other	0.0	0.0	0.0	0.0
Total Operating Expenses	259.5	214.6	1,106.7	975.4
Operating Income	47.1	38.7	320.3	290.1
Net Economic Earnings (Loss)	23.3	18.0	187.3	170.5
ASSETS
Total Assets	5,323.1	4,646.9	5,323.1	4,646.9	5,184.7
Gas Utility | Operating Segments | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	1.5	0.1	7.9	2.0
Gas Marketing | Operating Segments
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	17.9	(4.3)	61.8	(6.7)
Total Operating Revenues	17.9	2.3	61.8	23.1
Gas Utility
Natural and propane gas	0.0	0.0	0.0	0.0
Operation and maintenance	0.0	0.0	0.0	0.0
Depreciation and amortization	0.0	0.0	0.0	0.0
Taxes, other than income taxes	0.0	0.0	0.0	0.0
Total Gas Utility Operating Expenses	0.0	0.0	0.0	0.0
Gas Marketing and Other	12.0	3.9	58.9	18.4
Total Operating Expenses	12.0	3.9	58.9	18.4
Operating Income	5.9	(1.6)	2.9	4.7
Net Economic Earnings (Loss)	2.3	1.8	3.7	4.5
ASSETS
Total Assets	223.6	167.8	223.6	167.8	$ 205.0
Gas Marketing | Operating Segments | Intersegment revenues
Operating Segment Information [Abstract]
Total revenues including intersegment revenues	$ 0.0	$ 6.6	$ 0.0	$ 29.8

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INFORMATION BY OPERATING SEGMENT - Reconciliation of Consolidated Net Income to Consolidated Net Economic Earnings (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Segment Reporting [Abstract]
Net Income	$ 21.7	$ 10.7	$ 174.9	$ 158.4
Unrealized (gain) loss on energy-related derivative contracts	(2.2)	4.9	3.2	2.9
Lower of cost or market inventory adjustments	0.0	(0.1)	0.0	0.6
Realized gain on economic hedges prior to sale of the physical commodity	0.0	(0.3)	(0.2)	(0.9)
Acquisition, divestiture and restructuring activities	1.9	1.8	2.1	5.1
Income tax effect of adjustments	0.2	(2.4)	(1.9)	(2.9)
Net Economic Earnings	$ 21.6	$ 14.6	$ 178.1	$ 163.2

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COMMITMENTS AND CONTINGENCIES - Commitments (Details) $ in Millions	9 Months Ended
	Jun. 30, 2017 USD ($)
Long-term Purchase Commitment [Line Items]
Minimum total payments required for natural gas contracts	$ 1,311.6
Laclede Gas
Long-term Purchase Commitment [Line Items]
Minimum total payments required for natural gas contracts	518.7
Alagasco
Long-term Purchase Commitment [Line Items]
Minimum total payments required for natural gas contracts	$ 296.5

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COMMITMENTS AND CONTINGENCIES - Contingencies (Details)		9 Months Ended	57 Months Ended	63 Months Ended
	Dec. 17, 2013 fatality	Jun. 30, 2017 plaintiff lawsuit site	Dec. 31, 2016 lawsuit	Jun. 30, 2017 lawsuit site	Sep. 30, 2014 site
Laclede Gas
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP) sites in Missouri		4		4
Number of former manufactured gas plant (MGP) sites enrolled in BVCP		2		2
Alagasco
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)		9		9
Number of former manufactured gas distribution		5		5
Number of incident fatalities | fatality	1
Mobile Gas Service Corporation [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit			14
Number of lawsuits settled | lawsuit				11
Number of lawsuits pending | lawsuit		3		3
Previous Ownership | Laclede Gas
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)					19
Previous Ownership | Missouri Gas Energy (MGE)
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)		7		7
Previous Ownership | Mobile Gas Service Corporation [Member]
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)		1		1
Current Ownership | Alagasco
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP)		4		4
Number of former manufactured gas distribution		1		1
Pending Litigation [Member] | Mobile Gas Service Corporation [Member]
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff		270
Shrewsbury, Missouri | Laclede Gas
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP) sites in Missouri		1		1
St. Louis, Missouri | Laclede Gas
Loss Contingencies [Line Items]
Number of former manufactured gas plant (MGP) sites in Missouri		3		3