10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended December 31, 2012

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: 001-34664

Inergy, L.P.

(Exact name of registrant as specified in its charter)

Delaware	43-1918951
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)

Two Brush Creek Blvd., Suite 200 Kansas City, Missouri	64112
(Address of principal executive offices)	(Zip code)

(816) 842-8181

(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year,

if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.     Yes  ý    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that registrant was required to submit and post such files).    Yes  ý    No  ¨

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

Large accelerated filer	ý	Accelerated filer	¨
Non-accelerated filer	(Do not check if a smaller reporting company)	Smaller reporting company	¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  ý

INERGY, L.P.

INDEX TO FORM 10-Q

	Page
Part I – Financial Information
Item 1 – Financial Statements of Inergy, L.P.:
Consolidated Balance Sheets as of December 31, 2012 (unaudited) and September 30, 2012	3
Unaudited Consolidated Statements of Operations for the Three Months Ended December 31, 2012 and 2011	4
Unaudited Consolidated Statements of Comprehensive Income for the Three Months Ended December 31, 2012 and 2011	5
Unaudited Consolidated Statement of Partners’ Capital for the Three Months Ended December 31, 2012	6
Unaudited Consolidated Statements of Cash Flows for the Three Months Ended December 31, 2012 and 2011	7
Unaudited Notes to Consolidated Financial Statements	9
Item  2 – Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
Item 3 – Quantitative and Qualitative Disclosures About Market Risk	45
Item 4 – Controls and Procedures	46
Part II – Other Information
Item 1 – Legal Proceedings	47
Item 1A – Risk Factors	47
Item 2 – Unregistered Sales of Equity Securities and Use of Proceeds	48
Item 3 – Defaults Upon Senior Securities	48
Item 4 – Mine Safety Disclosures	48
Item 5 – Other Information	48
Item 6 – Exhibits	49
Signature	50

2

INERGY, L.P. AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS (in millions, except unit information)
	December 31, 2012		September 30, 2012
	(unaudited)
Assets
Current assets:
Cash and cash equivalents	$	1.8	$	—
Accounts receivable, less allowance for doubtful accounts of $0.4 million at December 31, 2012 and September 30, 2012, respectively	201.7		133.6
Inventories (Note 3)	63.5		87.1
Assets from price risk management activities	30.8		37.5
Prepaid expenses and other current assets	19.1		20.3
Total current assets	316.9		278.5
Property, plant and equipment (Note 3)	2,297.9		2,160.7
Less: accumulated depreciation	484.7		450.2
Property, plant and equipment, net	1,813.2		1,710.5
Intangible assets (Note 3):
Customer accounts	194.4		41.2
Other intangible assets	36.2		21.3
	230.6		62.5
Less: accumulated amortization	23.7		21.2
Intangible assets, net	206.9		41.3
Goodwill	330.8		165.8
Other assets	11.1		11.5
Total assets	$	2,678.9	$	2,207.6
Liabilities and partners’ capital
Current liabilities:
Accounts payable	$	143.5	$	120.8
Accrued expenses	68.0		93.9
Liabilities from price risk management activities	24.2		20.9
Current portion of long-term debt (Note 7)	2.1		3.4
Total current liabilities	237.8		239.0
Long-term debt, less current portion (Note 7)	1,024.2		739.8
Other long-term liabilities	22.7		23.4
Deferred income taxes	20.3		20.6
Partners’ capital (Note 8):
Limited partner unitholders (131,740,895 and 125,795,836 common units issued and outstanding at December 31, 2012 and September 30, 2012, respectively, and 5,882,105 Class B units issued and outstanding at September 30, 2012)	1,113.6		1,046.2
Total Inergy, L.P. partners’ capital	1,113.6		1,046.2
Interest of non-controlling partners in subsidiaries	260.3		138.6
Total partners’ capital	1,373.9		1,184.8
Total liabilities and partners’ capital	$	2,678.9	$	2,207.6

The accompanying notes are an integral part of these consolidated financial statements.

3

INERGY, L.P. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (in millions, except unit and per unit data) (unaudited)
	Three Months Ended
	December 31,
	2012			2011
Revenue:
Retail	$	—		$	295.0
Marketing, supply and logistics	370.8			314.4
Storage and transportation	67.8			59.2
	438.6			668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			178.8
Marketing, supply and logistics	338.8			295.1
Storage and transportation	19.8			13.9
	358.6			487.8
Expenses:
Operating and administrative	32.5			82.6
Depreciation and amortization	36.3			48.7
Loss on disposal of assets	0.8			1.4
Operating income	10.4			48.1
Other income (expense):
Interest expense, net	(8.1		)	(28.0		)
Early extinguishment of debt	—			(24.9		)
Other income	0.6			1.3
Income (loss) before income taxes	2.9			(3.5		)
Provision for income taxes	0.1			0.1
Net income (loss)	2.8			(3.6		)
Net income attributable to non-controlling partners	(1.5		)	(0.4		)
Net income (loss) attributable to partners	$	1.3		$	(4.0	)
Partners' interest information:
Total limited partners’ interest in net income (loss)	$	1.3		$	(4.0	)
Net income (loss) per limited partner unit:
Basic	$	0.01		$	(0.03	)
Diluted	$	0.01		$	(0.03	)
Weighted-average limited partners’ units outstanding (in thousands):
Basic	128,769			122,556
Dilutive units	2,813			—
Diluted	131,582			122,556

The accompanying notes are an integral part of these consolidated financial statements.

4

INERGY, L.P. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (in millions) (unaudited)
	Three Months Ended December 31,
	2012			2011
Net income (loss)	$	2.8		$	(3.6	)
Change in unrealized fair value on cash flow hedges (Note 2)	4.1			(2.6		)
Change in Suburban Propane Partners, L.P. units (Note 2)	(0.4		)	—
Comprehensive income (loss)	$	6.5		$	(6.2	)

The accompanying notes are an integral part of these consolidated financial statements.

5

INERGY, L.P. AND SUBSIDIARIES CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL (in millions) (unaudited)
	Common Unit Capital			Non-Controlling Partners			Total Partners’ Capital
Balance at September 30, 2012	$	1,046.2		$	138.6		$	1,184.8
Net proceeds from issuance of common units by Inergy Midstream, L.P.	—			224.7			224.7
Net proceeds from common unit options exercised	0.7			—			0.7
Unit-based compensation charges	2.2			0.9			3.1
Retirement of common units	(2.0		)	—			(2.0		)
Distributions	(36.7		)	(7.2		)	(43.9		)
Gain (loss) on issuance of Inergy Midstream, L.P. units	98.2			(98.2		)	—
Change in unrealized fair value on cash flow hedges and change in Suburban Propane Partners, L.P. units	3.7			—			3.7
Net income	1.3			1.5			2.8
Balance at December 31, 2012	$	1,113.6		$	260.3		$	1,373.9

The accompanying notes are an integral part of these consolidated financial statements.

6

INERGY, L.P. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS (in millions) (unaudited)
	Three Months Ended
	December 31,
	2012			2011
Operating activities
Net income (loss)	$	2.8		$	(3.6	)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and depletion	34.8			39.9
Amortization	1.5			8.8
Amortization of deferred financing costs, swap premium and bond discount	3.3			1.5
Unit-based compensation charges	3.1			3.1
Provision for doubtful accounts	0.1			(0.1		)
Loss on disposal of assets	0.8			1.4
Deferred income taxes	(0.3		)	(0.1		)
Early extinguishment of debt	—			8.3
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable	(64.9		)	(69.5		)
Inventories	23.6			56.0
Prepaid expenses and other current assets	1.3			(4.5		)
Other assets (liabilities)	0.2			(0.1		)
Accounts payable and accrued expenses	8.1			(0.7		)
Customer deposits	—			(7.4		)
Net liabilities from price risk management activities	13.6			(9.8		)
Net cash provided by operating activities	28.0			23.2
Investing activities
Acquisitions, net of cash acquired	(423.4		)	(19.8		)
Purchases of property, plant and equipment	(52.2		)	(57.1		)
Proceeds from sale of assets	—			2.7
Net cash used in investing activities	(475.6		)	(74.2		)
The accompanying notes are an integral part of these consolidated financial statements.

7

INERGY, L.P. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS (continued) (in millions) (unaudited)
	Three Months Ended
	December 31,
	2012			2011
Financing activities
Proceeds from the issuance of Inergy, L.P. long-term debt	$	203.2		$	577.7
Proceeds from the issuance of Inergy Midstream, L.P. long-term debt	581.1			86.8
Principal payments on Inergy, L.P. long-term debt	(183.5		)	(803.2		)
Principal payments on Inergy Midstream, L.P. long-term debt	(317.8		)	(6.6		)
Proceeds from the issuance of promissory note	—			255.0
Principal payment on promissory note	—			(255.0		)
Distributions	(36.7		)	(83.9		)
Distributions paid to non-controlling partners	(7.2		)	—
Payments for deferred financing costs	(13.1		)	(4.6		)
Net proceeds from issuance of Inergy Midstream, L.P. common units	224.7			292.7
Retirement of common units	(2.0		)	(1.1		)
Net proceeds from Inergy, L.P. common unit options exercised	0.7			0.4
Net cash provided by financing activities	449.4			58.2
Net increase in cash	1.8			7.2
Cash at beginning of period	—			11.5
Cash at end of period	$	1.8		$	18.7
Supplemental schedule of noncash investing and financing activities
Change in the value of intangible assets and equity	$	—		$	(3.0	)
Net change to property, plant and equipment through accounts payable and accrued expenses	$	(15.4	)	$	(7.0	)
Change in the fair value of interest rate swap liability and related long-term debt	$	—		$	(0.1	)
Acquisitions, net of cash acquired:
Current assets	$	3.3		$	4.7
Property, plant and equipment	100.9			10.5
Intangible assets	157.2			2.0
Goodwill	165.0			3.2
Other assets	—			0.1
Current liabilities	(3.5		)	—
Debt	0.5			(0.7		)
Total acquisitions, net of cash acquired	$	423.4		$	19.8

The accompanying notes are an integral part of these consolidated financial statements.

8

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1 – Partnership Organization and Basis of Presentation

Organization

The accompanying consolidated financial statements include the accounts of Inergy, L.P. (“Inergy” or "the Company") and its wholly owned subsidiaries, including among others, Inergy Partners, LLC (“Partners”), Tres Palacios Gas Storage LLC ("TPGS"), IPCH Acquisition Corp. (“IPCHA”), Inergy Finance Corp. and Inergy Operations, LLC. The accompanying consolidated financial statements also include the accounts of Inergy's majority-owned subsidiary, Inergy Midstream, L.P. (“Inergy Midstream”), and its wholly-owned subsidiaries.

NRGM GP, LLC Change of Control Event

In connection with the Inergy Midstream initial public offering ("IPO"), Inergy and Inergy Holdings GP, LLC (“Holdings GP”), the indirect owner of Inergy's general partner, entered into a membership interest purchase agreement under which, under certain circumstances, Holdings GP will be required to purchase from Inergy, and Inergy will be required to sell to Holdings GP, all of the membership interests in MGP GP, LLC, the entity that controls Inergy Midstream's general partner, for nominal consideration. MGP GP, LLC is a wholly owned subsidiary of Inergy and the general partner of Inergy Midstream Holdings, L.P., which is the sole member of Inergy Midstream's general partner and direct holder of all of its IDRs. Under the agreement, Holdings GP is required to purchase MGP GP, LLC in the event that (i) a change of control of Inergy occurs at a time when Inergy is entitled to receive less than 50% of all cash distributed with respect to Inergy Midstream's limited partner interests and IDRs or (ii) through dilution or a distribution to the Inergy common unitholders of Inergy's interests in Inergy Midstream, Inergy is entitled to receive less than 25% of all cash distributed with respect to Inergy Midstream's limited partner interests and IDRs.

Nature of Operations

Inergy's financial statements reflect two operating and reporting segments: (i) marketing, supply and logistics operations and (ii) storage and transportation operations. Inergy's marketing, supply and logistics operations provide natural gas liquids ("NGLs") and crude oil marketing, supply and logistics services to producers, refiners, petrochemical companies, marketers, and others that effectively provide flow assurances to our customers. Inergy's marketing, supply and logistics assets primarily includes its West Coast operations, a fleet of 275 tractors and 457 transports managed by a team of experienced employees in the NGL business, and a crude oil loading and storage terminal (the "COLT Hub") that was acquired by Inergy Midstream on December 7, 2012. The historical results of the retail propane operations that were contributed to Suburban Propane Partners, L.P. (“SPH”) on August 1, 2012 are also included in this segment.

Inergy's storage and transportation operations provide natural gas and NGL storage and transportation services to third parties, as well as the production and sale of salt products. Inergy's storage and transportation assets include the Tres Palacios natural gas storage facility in Texas. Through its ownership interest in Inergy Midstream, Inergy has an investment in four natural gas storage facilities in New York (Stagecoach, Thomas Corners, Steuben and Seneca Lake), natural gas transportation assets in New York and Pennsylvania (the North-South Facilities, the MARC I Pipeline, and the East Pipeline), an NGL storage facility in New York (Bath storage facility) and a solution-mining and salt production company in New York (US Salt).

Basis of Presentation

The financial information contained herein as of December 31, 2012, and for the three-month periods endedDecember 31, 2012 and 2011, is unaudited. Inergy believes this information has been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and Article 10 of Regulation S-X. Inergy also believes this information includes all adjustments (consisting only of normal recurring adjustments) necessary to present fairly the financial position, results of operations and cash flows for the periods then ended.

On August 1, 2012, Inergy contributed its retail propane operations to SPH.  ASC 205 requires that in order for a transaction to be considered discontinued operations, the gross cash flows related to the continuing involvement with the discontinued operations must be immaterial. The financial statements do not report the retail propane operations as discontinued as the involvement of Inergy with the retail propane operations subsequent to contribution is expected to be material due to a propane supply arrangement between Inergy and SPH.

9

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

The accompanying consolidated financial statements should be read in conjunction with the consolidated financial statements of Inergy, L.P. and subsidiaries and the notes thereto included in Form 10-K as filed with the Securities and Exchange Commission for the fiscal year ended September 30, 2012.

Reclassifications

The consolidated statement of operations for the three months endedDecember 31, 2011 reflects a reclassification within revenue and a reclassification within cost of product sold to conform to the current period presentation. For the three months endedDecember 31, 2011, propane and other revenue was $478.7 million and $189.9 million, respectively, and propane and other cost of product sold was $374.4 million and $113.4 million, respectively. These reclassifications had no effect on net income.

Note 2 – Summary of Significant Accounting Policies

Financial Instruments and Price Risk Management

Inergy utilizes certain derivative financial instruments to (i) manage its exposure to commodity price risk, specifically, the related change in the fair value of inventories, as well as the variability of cash flows related to forecasted transactions; (ii) ensure adequate physical supply of commodity will be available; and (iii) manage its exposure to interest rate risk associated with fixed and variable rate borrowings. Inergy records all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded either through current earnings or as other comprehensive income, depending on the type of transaction.

Inergy is party to certain commodity derivative financial instruments that are designated as hedges of selected inventory positions, and qualify as fair value hedges. Inergy is also periodically party to certain interest rate swap agreements designed to manage interest rate risk exposure. Inergy’s overall objective for entering into fair value hedges is to manage its exposure to fluctuations in commodity prices and changes in the fair market value of its inventories and fixed and variable rate borrowings. The commodity derivatives are recorded at fair value on the balance sheets as price risk management assets or liabilities and the related change in fair value is recorded to earnings in the current period as cost of product sold. The interest rate derivatives are recorded at fair value on the balance sheets in other assets or liabilities and the related change in fair value is recorded to earnings in the current period as interest expense.

Any ineffective portion of the fair value hedges is recognized as cost of product sold in the current period. Inergy recognized net gains of $2.1 million and $1.0 million in the three months ended December 31, 2012 and 2011, respectively, related to the ineffective portion of its fair value hedging instruments. In addition, Inergy recognized no gain or loss for the three months endedDecember 31, 2012 and 2011, related to the portion of fair value hedging instruments that it excluded from its assessment of hedge effectiveness.

Inergy also enters into derivative financial instruments that qualify as cash flow hedges, which hedge the exposure of variability in expected future cash flows predominantly attributable to forecasted purchases to supply fixed price sale contracts and variable interest payments. These derivatives are recorded on the balance sheet at fair value as price risk management assets or liabilities. The effective portion of the gain or loss on these cash flow hedges is recorded in other comprehensive income in partner's capital and reclassified into earnings in the same period in which the hedge transaction affects earnings. In certain situations under the rules, the ineffective portion of the gain or loss is recognized as cost of product sold in the current period. Accumulated other comprehensive loss was $11.2 million and $14.9 million at December 31, 2012 and September 30, 2012, respectively. Included in accumulated other comprehensive loss at December 31, 2012 was a loss of $3.9 million attributable to commodity instruments, a loss of $6.9 million attributable to interest rate swaps, and a loss of $0.4 million attributable to SPH units. Approximately $3.6 million is expected to be reclassified to earnings from other comprehensive income over the next twelve months.

Inergy’s policy is to offset fair value amounts of derivative instruments and cash collateral paid or received with the same counterparty under a master netting arrangement.

The cash flow impact of derivative financial instruments is reflected as cash flows from operating activities in the consolidated statements of cash flows.

10

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Revenue Recognition

Sales of NGLs and salt are recognized at the time product is shipped or delivered to the customer depending on the sales terms. NGL processing and fractionation fees are recognized upon delivery of the product. Revenues from the COLT Hub are recognized when the contractual services are provided, such as loading of customer rail cars. Revenues from storage and transportation contracts are recognized during the period in which the storage and transportation services are provided, such as loading of customer rail cars.

Expense Classification

Cost of product sold consists of tangible products sold including NGLs and salt, as well as certain direct costs incurred in providing storage and transportation services (period ended December 31, 2011 also includes costs of tangible product associated with retail propane sales). Operating and administrative expenses consist of all expenses incurred other than those described above in cost of product sold and depreciation and amortization. Certain operating and administrative expenses and depreciation and amortization are incurred in the distribution of the product sales and storage sales but are not included in cost of product sold. These amounts were $35.9 million and $54.1 million for the three months ended December 31, 2012 and 2011, respectively.

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the periods presented. Actual results could differ from those estimates.

Inventories

Inventories for marketing, supply and logistics operations, which mainly consist of NGLs, are stated at the lower of cost or market and are computed using the average cost method. These inventories are designated under a fair value hedge program and are consequently marked to market. NGL inventories being hedged and carried at market value at December 31, 2012 and September 30, 2012, amount to $48.4 million and $73.2 million, respectively. Inventories for storage and transportation operations are stated at the lower of cost or market and are computed predominantly using the average cost method.

Shipping and Handling Costs

Shipping and handling costs are recorded as part of cost of product sold at the time product is shipped or delivered to the customer except as discussed in “Expense Classification.”

Property, Plant and Equipment

Property, plant and equipment are stated at historical cost less accumulated depreciation. Inergy capitalizes all construction-related direct labor and material costs as well as the cost of funds used during construction. Amounts capitalized for cost of funds used during construction amounted to $3.1 million and $3.4 million for the three months ended December 31, 2012 and 2011, respectively. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:

	Years
Land, buildings and improvements	15 – 70
Office furniture and equipment	3 – 7
Vehicles	3 – 10
Pipelines	15
Tanks and plant equipment	3 – 30
Base gas	10

Salt deposits are depleted on a unit of production method.

11

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Identifiable Intangible Assets

The Company has recorded certain identifiable intangible assets, including customer accounts, covenants not to compete and deferred financing costs. Customer accounts and covenants not to compete have arisen from acquisitions. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt. Additionally, an acquired intangible asset should be separately recognized if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer's intent to do so.

Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows:

	Years
Customer accounts	15 - 20
Covenants not to compete	2 - 10
Deferred financing costs	4 - 10

Goodwill

Goodwill is recognized for various acquisitions as the excess of the cost of the acquisitions over the fair value of the related net assets at the date of acquisition. Goodwill is subject to at least an annual assessment for impairment by applying a fair-value-based test.

Inergy completed its annual impairment test for each of its reporting units and determined that no impairment existed as of September 30, 2012. No indicators of impairment were identified requiring an interim impairment test during the three-month period ended December 31, 2012.

Income Taxes

Inergy is a publicly-traded master limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. Inergy Sales and Service, Inc. (“Services”), a subsidiary of Inergy, does not generate at least 90% of its gross income from qualifying sources, and as such, federal and state income taxes are provided on the taxable income of Services. The earnings of the Company and its limited liability subsidiaries are included in the Federal and state income tax returns of the individual members or partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes for Inergy have been included in the accompanying financial statements as income taxes due to the nature of the tax in those particular states. In addition, Federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities (IPCHA and Services). The Company is required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which differences are expected to reverse.

Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.

Sales Tax

Inergy accounts for the collection and remittance of sales tax on a net tax basis. As a result, these amounts are not reflected in the consolidated statements of operations.

12

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Income Per Unit

Inergy calculates basic net income per limited partner unit by utilizing the two class method. Diluted net income per limited partner unit is computed by dividing net income by the weighted-average number of units outstanding and the effect of dilutive units granted under the Long Term Incentive Plan and the Class B units. All outstanding Class B units converted to common units during the quarter ended December 31, 2012. No Class B units were outstanding as of December 31, 2012.

Asset Retirement Obligations

An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. The fair value of certain AROs could not be made as settlement dates (or range of dates) associated with these assets were not estimable.

Accounting for Unit-Based Compensation

Inergy sponsors a Long Term Incentive Plan and all share-based payments to employees, including grants of employee stock options, are recognized in the consolidated statements of operations based on their fair values.

The amount of compensation expense recorded by the Company was $3.1 million and $3.1 million during the three months endedDecember 31, 2012 and 2011, respectively.

Segment Information

There are certain accounting requirements that establish standards for reporting information about operating segments, as well as related disclosures about products and services, geographic areas and major customers. Further, they define operating segments as components of an enterprise for which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assess performance. In determining its operating segments, Inergy examined the way it organizes its business internally for making operating decisions and assessing business performance. See Note 10 for disclosures related to Inergy’s two operating and reporting segments.

Fair Value

Cash and cash equivalents, accounts receivable (net of allowance for doubtful accounts) and payables are carried at cost, which approximates fair value due to their liquid and short-term nature. As of December 31, 2012, the estimated fair value of Inergy's fixed-rate Senior Notes, based on available trading information, totaled $11.9 million compared with the aggregate principal amount at maturity of $11.5 million. As of December 31, 2012, the estimated fair value of Inergy Midstream's fixed-rate Senior Notes, based on available trading information, totaled $515.3 million compared with the aggregate principal amount at maturity of $500.0 million. The fair value of debt was determined based on market quotes from Bloomberg. This is considered a level 1 pricing source within the fair value hierarchy. At December 31, 2012, Inergy's credit agreement (“Credit Agreement”) consists of a $550 million revolving loan facility (“Revolving Loan Facility”). The carrying value at December 31, 2012, of amounts outstanding under the Credit Agreement of $332.1 million approximate fair value due primarily to the floating interest rate associated with the Credit Agreement.  At December 31, 2012, Inergy Midstream's $600 million revolving credit facility (“NRGM Credit Facility”) had amounts outstanding of $179.8 million, which approximated fair value due primarily to the floating interest rate associated with borrowings under the NRGM Credit Facility. See Note 7 for a discussion of the Company's debt.

Assets and liabilities from price risk management are carried at fair value as discussed in Note 6. At December 31, 2012, the estimated fair value of assets, on a net basis, from price risk management activities amounted to $30.8 million and liabilities, on a net basis, from price risk management amounted to $24.2 million.

Recently Issued Accounting Pronouncements

On December 16, 2011, the Financial Accounting Standards Board issued ASU No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This ASU requires disclosures to provide information to help reconcile differences in the offsetting requirements under U.S. Generally Accepted Accounting Principles and International Financial Reporting Standards. The disclosure requirements of this ASU mandate that entities disclose both gross and net information about financial instruments and transactions eligible for offset in the statement of financial position as well as instruments and

13

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

transactions subject to an enforceable master netting arrangement or similar agreement. ASU No. 2011-11 also requires disclosure of collateral received and posted in connection with master netting arrangements or similar arrangements. The scope of this ASU includes derivative contracts, repurchase agreements, and securities borrowing and lending arrangements. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The Company is currently reviewing the effects of ASU No. 2011-11.

Note 3 – Certain Balance Sheet Information

Inventories consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
NGLs	$	56.9	$	80.8
Parts, supplies and other	6.6		6.3
Total inventory	$	63.5	$	87.1

Property, plant and equipment consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Plant equipment	$	721.1	$	619.3
Buildings, land and storage rights	594.9		513.9
Pipelines	578.1		381.3
Vehicles	45.3		44.1
Construction in process	164.7		409.6
Base gas	134.1		134.0
Salt deposits	41.6		41.6
Office furniture and equipment	18.1		16.9
	2,297.9		2,160.7
Less: accumulated depreciation	484.7		450.2
Total property, plant and equipment, net	$	1,813.2	$	1,710.5

Intangible assets consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Customer accounts	$	194.4	$	41.2
Covenants not to compete	8.3		4.2
Deferred financing and other costs	27.9		17.1
	230.6		62.5
Less: accumulated amortization	23.7		21.2
Total intangible assets, net	$	206.9	$	41.3

14

Note 4 – Business Acquisitions

On December 7, 2012, Inergy Midstream completed the acquisition of 100% of the ownership interest of Rangeland Energy, LLC in exchange for $425 million in cash, net of cash acquired in the transaction and subject to certain closing adjustments. Rangeland Energy, LLC was the owner and operator of the Crude Hub. Concurrently with the closing of the acquisition, Inergy Midstream completed the private placement of $225 million common units and $500 million of senior unsecured notes due 2020. The remaining net proceeds from these offerings were used to repay borrowings under the NRGM Credit Facility.

The primary purpose of this acquisition was to acquire the integrated crude oil loading terminal, storage, and pipeline assets of Rangeland Energy, LLC and its subsidiaries, which are located in Williams County, North Dakota. The COLT Hub primarily consists of 720,000 barrels of crude oil storage, two8,700-foot rail loops, an eight-bay truck unloading rack, and a 21-mile bi-directional crude oil pipeline that connects the hub to gathering systems and interstate crude oil pipelines. The following table summarizes the estimated fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

	December 7, 2012
Current assets	$	3.3
Property, plant and equipment	100.9
Intangible assets	157.2
Total identifiable assets acquired	261.4
Current liabilities	2.9
Total liabilities assumed	2.9
Net identifiable assets acquired	258.5
Goodwill	165.0
Net assets acquired	$	423.5

The $165.0 million of goodwill is reflected in Inergy's marketing, supply and logistics segment. Goodwill recognized in the transaction relates primarily to expanding our geographic footprint into a new growing shale play.  The name of the acquired entity has since been changed from Rangeland Energy, LLC to Inergy Crude Logistics, LLC ("ICL"). Based on the preliminary purchase price allocation, amortization expenses relative to the intangible assets acquired are expected to be $8.9 million, $10.9 million, $10.9 million, $9.8 million, and $9.5 million for the years ended September 30, 2013 through September 30, 2017, respectively.

The following represents the pro forma consolidated statements of operations as if the COLT Hub had been included in the consolidated results of the Company for the full three-month periods endedDecember 31, 2012 and 2011 (in millions):

	(Unaudited) Pro Forma Consolidated Statement of Operations
	Three Months Ended December 31,
	2012		2011
Revenue	$	443.8	$	668.6
Net income	$	1.3	$	(10.2	)

15

These amounts have been calculated after applying the Company's accounting policies and adjusting the results of Rangeland Energy, LLC to reflect the depreciation and amortization that would have been charged assuming the preliminary fair value adjustments to property, plant and equipment and intangible assets had been made at the beginning of the current period.  The purchase price allocation for this acquisition has been prepared on a preliminary basis pending final asset valuation and asset rationalization, and changes are expected when additional information becomes available. Accordingly, the purchase accounting adjustments made in connection with the development of the unaudited pro forma are preliminary and subject to change. The entities acquired were development stage entities (as defined by ASC Topic 915, Development Stage Entities) until commencing principal commercial operations in June 2012.

Note 5 – Risk Management

The Company is exposed to certain market risks related to its ongoing business operations. These risks include exposure to changing commodity prices as well as fluctuations in interest rates. The Company utilizes derivative instruments to manage its exposure to fluctuations in commodity prices, which is discussed more fully below. The Company also periodically utilizes derivative instruments to manage its exposure to fluctuations in interest rates, which is discussed more fully in Note 7. Additional information related to derivatives is provided in Note 2 and Note 6.

Commodity Derivative Instruments and Price Risk Management

Risk Management Activities

Inergy sells NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of propane. Inergy will enter into offsetting positions to economically hedge against the exposure its customer contracts create, however does not designate these instruments as hedging instruments for accounting purposes. These instruments are marked to market with the changes in the market value reflected in cost of product sold. Inergy attempts to balance its contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in cost of product sold related to these instruments.

Cash Flow Hedging Activity

Prior to the disposition of its retail propane operations, the Company entered into derivative instruments to hedge a significant portion of its exposure to fluctuations in commodity prices as a result of entering into fixed price contracts with certain of its retail customers. The Company designated these instruments as cash flow hedges. As a result of the disposition of the retail propane operations, the Company no longer anticipates utilizing cash flow hedges for commodity price risk. However, existing cash flow hedges in place at the time of the disposition will remain in OCI until the forecasted transaction takes place, the bulk of which will be in the first two quarters of fiscal 2013. The forecasted transaction is still expected to take place due to the supply arrangement with SPH.

Fair Value Hedging Activity

Inergy will enter into derivative instruments to hedge its exposure to fluctuating commodity prices that results from maintaining its NGL inventory. These instruments qualify as fair value hedges. This accounting treatment requires the fair value changes in both the derivative instruments and the hedged inventory to be recorded in cost of product sold.

A significant amount of inventory held in bulk storage facilities is hedged as it is not expected to be sold in the immediate future and is therefore exposed to fluctuations in commodity prices.

16

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Commodity Price and Credit Risk

Notional Amounts and Terms

The notional amounts and terms of the Company’s derivative financial instruments include the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	6.8	7.8	7.8	9.2
Natural gas (MMBTUs)	13.6	13.6	11.8	11.6

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect the Company’s monetary exposure to market or credit risks.

17

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Fair Value of Derivative Instruments

The following tables detail the amount and location on the Company’s consolidated balance sheets and consolidated statements of operations related to all of its commodity and debt derivatives (in millions):

	Amount of Gain (Loss) Recognized in Net Income from Derivatives
	Three Months Ended December 31,
	2012			2011
Derivatives in fair value hedging relationships:
Commodity (a)	$	2.9		$	4.3
Debt(b)	—			0.1
Total fair value of derivatives	$	2.9		$	4.4
	Amount of Gain (Loss) Recognized in Net Income on Item Being Hedged
	Three Months Ended December 31,
	2012			2011
Derivatives in fair value hedging relationships:
Commodity (a)	$	(0.8	)	$	(3.3	)
Debt(b)	—			(0.1		)
Total fair value of derivatives	$	(0.8	)	$	(3.4	)
	Amount of Gain (Loss) Recognized in OCI on Effective Portion of Derivatives
	Three Months Ended December 31,
	2012			2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	—		$	(3.2	)
Debt (e)	—			(0.1		)
Total fair value of derivatives	$	—		$	(3.3	)
	Amount of Gain (Loss) Reclassified from OCI to Net Income
	Three Months Ended December 31,
	2012			2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	(3.4	)	$	(0.7	)
Debt (e)	(0.7		)	—
Total fair value of derivatives	$	(4.1	)	$	(0.7	)

18

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

	Amount of Gain (Loss) Recognized  in Net Income on Ineffective Portion of Derivatives and Amount Excluded from Testing
	Three Months Ended December 31,
	2012		2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	—	$	—
Debt (e)	—		—
Total fair value of derivatives	$	—	$	—
	Amount of Gain (Loss) Recognized in Net Income from Derivatives
	Three Months Ended December 31,
	2012		2011
Derivatives not designated as hedging instruments:
Commodity (d)	$	5.5	$	2.8

(a) The gain (loss) on both the derivative and the item being hedged are located in cost of product sold in the consolidated statements of operations.

(b) The gain (loss) on both the derivative and the item being hedged are located in interest expense in the consolidated statements of operations.

(c) The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in cost of product sold.

(d) The gain (loss) is recognized in cost of product sold.

(e) The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in interest expense.

All contracts subject to price risk had a maturity of twenty-six months or less; however, 99% of the contracts expire within twelve months.

Credit Risk

Inherent in the Company's contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. Inergy takes an active role in managing credit risk and has established control procedures, which are reviewed on an ongoing basis. The Company attempts to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with assets from price risk management activities as of December 31, 2012 and September 30, 2012, were energy marketers and propane retailers, resellers and dealers.

Certain of the Company's derivative instruments have credit limits that require the Company to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as the Company's established credit limit with the respective counterparty. If the Company's credit rating were to change, the counterparties could require the Company to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in the Company's credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2012, is $4.0 million for which the Company has posted collateral of $3.0 million and $6.1 million of NYMEX margin deposit in the normal course of business. The Company has received collateral of $9.4 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty.

19

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 6 – Fair Value Measurements

FASB Accounting Standards Codification Subtopic 820-10 (“820-10”) establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurement) and the lowest priority to unobservable inputs (level 3 measurement). The three levels of the fair value hierarchy are as follows:

• Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.

• Level 2—Pricing inputs are other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (“OTC”) forwards, options and physical exchanges.

• Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

As of December 31, 2012, the Company held certain assets and liabilities that are required to be measured at fair value on a recurring basis. These included the Company’s derivative instruments related to heating oil, crude oil, NGLs and interest rates as well as the portion of inventory that is hedged in a qualifying fair value hedge. The Company’s derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Certain of the Company’s derivative instruments are traded on the NYMEX. These instruments have been categorized as level 1.

The Company’s derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as level 2.

The Company’s inventory that is the hedged item in a qualifying fair value hedge is valued based on prices quoted from observable sources and verified with broker quotes. This inventory has been categorized as level 2.

The Company’s OTC options are valued based on Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as level 2.

No changes in valuation techniques were made by the Company during the three months endedDecember 31, 2012.

The assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

20

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

The following tables set forth by level within the fair value hierarchy the Company's assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2012 and September 30, 2012 (in millions):

	December 31, 2012
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Designated as Hedges		Not Designated as Hedges		Netting Agreements(a)			Total
Assets
Assets from price risk management	$	2.5	$	40.4	$	—	$	42.9	$	5.7	$	37.2	$	(12.1	)	$	30.8
Inventory	—		48.4		—		48.4		—		—		—			48.4
SPH units	5.5		—		—		5.5		—		—		—			5.5
Total assets at fair value	$	8.0	$	88.8	$	—	$	96.8	$	5.7	$	37.2	$	(12.1	)	$	84.7
Liabilities
Liabilities from price risk management	$	2.9	$	30.2	$	—	$	33.1	$	4.2	$	28.9	$	(8.9	)	$	24.2
Interest rate swaps	—		6.8		—		6.8		—		—		—			—
Total liabilities at fair value	$	2.9	$	37.0	$	—	$	39.9	$	4.2	$	28.9	$	(8.9	)	$	24.2

	September 30, 2012
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Designated as Hedges		Not Designated as Hedges		Netting Agreements(a)			Total
Assets
Assets from price risk management	$	2.7	$	51.3	$	—	$	54.0	$	9.8	$	44.2	$	(16.5	)	$	37.5
Inventory	—		73.2		—		73.2		—		—		—			73.2
SPH units	5.9		—		—		5.9		—		—		—			5.9
Total assets at fair value	8.6		124.5		—		133.1		9.8		44.2		(16.5		)	116.6
Liabilities
Liabilities from price risk management	$	2.0	$	31.1	$	—	$	33.1	$	11.3	$	21.8	$	(12.2	)	$	20.9
Interest rate swap	—		7.5		—		7.5		7.5		—		—			7.5
Total liabilities at fair value	$	2.0	$	38.6	$	—	$	40.6	$	18.8	$	21.8	$	(12.2	)	$	28.4

(a) Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

21

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 7 – Long-Term Debt

Long-term debt consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Inergy credit agreement	$	332.1	$	311.7
Inergy senior unsecured notes	11.5		11.5
Inergy obligations under noncompetition agreements and notes to former owners of businesses acquired	2.9		3.5
NRGM credit facility	179.8		416.5
NRGM senior unsecured notes	500.0		—
Total debt	1,026.3		743.2
Less: current portion	2.1		3.4
Total long-term debt	$	1,024.2	$	739.8

On November 24, 2009, Inergy entered into a secured credit facility (“Credit Agreement”) which, at the time, provided borrowing capacity of up to $525 million in the form of a $450 million revolving general partnership credit facility and a $75 million working capital credit facility. The Credit Agreement was to mature on November 22, 2013.

On February 2, 2011, Inergy amended and restated the Credit Agreement to add a $300 million term loan facility. The term loan was repaid in full in December 2011 as discussed below. The term loan was to mature on February 2, 2015, and did bear interest, at Inergy's option, subject to certain limitations, at a rate equal to the following:

• the Alternate Base Rate, which is defined as the higher of (i) the federal funds rate plus 0.50%; (ii) JP Morgan’s prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 1.00% to 2.25%; or

• the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 2.00% to 3.25%.

On July 28, 2011, Inergy further amended its Credit Agreement to (i) raise the aggregate revolving commitment from $525 million to $700 million with the amount existing as a singular tranche, (ii) reduce the applicable rate on revolving loans and commitment fees, (iii) modify and refresh certain covenants and covenant baskets, and (iv) extend the maturity date from November 22, 2013 to July 28, 2016.

On April 13, 2012, Inergy further amended its Credit Agreement. This amendment, among other things, (i) permitted Inergy to sell up to 5,000,000 of the Inergy Midstream common units that Inergy owns, (ii) permitted Inergy to sell US Salt, (iii) decreased the aggregate revolving commitment and general partnership commitment from $700 million to $550 million, and (iv) adjusted several of the financial covenants.

On July 26, 2012, Inergy further amended its Credit Agreement in order to (i) permit Inergy to enter into a series of transactions as described in the Contribution Agreement dated as of April 25, 2012 among Inergy and SPH, (ii) permit Inergy to repurchase, repay or redeem all or any portion of the senior notes that remain outstanding after the closing of the Contribution Agreement,  (iii) modify certain negative and financial covenants under the Credit Agreement, and  (iv) allow Inergy to redeem, buy back or otherwise acquire up to $100 million of its common units on or prior to March 31, 2013 subject to meeting certain financial covenant requirements. This amendment did not become effective until the contribution of Inergy's retail propane assets to SPH closed on August 1, 2012. In conjunction with the close of this transaction, $1,187.0 million in Inergy senior notes were exchanged for SPH senior notes and cash paid directly to noteholders, thereby eliminating the senior notes from Inergy's consolidated balance sheet on August 1, 2012.

22

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

The Credit Agreement contains various covenants and restrictive provisions that limit its ability to, among other things:

• incur additional debt;

• make distributions on or redeem or repurchase units;

• make certain investments and acquisitions;

• incur or permit certain liens to exist;

• enter into certain types of transactions with affiliates;

• merge, consolidate or amalgamate with another company; and

• transfer or otherwise dispose of assets.

The Credit Agreement contains the following financial covenants:

• the ratio of Inergy's total funded debt (as defined in the Credit Agreement) to consolidated EBITDA (as defined in the Credit Agreement) for the four fiscal quarters most recently ended must be no greater than 4.75 to 1.0; and

• the ratio of Inergy's consolidated EBITDA to consolidated interest expense (as defined in the Credit Agreement), for the four fiscal quarters then most recently ended, must not be less than 2.50 to 1.0.

If Inergy should fail to perform its obligations under these and other covenants, the Revolving Loan Facility could be terminated and any outstanding borrowings, together with accrued interest, under the Credit Agreement could be declared immediately due and payable. The Credit Agreement also has cross default provisions that apply to any other material indebtedness of Inergy, excluding the debt of Inergy's majority-owned subsidiary, Inergy Midstream.

All borrowings under the Credit Agreement are generally secured by substantially all of Inergy's assets and the equity interests in all of Inergy's wholly owned subsidiaries, and loans thereunder bear interest, at Inergy's option, subject to certain limitations, at a rate equal to the following:

• the Alternate Base Rate, which is defined as the higher of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 0.75% to 2.00%; or

• the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 1.75% to 3.00%.

We are required to use 50% of the net cash proceeds (that are not applied to purchase replacement assets) from asset dispositions (other than the sale of inventory and motor vehicles in the ordinary course of business, sales of assets among us and our domestic subsidiaries and the sale or disposition of obsolete or worn-out equipment) to reduce borrowings under the Credit Agreement during any fiscal year in which unapplied net cash proceeds are in excess of $50 million.

At December 31, 2012, the balance outstanding under the Credit Agreement was $332.1 million. At September 30, 2012, the balance outstanding under the Credit Agreement was $311.7 million. The interest rates of the Revolving Loan Facility are based on prime rate and LIBOR plus the applicable spreads, resulting in interest rates which were between 1.96% and 4.00% at December 31, 2012, and 2.99% and 5.00% at September 30, 2012. Availability under the Credit Agreement amounted to $168.7 million and $184.0 million at December 31, 2012 and September 30, 2012, respectively. Outstanding standby letters of credit under the Credit Agreement amounted to $49.2 million and $54.3 million at December 31, 2012 and September 30, 2012, respectively.

At December 31, 2012, Inergy was in compliance with the debt covenants in the Credit Agreement and senior unsecured notes.

Inergy is party to six interest rate swap agreements scheduled to mature in 2016 to hedge its exposure to variable interest payments due under the Credit Agreement. These swap agreements require Inergy to pay the counterparty an amount based on fixed rates from 0.84% to 2.52% due quarterly. In exchange, the counterparty is required to make quarterly floating interest

23

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

rate payments on the same date to Inergy based on the three-month LIBOR applied to the same aggregate notional amount of $225.0 million. These swap agreements have been accounted for as cash flow hedges.

Inergy Midstream

NRGM Credit Facility

On December 21, 2011, Inergy Midstream entered into a $500 million, five-year revolving credit facility (“NRGM Credit Facility”). The NRGM Credit Facility is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. The NRGM Credit Facility has an accordion feature that allows Inergy Midstream to increase the available borrowings under the facility by up to $250 million, subject to the lenders' agreement and the satisfaction of certain conditions. In addition, its credit facility includes a sub-limit up to $10 million for same-day swing line advances and a sub-limit up to $100 million for letters of credit.

On April 16, 2012, Inergy Midstream exercised a portion of its accordion feature under the NRGM Credit Facility and increased the loan commitments thereunder by $100 million and as a result, the accordion feature available to Inergy Midstream is now $150 million. The aggregate amount of revolving loan commitments under the NRGM Credit Facility is now $600 million, and can be increased by up to $150 million, subject to the lenders' agreement and the satisfaction of certain conditions.

On November 16, 2012, Inergy Midstream amended its revolving credit facility to, among other things, (i) amend the definition of consolidated EBITDA to include projected consolidated EBITDA attributable to fixed fee contracts acquired in the acquisition of the COLT Hub; (ii) increase the maximum total leverage ratio to 5.50 to 1.0 for any two consecutive fiscal quarters ending on or immediately after the date of the consummation of a permitted acquisition in excess of $50 million; and (iii) add a senior secured leverage ratio of 3.75 to 1.0 on and after the cumulative issuance of $200 million or more of permitted junior debt.

At December 31, 2012, the balance outstanding under the NRGM Credit Facility was $179.8 million. At September 30, 2012, the balance outstanding under the NRGM Credit Facility was $416.5 million. Outstanding standby letters of credit under the NRGM Credit Facility amounted to $2.0 million at December 31, 2012. As a result, Inergy Midstream had approximately $418.2 million of remaining capacity at December 31, 2012, subject to compliance with any applicable covenants under such facility.

The NRGM Credit Facility contains various covenants and restrictive provisions that limit its ability to, among other things:

• incur additional debt;

• make distributions on or redeem or repurchase units;

• make certain investments and acquisitions;

• incur or permit certain liens to exist;

• enter into certain types of transactions with affiliates;

• merge, consolidate or amalgamate with another company; and

• transfer or otherwise dispose of assets.

If Inergy Midstream fails to perform its obligations under these and other covenants, the lenders' credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under its credit facility could be declared immediately due and payable. The NRGM Credit Facility also has cross default provisions that apply to any other material indebtedness of Inergy Midstream.

24

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Borrowings under the NRGM Credit Facility are generally secured by pledges of the equity interests in Inergy Midstream's wholly owned subsidiaries, liens on substantially all of its assets and guarantees issued by all of Inergy Midstream's subsidiaries. Borrowings under the NRGM Credit Facility (other than swing line loans) will bear interest at its option at either:

• the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 0.75% to 1.75% depending on our most recent total leverage ratio; or

• the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 1.75% to 2.75% depending on Inergy Midstream's most recent total leverage ratio.

Swing line loans bear interest at the Alternate Base Rate plus a margin varying from 0.75% to 1.75%. The unused portion of the NRGM Credit Facility is subject to a commitment fee ranging from 0.30% to 0.50% per annum according to its most recent total leverage ratio. Interest on Alternative Base Rate loans is payable quarterly or, if the Adjusted LIBO Rate applies, it may be paid at more frequent intervals.

The NRGM Credit Facility requires maintenance of a consolidated leverage ratio (as defined in its credit agreement) of not more than 5.00 to 1.0 (subject to increase to 5.50 to 1.0 following certain permitted acquisitions, as indicated above) and an interest coverage ratio (as defined in its credit agreement) of not less than 2.50 to 1.0. The NRGM Credit Facility also requires maintenance of a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0 on and after the cumulative issuance of $200 million or more of permitted junior debt.

NRGM Senior Notes

On December 7, 2012, Inergy Midstream and NRGM Finance Corp. (“Finance Corp.” and together with Inergy Midstream, the “Issuers”) issued and sold $500 million in a private offering in aggregate principal amount of their 6.0% Senior Notes due 2020 (the “NRGM Notes”) pursuant to a purchase agreement dated November 29, 2012. The Issuers issued the NRGM Notes pursuant to an indenture dated as of December 7, 2012 (the “Indenture”), among the Issuers, the subsidiary guarantors and U.S. Bank National Association, as trustee. The NRGM Notes will mature on December 15, 2020. Interest on the NRGM Notes is payable semi-annually in arrears on June 15 and December 15 of each year, beginning on June 15, 2013. The NRGM Notes are guaranteed on a senior unsecured basis by all of Inergy Midstream's existing subsidiaries (other than Finance Corp.) and certain of the Inergy Midstream's future subsidiaries.

The Indenture restricts Inergy Midstream's ability and the ability of its subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase Inergy Midstream's units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from Inergy Midstream's restricted subsidiaries to Inergy Midstream; (vii) consolidate, merge or transfer all or substantially all of Inergy Midstream's assets; (viii) engage in transactions with affiliates; (ix) create unrestricted subsidiaries and (x) enter into sale and leaseback transactions. These covenants are subject to a number of important exceptions and qualifications. At any time when the NRGM Notes are rated investment grade by either of Moody’s Investors Service, Inc. or Standard & Poor’s Ratings Services and no Default or Event of Default (each as defined in the Indenture) has occurred and is continuing, many of these covenants will terminate.

Inergy and its wholly owned subsidiaries do not provide credit support or guarantee any amounts outstanding under the NRGM Credit Facility or the NRGM Notes.

At December 31, 2012, Inergy Midstream was in compliance with the debt covenants in the NRGM Credit Facility and the NRGM Notes.

25

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 8 – Partners’ Capital

Class B Units

The Class B units have similar rights and obligations of Inergy common units except that the units will pay distributions in kind rather than in cash for a certain period of time. All of the outstanding Class B units converted into Inergy common units in the first quarter of fiscal 2013. There were no Class B units outstanding as of December 31, 2012. For a complete description of the Class B units, please see the Third Amended and Restated Agreement of Limited Partnership of Inergy, filed on Form 8-K on November 5, 2010.

Quarterly Distributions of Available Cash

A summary of the Company’s limited partner quarterly distribution for the three months endedDecember 31, 2012 and 2011, is presented below:

Three Months Ended December 31, 2012
Record Date	Payment Date	Per Unit Rate		Distribution Amount (in millions)
November 7, 2012	November 14, 2012	$	0.290	$	36.4
				$	36.4
Three Months Ended December 31, 2011
Record Date	Payment Date	Per Unit Rate		Distribution Amount (in millions)
November 7, 2011	November 14, 2011	$	0.705	$	83.9
				$	83.9

On January 25, 2013, Inergy declared a distribution of $0.290 per limited partner unit to be paid on February 14, 2013, to unitholders of record on February 7, 2013 with respect to the first fiscal quarter of 2013. On February 14, 2012, Inergy paid a distribution of $0.705 per limited partner unit to unitholders of record on February 7, 2012 with respect to the first fiscal quarter of 2012.

Note 9 – Commitments and Contingencies

Inergy periodically enters into agreements with suppliers to purchase fixed quantities of NGLs, distillates and natural gas at fixed prices. At December 31, 2012, the total of these firm purchase commitments was $317.2 million, all of which will occur over the course of the next twelve months. The Company also enters into non-binding agreements with suppliers to purchase quantities of NGLs, distillates and natural gas at variable prices at future dates at the then prevailing market prices.

Inergy and Inergy Midstream have entered into certain purchase commitments in connection with the identified growth projects primarily related to the Watkins Glen NGL development project and the MARC I Pipeline. The Watkins Glen NGL development project entails the conversion of certain caverns created by US Salt into 2.1 million barrels of NGL storage.  The MARC I Pipeline, which was placed into service in December 2012, is a 39 mile, 30" bi-directional pipeline that extends between the Stagecoach south lateral interconnect with Tennessee Gas Pipeline Company's 300 Line near its compressor station 319 and Transco's Leidy Line near its compressor station 517, and is capable of providing 550 MMcf/d of firm transportation capacity. At December 31, 2012, the total of Inergy's and Inergy Midstream's storage and transportation operations' firm purchase commitments was approximately $8.4 million, and the majority of the purchases associated with these commitments are expected to occur over the course of the next twelve months.

Inergy is periodically involved in litigation proceedings. The results of litigation proceedings cannot be predicted with certainty; however, management believes that Inergy does not have material potential liability in connection with these proceedings that would have a significant financial impact on its consolidated financial condition, results of operations or cash flows.

26

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

In June 2010, Inergy Midstream and CNYOG entered into a letter of intent with Anadarko Petroleum Corporation (“Anadarko”) which contemplated that, subject to certain conditions, Anadarko may exercise an option to acquire up to a 25% ownership interest in the MARC I pipeline. On September 23, 2011, Anadarko filed a complaint against the Inergy Midstream entities in the Court of Common Pleas in Lycoming County, Pennsylvania (Cause No. 11-01697) alleging that (i) Anadarko had an option to acquire, and timely exercised its option to acquire, a 25% ownership interest in the MARC I Pipeline, (ii) the Inergy Midstream entities refused to enter into definitive agreements under which Anadarko would acquire a 25% interest in the pipeline and, by doing so, the Inergy Midstream entities breached the letter of intent, and (iii) by refusing to enter into definitive agreements, the Inergy Midstream entities breached a duty of good faith and fair dealing in connection with the letter of intent. Based on these allegations, Anadarko seeks various remedies, including specific performance of the letter of intent and monetary damages.

The Inergy Midstream entities filed an answer to Anadarko's complaint on January 17, 2012 and discovery is ongoing. The Inergy Midstream entities believe that Anadarko's claims are without merit and intends to vigorously defend themselves in the lawsuit. Inergy may be required to indemnify Inergy Midstream for litigation-related costs and damages under the omnibus agreement that governs its relationship with Inergy Midstream and its general partner.

Inergy utilizes third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers' compensation claims and general, product, vehicle and environmental liability. Losses are accrued based upon management's estimates of the aggregate liability for claims incurred using certain assumptions followed in the insurance industry and based on past experience. The primary assumption utilized is actuarially determined loss development factors. The loss development factors are based primarily on historical data. Inergy's self insurance reserves could be affected if future claims development differs from the historical trends. Inergy believes changes in health care costs, trends in health care claims of its employee base, accident frequency and severity and other factors could materially affect the estimate for these liabilities. Inergy continually monitors changes in employee demographics, incident and claim type and evaluates its insurance accruals and adjusts its accruals based on its evaluation of these qualitative data points. Inergy is liable for the development of claims for its disposed retail propane operations, provided they were reported prior to August 1, 2012. At December 31, 2012 and September 30, 2012, Inergy's self-insurance reserves were $21.2 million and $23.8 million, respectively. The Company estimates that $15.0 million of this balance will be paid subsequent to December 31, 2013. As such, $15.0 million has been classified in other long-term liabilities on the consolidated balance sheets.

Note 10 – Segments

Inergy's financial statements reflect two operating and reporting segments: (i) marketing, supply and logistics operations and (ii) storage and transportation operations. Inergy's marketing, supply and logistics operations provide NGLs and crude oil marketing, supply and logistics services to producers, refiners, petrochemical companies, marketers, and others that effectively provide flow assurances to our customers. Inergy's storage and transportation operations provide natural gas and NGL storage and transportation services to third parties, as well as the production and sale of salt products.

The identifiable assets associated with each reporting segment include accounts receivable and inventories. Goodwill, property, plant and equipment and expenditures for property, plant and equipment are also presented for each segment. The net asset/liability from price risk management, as reported in the accompanying consolidated balance sheets, is primarily related to the marketing, supply and logistics segment.

27

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Revenues, gross profit, identifiable assets, goodwill, property, plant and equipment and expenditures for property, plant and equipment for each of Inergy's reporting segments are presented below (in millions):

	Three Months Ended December 31, 2012
	Marketing, Supply and Logistics Operations		Storage and Transportation Operations		Intersegment Operations		Corporate Assets		Total
Retail revenues	$	—	$	—	$	—	$	—	$	—
Marketing, supply and logistics revenues	370.8		—		—		—		370.8
Storage and transportation revenues	—		67.8		—		—		67.8
Gross profit (excluding depreciation and amortization)	32.0		48.0		—		—		80.0
Identifiable assets	235.9		29.3		—		—		265.2
Goodwill	168.8		141.8		—		20.2		330.8
Property, plant and equipment	455.7		1,835.3		—		6.9		2,297.9
Expenditures for property, plant and equipment	2.9		33.9		—		—		36.8

	Three Months Ended December 31, 2011
	Marketing, Supply and Logistics Operations		Storage and Transportation Operations		Intersegment Operations			Corporate Assets		Total
Retail revenues	$	295.0	$	—	$	—		$	—	$	295.0
Marketing, supply and logistics revenues	314.8		—		(0.4		)	—		314.4
Storage and transportation revenues	—		59.2		—			—		59.2
Gross profit (excluding depreciation and amortization)	135.5		45.3		—			—		180.8
Identifiable assets	370.5		28.6		—			—		399.1
Goodwill	339.2		141.8		—			20.2		501.2
Property, plant and equipment	1,083.5		1,575.5		—			12.5		2,671.5
Expenditures for property, plant and equipment	8.2		41.8		—			0.1		50.1

Note 11 – Condensed Consolidating Financial Information

Inergy is a holding company and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under its outstanding senior notes and credit agreement listed in Note 8 are jointly and severally guaranteed by Inergy's wholly owned domestic subsidiaries. Subsequent to Inergy Midstream's IPO on December 21, 2011, Inergy Midstream and its wholly owned subsidiaries no longer guarantee Inergy's senior notes or credit agreement.

The tables below present condensed consolidated financial statements for Inergy (parent) on a stand-alone, unconsolidated basis, and its combined guarantor and combined non-guarantor subsidiaries as of December 31, 2012 and September 30, 2012, and for the three months ended December 31, 2012 and 2011. The financial information may not necessarily be indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.

28

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Balance Sheet
December 31, 2012
(in millions)
	Parent		Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	0.1	$	1.7		$	—	$	—		$	1.8
Accounts receivable	—		178.5			23.2		—			201.7
Inventories	—		57.4			6.1		—			63.5
Other	—		40.2			9.7		—			49.9
Total current assets	0.1		277.8			39.0		—			316.9
Property, plant and equipment, net	—		831.4			981.8		—			1,813.2
Goodwill and intangible assets, net	20.2		60.3			457.2		—			537.7
Investment in subsidiary	1,468.7		—			—		(1,468.7		)	—
Other assets	—		8.3			2.8		—			11.1
Total assets	$	1,489.0	$	1,177.8		$	1,480.8	$	(1,468.7	)	$	2,678.9
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	139.3		$	4.2	$	—		$	143.5
Other	2.0		53.5			38.8		—			94.3
Total current liabilities	2.0		192.8			43.0		—			237.8
Long-term liabilities:
Long-term debt, less current portion	346.3		(0.1		)	678.0		—			1,024.2
Other long-term liabilities	27.1		15.1			0.8		—			43.0
Total long-term liabilities	373.4		15.0			678.8		—			1,067.2
Partners' capital	1,113.6		970.0			498.7		(1,468.7		)	1,113.6
Interest of non-controlling partners in subsidiary	—		—			260.3		—			260.3
Total partners' capital	1,113.6		970.0			759.0		(1,468.7		)	1,373.9
Total liabilities and partners' capital	$	1,489.0	$	1,177.8		$	1,480.8	$	(1,468.7	)	$	2,678.9

29

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Balance Sheet
September 30, 2012
(in millions)
	Parent		Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	2.9	$	(2.9	)	$	—	$	—		$	—
Accounts receivable	—		114.3			19.3		—			133.6
Inventories	—		81.5			5.6		—			87.1
Other	—		52.7			5.4		(0.3		)	57.8
Total current assets	2.9		245.6			30.3		(0.3		)	278.5
Property, plant and equipment, net	—		842.6			867.9		—			1,710.5
Goodwill and intangible assets, net	20.2		61.1			125.8		—			207.1
Investment in subsidiary	1,380.6		—			—		(1,380.6		)	—
Other assets	—		7.6			3.9		—			11.5
Total assets	$	1,403.7	$	1,156.9		$	1,027.9	$	(1,380.9	)	$	2,207.6
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	116.9		$	3.9	$	—		$	120.8
Other	4.6		61.0			52.9		(0.3		)	118.2
Total current liabilities	4.6		177.9			56.8		(0.3		)	239.0
Long-term liabilities:
Long-term debt, less current portion	324.8		—			415.0		—			739.8
Other long-term liabilities	28.1		15.1			0.8		—			44.0
Total long-term liabilities	352.9		15.1			415.8		—			783.8
Partners' capital	1,046.2		963.9			416.7		(1,380.6		)	1,046.2
Interest of non-controlling partners in subsidiary	—		—			138.6		—			138.6
Total partners' capital	1,046.2		963.9			555.3		(1,380.6		)	1,184.8
Total liabilities and partners' capital	$	1,403.7	$	1,156.9		$	1,027.9	$	(1,380.9	)	$	2,207.6

30

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Statements of Operations
Three Months Ended December 31, 2012
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenue:
Retail	$	—		$	—		$	—		$	—		$	—
Marketing, supply and logistics	—			368.0			2.8			—			370.8
Storage and transportation	—			23.6			47.6			(3.4		)	67.8
	—			391.6			50.4			(3.4		)	438.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			—			—			—			—
Marketing, supply and logistics	—			338.5			0.3			—			338.8
Storage and transportation	—			12.6			10.6			(3.4		)	19.8
	—			351.1			10.9			(3.4		)	358.6
Expenses:
Operating and administrative	—			20.8			11.7			—			32.5
Depreciation and amortization	—			21.1			15.2			—			36.3
Loss on disposal of assets	—			0.2			0.6			—			0.8
Operating income	—			(1.6		)	12.0			—			10.4
Other income (expense):
Interest expense, net	(2.6		)	—			(5.5		)	—			(8.1		)
Early extinguishment of debt	—			—			—			—			—
Gain on disposal of retail propane operations	—			—			—			—			—
Loss on Suburban Propane Partners, L.P. units	—			—			—			—			—
Other income	—			0.6			—			—			0.6
Equity in net income of subsidiary	5.4			—			—			(5.4		)	—
Income (loss) before income taxes	2.8			(1.0		)	6.5			(5.4		)	2.9
Provision for income taxes	—			0.1			—			—			0.1
Net income (loss)	2.8			(1.1		)	6.5			(5.4		)	2.8
Net income attributable to non-controlling partners in subsidiary	—			—			(1.5		)	—			(1.5		)
Net income (loss) attributable to partners	$	2.8		$	(1.1	)	$	5.0		$	(5.4	)	$	1.3

31

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Statements of Operations
Three Months Ended December 31, 2011
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenue:
Retail	$	—		$	295.0	$	—		$	—		$	295.0
Marketing, supply and logistics	—			314.4		—			—			314.4
Storage and transportation	—			14.4		46.8			(2.0		)	59.2
	—			623.8		46.8			(2.0		)	668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			178.8		—			—			178.8
Marketing, supply and logistics	—			295.1		—			—			295.1
Storage and transportation	—			4.8		11.1			(2.0		)	13.9
	—			478.7		11.1			(2.0		)	487.8
Expenses:
Operating and administrative	—			76.5		6.1			—			82.6
Depreciation and amortization	—			36.7		12.0			—			48.7
Loss on disposal of assets	—			1.4		—			—			1.4
Operating income	—			30.5		17.6			—			48.1
Other income (expense):
Interest expense, net	(28.0		)	—		—			—			(28.0		)
Early extinguishment of debt	(24.9		)	—		—			—			(24.9		)
Other income	—			1.3		—			—			1.3
Equity in net income of subsidiary	49.3			—		—			(49.3		)	—
Income (loss) before income taxes	(3.6		)	31.8		17.6			(49.3		)	(3.5		)
Provision for income taxes	—			0.1		—			—			0.1
Net income (loss)	(3.6		)	31.7		17.6			(49.3		)	(3.6		)
Net income attributable to non-controlling partners in subsidiary	—			—		(0.4		)	—			(0.4		)
Net income (loss) attributable to partners	$	(3.6	)	$	31.7	$	17.2		$	(49.3	)	$	(4.0	)

32

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Statements of Comprehensive Income
Three Months Ended December 31, 2012
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries	Eliminations		Consolidated
Net income (loss)	2.8		(1.1	)	6.5	(5.4	)	2.8
Change in unrealized fair value on cash flow hedges	0.7		3.4		—	—		4.1
Change in Suburban Propane Partners, L.P. units	(0.4	)	—		—	—		(0.4	)
Comprehensive income (loss)	3.1		2.3		6.5	(5.4	)	6.5

Condensed Consolidating Statements of Comprehensive Income
Three Months Ended December 31, 2011
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries	Eliminations		Consolidated
Net income (loss)	(3.6	)	31.7		17.6	(49.3	)	(3.6	)
Change in unrealized fair value on cash flow hedges	(0.1	)	(2.5	)	—	—		(2.6	)
Comprehensive income (loss)	(3.7	)	29.2		17.6	(49.3	)	(6.2	)

33

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Statements of Cash Flows
Three Months Ended December 31, 2012
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	—		$	5.8		$	22.2		$	—		$	28.0
Cash flows from investing activities
Acquisitions, net of cash acquired	—			0.1			(423.5		)	—			(423.4		)
Purchases of property, plant and equipment	—			(8.6		)	(43.6		)	—			(52.2		)
US Salt, LLC contribution, net	—			—			—			—			—
Payments associated with the disposal of retail propane operations	—			—			—			—			—
Other	—			—			—			—			—
Net cash used in investing activities	—			(8.5		)	(467.1		)	—			(475.6		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	—			203.2			581.1			—			784.3
Principal payments on long-term debt	—			(183.5		)	(317.8		)	—			(501.3		)
Distributions paid	(59.2		)	(36.7		)	(22.8		)	82.0			(36.7		)
Distributions paid to non-controlling partners	—			—			(7.2		)	—			(7.2		)
Distributions received	59.2			22.8			—			(82.0		)	—
Net proceeds from the issuance of common units	—			—			224.7			—			224.7
US Salt, LLC contribution, net	—			—			—			—			—
Other	(2.8		)	1.5			(13.1		)	—			(14.4		)
Net cash provided by (used in) financing activities	(2.8		)	7.3			444.9			—			449.4
Net increase (decrease) in cash	(2.8		)	4.6			—			—			1.8
Cash at beginning of period	2.9			(2.9		)	—			—			—
Cash at end of period	$	0.1		$	1.7		$	—		$	—		$	1.8

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INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Condensed Consolidating Statements of Cash Flows
Three Months Ended December 31, 2011
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	—		$	(8.7	)	$	31.9		$	—		$	23.2
Cash flows from investing activities
Acquisitions, net of cash acquired	—			(19.8		)	—			—			(19.8		)
Purchases of property, plant and equipment	—			(17.7		)	(39.4		)	—			(57.1		)
Other	—			2.7			—			—			2.7
Net cash used in investing activities	—			(34.8		)	(39.4		)	—			(74.2		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	255.0			577.7			341.8			—			1,174.5
Principal payments on long-term debt	(255.0		)	(548.2		)	(516.6		)	—			(1,319.8		)
Distributions paid	(202.1		)	(83.9		)	(118.2		)	320.3			(83.9		)
Distributions received	202.1			118.2			—			(320.3		)	—
Net proceeds from the issuance of common units	—			—			292.7			—			292.7
Other	—			(13.2		)	7.9			—			(5.3		)
Net cash provided by financing activities	—			50.6			7.6			—			58.2
Net increase in cash	—			7.1			0.1			—			7.2
Cash at beginning of period	3.0			8.5			—			—			11.5
Cash at end of period	$	3.0		$	15.6		$	0.1		$	—		$	18.7

Note 12 – Subsequent Events

The Company has identified subsequent events requiring disclosure through the date of the filing of this Form 10-Q.

On January 25, 2013, Inergy declared a distribution of $0.290 per limited partner unit to be paid on February 14, 2013, to unitholders of record on February 7, 2013.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

“Management’s Discussion and Analysis of Financial Condition and Results of Operations” should be read in conjunction with the accompanying consolidated financial statements and “Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Annual Report on Form 10-K of Inergy, L.P. for the fiscal year ended September 30, 2012. Unless the context indicates otherwise, the terms “Inergy,” “we,” “us,” “our,” “ours” and similar terms refer to Inergy, L.P. and its subsidiaries.

This report, including information included or incorporated by reference in this report, contains forward-looking statements concerning the financial condition, results of operations, plans, objectives, future performance and business of our company and its subsidiaries. These forward-looking statements include:

• statements that are not historical in nature, including, but not limited to: (i) our expectation that Inergy Midstream will grow its business in the near term through both organic growth projects and acquisitions; (ii) our belief  that anticipated cash from operations and borrowing capacity under our Credit Agreement will be sufficient to meet our liquidity needs for the foreseeable future; (iii) our belief that we do not have material potential liability in connection with legal proceedings that would have a significant financial impact on its consolidated financial condition, results of operations or cash flows; (iv) our expectation to grow our Tres Palacios operations through development projects, such as the Copano header extension project, (v) our belief that Inergy Midstream's pipelines and storage assets will continue to benefit from the development of the Marcellus shale as a significant supply basin; and

• statements preceded by, followed by or that contain forward-looking terminology including the words “believe,” “expect,” “may,” “will,” “should,” “could,” “anticipate,” “estimate,” “intend” or the negation thereof, or similar expressions.

Forward-looking statements are not guarantees of future performance or results. They involve risks, uncertainties and assumptions. Actual results may differ materially from those contemplated by the forward-looking statements due to, among others, the following factors:

• our ability to successfully implement our business plan for our assets and operations;

• governmental legislation and regulations;

• industry factors that influence the supply of, and demand for, crude oil, natural gas and NGLs;

• weather conditions;

• industry factors that influence the demand for natural gas and NGL storage and transportation capacity, particularly in the Northeast and Texas markets;

• industry factors that influence the demand for crude oil loading and storage services in the Bakken;

• economic conditions;

• the availability of crude oil, natural gas and NGLs, and the price of those commodities, to consumers relative to the price of alternative and competing fuels;

• costs or difficulties related to the integration of our existing businesses and acquisitions;

• environmental claims;

• operating hazards and other risks incidental to transporting and storing crude oil, natural gas and NGLs;

• interest rates; and

• the price and availability of debt and equity financing.

Overview

We are a publicly-traded master limited partnership that owns and operates energy midstream infrastructure and a marketing, supply and logistics business. We own and operate the Tres Palacios natural gas storage facility in Texas; a proprietary NGL business that specializes in providing supply, logistics and marketing services predominantly to producers and refiners; and approximately 66% ownership interest in Inergy Midstream, a publicly-traded, growth-oriented master limited partnership with midstream assets located in the Northeast region of the United States and in North Dakota.

Our Company

We are a midstream energy company with significant investments in the crude oil, natural gas and NGL sectors of the energy value chain. Our Tres Palacios facility is located near the liquids-rich Eagle Ford shale and Texas demand markets, and through Inergy Midstream, we have significant investments in natural gas storage and transportation facilities located near the Marcellus shale and the Northeast demand market, and crude oil loading and storage facilities located in the heart of the

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Bakken shale. We believe our marketing, supply and logistics business complements our infrastructure investments, and the combination of the expertise and proprietary knowledge developed by our marketing, supply, transportation and risk management professionals and our fleet of transportation assets provides a competitive advantage over our competitors. Inergy Midstream's acquisition of the COLT Hub assets in December 2012 is a natural extension of our refinery and producer-services business, expands Inergy Midstream's shale-focused infrastructure portfolio and diversifies Inergy Midstream's revenue mix.

Our primary business objective is to increase the cash distributions that we pay to our unitholders by growing our investment in Inergy Midstream and, to a lesser extent, growing our Texas infrastructure footprint and our marketing, supply and logistics business. We intend to position Inergy Midstream to be able to increase its cash distributions by providing strong general partner support (including, if applicable, selling assets to Inergy Midstream) and using it as the primary vehicle through which we grow our midstream business. We expect to grow our Tres Palacios operations through development projects, such as the Copano header extension project, and we believe the facility's strategic location to the Eagle Ford shale play and interconnections with 10 interstate and intrastate pipelines will allow us to capture greater revenue opportunities as natural gas prices and volatility increase. We anticipate growing our marketing, supply, and logistics business by continuing to leverage our industry knowledge, expertise and relationships to develop and harvest business opportunities, including opportunities involving the COLT Hub, and to expand our service offerings.

Our business segments include (i) storage and transportation, which includes our Tres Palacios natural gas storage facility and Inergy Midstream's natural gas and NGL storage and transportation assets (discussed below), and (ii) marketing, supply and logistics reporting segment, which includes our NGL business and Inergy Midstream's COLT Hub (discussed below). The cash flows from our Tres Palacios facility are predominantly fee-based under one to three year contracts with creditworthy counterparties. The cash flows from our NGL business represent sales to creditworthy customers typically under contracts that are less than one year in duration, and these cash flows tend to be seasonal in nature due to our customer profiles and their tendencies to purchase NGLs during peak winter periods.

Our natural gas storage revenues are driven in large part by competition and demand for our storage capacity and deliverability, although demand for firm storage service in Texas remains depressed due to low natural gas prices and low seasonal spreads. Our NGL business revenues are driven in large part by our ability to optimize NGL assets that we own or control, and provide services to producers, refiners and other customers which effectively provide flow assurance to our customers. These services offer customers certainty of NGL and crude oil supply volumes flowing without interruption and at attractive economic value.

Our long-term profitability will be influenced primarily by (i) Inergy Midstream's ability to execute on its growth strategy, including both development projects and strategic acquisitions, and to increase cash available for distribution; (ii) our ability to execute growth strategies for our Tres Palacios facility and NGL business; (iii) our ability to contract and re-contract with customers; and (iv) our ability to manage increasingly difficult regulatory processes, particularly in permitting and approval proceedings at the federal and state levels.

With respect to market trends, the assets comprising our storage and transportation segment (including the infrastructure assets of Inergy Midstream) could be negatively affected in the long term by sustained downturns or sluggishness in the economy, which could affect long-term demand and market prices for crude oil, natural gas and NGLs, all of which are beyond our control and could impair our ability to meet our long-term goals. At the same time, we believe that the contractual fee-based nature of these assets should help to reduce this risk. Development projects over the past few years have also been exposed to increased cost pressures associated with a shortage availability of skilled labor and the pricing of materials, even though we have seen some of these pressures begin to decrease in certain geographic areas. Moreover, although it has become more difficult to obtain the authorizations required to develop or expand natural gas and NGL infrastructure, we remain confident that the incremental time and money required to pursue and complete market-driven facilities will deliver meaningful value to our unitholders. The regulatory environment, combined with the location of our assets relative to both high-demand markets and prolific shale basins, effectively provides a significant barrier to entry that other market participants may find difficult to overcome.

Inergy Midstream

Inergy Midstream is a predominantly fee-based, growth-oriented limited partnership that develops, acquires, owns and operates midstream energy assets. It owns and operates natural gas and NGL storage and transportation facilities, the COLT Hub and a salt production business. Inergy Midstream owns and operates four natural gas storage facilities that have an aggregate working gas storage capacity of approximately 41.0 Bcf; natural gas pipeline facilities with 905 MMcf/d of transportation capacity; a 1.5 million barrel NGL storage facility; the COLT Hub; and US Salt, a leading solution mining and salt production company.

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Inergy Midstream's primary business objective is to increase the cash distributions that it pays to unitholders by growing its business through the development, acquisition and operation of additional midstream assets near production and demand centers. An integral part of its growth strategy is the continued development of Inergy Midstream's platform of interconnected natural gas assets in the Northeast that can be operated as an integrated storage and transportation hub. For example, because Inergy Midstream believes that storage and transportation customers value operating flexibility, it expects to increase the interconnectivity between its natural gas assets and third-party pipelines, thereby resulting in increased demand for its services. Its growth strategy is expected to reflect Inergy Midstream's desire to diversify its operations, in terms of both its geographic footprint and the type of midstream services it provides to customers. The acquisition of the COLT Hub in December 2012 diversifies Inergy Midstream's cash flow and expands its geographic footprint.

Organic growth projects, including both expansions and greenfield development projects, have recently provided cost-effective options for Inergy Midstream to grow its infrastructure base. In general, purchasers of midstream infrastructure have paid relatively high prices (measured in terms of a multiple of EBITDA or another financial metric) to acquire midstream assets and operations in recent arms-length transactions. Although the prices paid for certain types of midstream assets are likely to remain robust for the foreseeable future, acquisitions will continue to permit Inergy Midstream to gain access to new markets (with respect to geographic footprint and product offerings) and develop the scale required to grow its business quickly and successfully. We therefore expect Inergy Midstream to grow its business in the near term through both organic growth projects and acquisitions.

Inergy Midstream's operations include (i) the storage and transportation of natural gas and NGLs, (ii) US Salt's production and wholesale distribution of evaporated salt products, and (iii) the loading, storage and transportation operations conducted at or through the COLT Hub. The cash flows from its storage and transportation operations are predominantly fee-based under one to ten year contracts with creditworthy counterparties and, therefore, are generally economically stable and not significantly affected in the short term by changing commodity prices, seasonality or weather fluctuations. The cash flows from its salt operations represent sales to creditworthy customers typically under contracts that are less than one year in duration, and these cash flows tend to be relatively stable and not subject to seasonal or cyclical variation due to the use of, and demand for salt products in everyday life. The cash flows from its crude oil segment are predominantly fee-based under multi-year contracts with creditworthy counterparties and, therefore, are generally economically stable and not significantly affected in the short term by changing commodity prices, seasonality or weather fluctuations.

The majority of Inergy Midstream's operating cash flows are generated by its natural gas storage operations. Its natural gas storage revenues are driven in large part by competition and demand for storage capacity and deliverability. Demand for storage in the Northeast is projected to continue to be strong, driven by a shortage in storage capacity and a higher than average annual growth in natural gas demand. This demand growth is primarily driven by the natural gas-fired electric generation sector and conversion from petroleum-based fuels. Due to the high percentage of its cash flows generated by its natural gas storage operations, Inergy Midstream has attempted to diversify its asset base recently by developing natural gas transportation and NGL storage assets and acquiring the COLT Hub.

Inergy Midstream's ability to market available transportation capacity is impacted by supply and demand for natural gas, competition from other pipelines, natural gas price volatility, the price differential between physical locations on its pipeline systems (basis spreads), economic conditions, and other factors. Its transportation facilities have benefited from, and Inergy Midstream expects its pipelines to continue to benefit from, the development of the Marcellus shale as a significant supply basin. As LDCs and other customers increasingly utilize short-haul transportation options to satisfy their transportation needs, the location of its transportation assets relative to the Marcellus shale will enable Inergy Midstream to realize additional benefits.

Inergy Midstream's long-term profitability will be influenced primarily by (i) successfully executing its existing development projects and continuing to develop new organic growth projects in its markets; (ii) pursuing strategic acquisitions from third parties, including us, to grow its business; (iii) contracting and re-contracting storage and transportation capacity with its customers; and (iv) managing increasingly difficult regulatory processes, particularly in permitting and approval proceedings at the federal and state levels.

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How We Evaluate Our Operations

We evaluate our business performance on the basis of the following key measures:

• cash available for distribution to our unitholders;

• distributions received from Inergy Midstream;

• revenues derived from our Tres Palacios natural gas storage facility; 

• gross profit (excluding depreciation and amortization) derived from our marketing, supply and logistics business; 

• EBITDA and Adjusted EBITDA.

We do not utilize depreciation, depletion and amortization expense in our key measures because we focus our performance management on cash flow generation and our assets have long useful lives.

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Results of Operations

Three Months EndedDecember 31, 2012 Compared to Three Months EndedDecember 31, 2011

The following table summarizes the consolidated statement of operations components for the three months endedDecember 31, 2012 and 2011, respectively (in millions):

	Three Months Ended December 31,						Change
	2012			2011			In Dollars			Percentage
Revenue	$	438.6		668.6			(230.0		)	(34.4	)%
Cost of product sold	358.6			487.8			(129.2		)	(26.5	)
Gross profit (excluding depreciation and amortization)	80.0			180.8			(100.8		)	(55.8	)
Operating and administrative expenses	32.5			82.6			(50.1		)	(60.7	)
Depreciation and amortization	36.3			48.7			(12.4		)	(25.5	)
Loss on disposal of assets	0.8			1.4			(0.6		)	(42.9	)
Operating income (loss)	10.4			48.1			(37.7		)	78.4
Interest expense, net	(8.1		)	(28.0		)	19.9			71.1
Early extinguishment of debt	—			(24.9		)	24.9			100.0
Other income	0.6			1.3			(0.7		)	(53.8	)
Income (loss) before income taxes	2.9			(3.5		)	6.4			182.9
Provision for income taxes	0.1			0.1			—			—
Net income (loss)	2.8			(3.6		)	6.4			177.8
Net (income) loss attributable to non-controlling partners	(1.5		)	(0.4		)	(1.1		)	(275.0	)
Net income (loss) attributable to partners	$	1.3		$	(4.0	)	$	5.3		132.5	%

Volume. We did not report retail gallons sold for the three months endedDecember 31, 2012, compared to 89.3 million retail gallons sold during the three months endedDecember 31, 2011 due to the contribution of our retail business to Suburban Propane Partners, L.P. (“SPH”) on August 1, 2012. Gallons sold or processed related to our marketing, supply and logistics business increased172.5 million gallons, or 76.9%, to 396.9 million gallons in the three months endedDecember 31, 2012, from 224.4 million gallons in the same three-month period in 2011.  This increase in gallons sold or processed was driven by an increase relating to gallons sold to new and existing customers, including volumes sold to SPH, and an increase in Y-grade sales during the three months ended December 31, 2012 as a result of increased production at certain facilities for which we marketed 100% of the production during both the three months ended December 31, 2012 and 2011, respectively. Also contributing to this increase was higher throughput and fractionated volumes processed at our West Coast NGL operations of approximately 70.1 million gallons, which was partially a result of operational expansion of that facility in fiscal 2012.

For our storage and transportation business, the available capacity at Inergy Midstream's Stagecoach, Steuben and Thomas Corners storage facilities was 100% sold on a firm basis during the three month periods ended December 31, 2012 and 2011, respectively. The Seneca Lake storage facility was 100% and 72% contracted on a firm basis during the three months ended December 31, 2012 and 2011, respectively. The MARC I Pipeline, which was placed into service on December 1, 2012, was 82% contracted during the period in which it was in service and the Bath NGL storage facility was approximately 100% contracted (for storage or forward sales) during both the three month periods ended December 31, 2012 and 2011, respectively. Our Tres Palacios storage facility was approximately 53% contracted on a firm basis (87% and 83% contracted on a firm and interruptible basis) during the three months ended December 31, 2012 and 2011, respectively. As of December 31, 2012, 59% of the COLT Hub's rail loading capacity (or, giving effect to contracted throughput increases described below, 89%) was sold under long-term take-or-pay contracts with minimum throughput commitments.  A majority of customer contracts for rail loading capacity increase through the duration of the contracts to where contractual rail loading commitments approximate the rail loading capacity of the facility.

Revenues. Revenues for the three months endedDecember 31, 2012, were $438.6 million, a decrease of $230.0 million, or 34.4%, from $668.6 million during the same three-month period in 2011.

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We did not report revenue from retail sales for the three months endedDecember 31, 2012, compared to $295.0 million during the same three-month period in 2011 due to the contribution of our retail business to SPH on August 1, 2012. As a result, there were no retail revenues for the current year period.

Marketing, supply and logistics revenues were $370.8 million for the three months endedDecember 31, 2012, an increase of $56.4 million, or 17.9%, from $314.4 million during the same three-month period in 2011. This increase was driven by several factors, including the following: (i) an increase of $116.2 million resulting from increased volumes sold to new and existing marketing customers, including SPH, and increased natural gas liquid gallons sold or processed at our West Coast NGL operations; (ii) an increase in Y-grade sales of $15.8 million during the three months ended December 31, 2012 as a result of increased production at certain facilities for which we marketed 100% of the production; (iii) an increase of approximately $9.2 million arising from acquisition related revenues; and (iv) an increase of approximately $5.8 million in our legacy transportation business, a portion of which related to additional sales to SPH after the close of the contribution of our retail propane business to SPH and a portion related to increased shale activity, including the Marcellus and Utica shales. These increases were partially offset by a decrease of $90.6 million due to lower commodity market prices during the three months ended December 31, 2012 compared to the same prior year period.

Revenues from storage and transportation were $67.8 million for the three months endedDecember 31, 2012, an increase of $8.6 million or 14.5% from $59.2 million during the same three-month period in 2011. Storage and transportation revenues increased $2.8 million and $1.8 million, respectively, due to the placement into service of the MARC I Pipeline and North-South Facilities. Additionally, revenues at Tres Palacios increased $1.3 million due to an increase in demand for hub services at the facility partially offset by a decrease in firm storage services related to non-renewal of certain firm storage contracts. Revenues also increased approximately $8.5 million due to higher commodity sales at the Bath facility. These increases in storage and transportation revenues were partially offset by a $4.0 million reduction derived from changes in the amount of capacity held on TGP's 300 Line and a $1.8 million decrease arising from lesser interruptible wheeling services, lower storage revenues at certain of our storage facilities and a reduction in salt revenues.

Cost of Product Sold. Cost of product sold for the three months endedDecember 31, 2012, was $358.6 million, a decrease of $129.2 million, or 26.5%, from $487.8 million during the same three-month period in 2011.

We did not report retail cost of product sold for the three months endedDecember 31, 2012, compared to $178.8 million during the same three-month period in 2011 due to the contribution of our retail business as discussed above.

Marketing, supply and logistics cost of product sold was $338.8 million for the three months endedDecember 31, 2012, an increase of $43.7 million, or 14.8%, from $295.1 million during the same three-month period in 2011. Costs increased approximately $128.7 million due to the higher sales volumes discussed above related to additional volumes sold to new and existing marketing customers, including SPH, and increased volume sold or processed at our West Coast NGL operations and the Y-Grade business at certain production facilities. Also contributing to the higher cost of product sold were costs related to acquisitions of $4.8 million and higher costs in our transportation business of $3.2 million related to the increased trucking business as discussed above. These increases were partially offset by a $93.0 million decrease due to lower commodity purchase prices during the three months ended December 31, 2012 as compared to the three months ended December 31, 2011.

Storage and transportation cost of product sold was $19.8 million for the three months endedDecember 31, 2012, an increase of $5.9 million or 42.4% from $13.9 million during the same three-month period in 2011. Storage and transportation cost of product sold increased approximately $5.7 million primarily as a result of commodity sold from the Bath facility as discussed above. Also contributing to the increase was higher power costs at the Tres Palacios facility, which were directly related to the increased hub services as discussed above.

Our retail and marketing, supply and logistics cost of product sold consists primarily of tangible products sold including all propane, distillates and other NGLs sold and all propane-related appliances sold. Other costs incurred in conjunction with the distribution of these products are included in operating and administrative expenses and consist primarily of wages to delivery personnel, delivery vehicle costs consisting of fuel costs, repair and maintenance and lease expense. Costs associated with delivery vehicles approximated $3.3 million and $19.2 million for the three months endedDecember 31, 2012 and 2011, respectively. In addition, the depreciation expense associated with the delivery vehicles, customer tanks and other plant equipment is reported within depreciation and amortization expense and amounted to $12.0 million and $17.1 million for the three months endedDecember 31, 2012 and 2011, respectively. Since we include these costs in our operating and administrative expense and depreciation and amortization expense rather than in cost of product sold, our results may not be comparable to other entities in our lines of business if they include these costs in cost of product sold. The decrease in these costs compared to the prior period is primarily due to the contribution of our retail propane operations to SPH on August 1, 2012.

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Our storage and transportation cost of product sold consists primarily of commodity and transportation costs. Other costs incurred in conjunction with these services are included in operating and administrative expense and depreciation and amortization expense and consist primarily of depreciation, vehicle costs consisting of fuel costs and repair and maintenance and wages. Depreciation expense for storage and pipeline transportation services amounted to $19.1 million and $16.9 million for the three months endedDecember 31, 2012 and 2011, respectively. Vehicle costs and wages for personnel directly involved in providing storage and pipeline transportation services amounted to $1.5 million and $0.9 million for the three months endedDecember 31, 2012 and 2011, respectively. Since we include these costs in our operating and administrative expense and depreciation and amortization expense rather than in cost of product sold, our results may not be comparable to other entities in our lines of business if they include these costs in cost of product sold.

Gross Profit (Excluding Depreciation and Amortization). Gross profit for the three months endedDecember 31, 2012, was $80.0 million, a decrease of $100.8 million, or 55.8%, from $180.8 million during the same three-month period in 2011.

There was no retail gross profit for the three months endedDecember 31, 2012, compared to $116.2 million during the same three-month period in 2011 due to the contribution of our retail business in fiscal 2012 as further discussed above.

Marketing, supply and logistics gross profit was $32.0 million for the three months endedDecember 31, 2012, an increase of $12.7 million, or 65.8%, from $19.3 million during the same three-month period in 2011. Marketing, supply and logistics gross profit increased $3.3 million due to the increased marketing, supply and West Coast sales volumes as further discussed above and $2.4 million as a result of higher average margins. Also contributing to higher gross profit were acquisitions and increased volumes in our trucking business, which contributed approximately $4.4 million and $2.6 million, respectively.

Storage and transportation gross profit was $48.0 million for the three months endedDecember 31, 2012, an increase of $2.7 million or 6.0% from $45.3 million during the same three-month period in 2011. Storage and transportation gross profit increased $2.8 million primarily due to commodity sales at the Bath facility as further discussed above, partially offset by slightly lower gross profit for other storage and transportation businesses.

Operating and Administrative Expenses.  Operating and administrative expenses were $32.5 million for the three months endedDecember 31, 2012, compared to $82.6 million for the three months endedDecember 31, 2011, a decrease of $50.1 million, or 60.7%.  This decrease was primarily due to the contribution of our retail business in fiscal 2012 as further discussed above. Partially offsetting this decrease was a $2.8 million increase in transaction costs primarily from the acquisition of the COLT Hub and an increase of $2.1 million due to acquisitions.

Depreciation and Amortization. Depreciation and amortization was $36.3 million for the three months endedDecember 31, 2012, compared to $48.7 million during the three months endedDecember 31, 2011. This $12.4 million, or 25.5%, decrease was primarily due to the contribution of our retail business in fiscal 2012 as further discussed above. Partially offsetting this decrease was an increase related to acquisitions and the placing of Inergy Midstream assets into service during the three months endedDecember 31, 2012.

Interest Expense. Interest expense was $8.1 million for the three months endedDecember 31, 2012, compared to $28.0 million during the three months endedDecember 31, 2011. This $19.9 million, or 71.1%, decrease was due to a decline in average outstanding borrowings and average interest rate incurred, both due primarily to debt retired in conjunction with the contribution of our retail business in fiscal 2012. Additionally, during the three months endedDecember 31, 2011 and 2011, we capitalized $3.1 million and $3.4 million, respectively, of interest related to certain capital improvement projects in our storage and transportation segment as further described below in the “Liquidity and Sources of Capital” section.

Early Extinguishment of Debt. During the three months endedDecember 31, 2012, we did not incur any costs associated with the early extinguishment of debt. During the three months endedDecember 31, 2011, we paid in full the $300 million balance outstanding on our term loan facility, tendered substantially all the $95 million outstanding on our 2015 senior notes and tendered for $150 million of the $750 million outstanding on our 2021 senior notes. The loss associated with the above described transactions amounted to $24.9 million and was primarily related to the tender premiums and the write-off of previously capitalized charges associated with the original issuance of the respective debt.

Provision for Income Taxes.  The provision for income taxes for three months endedDecember 31, 2012, was $0.1 million compared to $0.1 million for the three months endedDecember 31, 2011. The provision for income taxes for the three months endedDecember 31, 2012, was composed of $0.4 million of current income tax expense partially offset by $0.3 million of deferred income tax benefit.

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Net Income (Loss). Net income was $2.8 million for the three months endedDecember 31, 2012, compared to a net loss of $(3.6) million for the three months endedDecember 31, 2011. The $6.4 million increase in net income was primarily attributable to a $24.9 million decrease in charges related to the early extinguishment of debt, a $19.9 million decrease in interest expense and the lower operating and administrative expenses and depreciation and amortization primarily resulting from the contribution of our retail business in fiscal 2012 as further discussed above, partially offset by a decrease in gross profit resulting from the contribution of our retail operations.

Net (Income) Loss Attributable to Non-Controlling Partners. The earnings of non-controlling partners of $1.5 million and for the three months endedDecember 31, 2012, solely relates to an approximate 34% minority interest in Inergy Midstream's net income. The net income attributable to non-controlling interest for the three months endedDecember 31, 2011 of $0.4 million solely related to the 24.8% minority interest in Inergy Midstream's net income for the ten day period from the closing of Inergy Midstream's IPO to the end of the quarter.

EBITDA and Adjusted EBITDA. The following tables summarize EBITDA and Adjusted EBITDA for the three months endedDecember 31, 2012 and 2011, respectively (in millions):

	Three Months Ended December 31,
	2012		2011
EBITDA:
Net income (loss)	$	2.8	$	(3.6	)
Interest expense, net	8.1		28.0
Early extinguishment of debt	—		24.9
Provision for income taxes	0.1		0.1
Depreciation and amortization	36.3		48.7
EBITDA	$	47.3	$	98.1
Non-cash loss on derivative contracts	3.4		0.1
Long-term incentive and equity compensation expense	3.1		3.1
Loss on disposal of assets	0.8		1.4
Transaction costs	2.8		—
Adjusted EBITDA	$	57.4	$	102.7

43

	Three Months Ended December 31,
	2012			2011
EBITDA:
Net cash provided by operating activities	$	28.0		$	23.2
Net changes in working capital balances	18.1			36.0
Non-cash early extinguishment of debt	—			(8.3		)
Provision for doubtful accounts	(0.1		)	0.1
Amortization of deferred financing costs, swap premium and net bond discount	(3.3		)	(1.5		)
Long-term incentive and equity compensation expense	(3.1		)	(3.1		)
Loss on disposal of assets	(0.8		)	(1.4		)
Deferred income tax	0.3			0.1
Interest expense, net	8.1			28.0
Early extinguishment of debt	—			24.9
Provision for income taxes	0.1			0.1
EBITDA	$	47.3		$	98.1
Non-cash loss on derivative contracts	3.4			0.1
Long-term incentive and equity compensation expense	3.1			3.1
Loss on disposal of assets	0.8			1.4
Transaction costs	2.8			—
Adjusted EBITDA	$	57.4		$	102.7

EBITDA is defined as income before income taxes, plus net interest expense, early extinguishment of debt and depreciation and amortization expense. As indicated in the table, Adjusted EBITDA represents EBITDA excluding the gain or loss on derivative contracts associated with retail propane fixed price sales contracts, long-term incentive and equity compensation expenses, the gain or loss on the disposal of assets and transaction costs. Transaction costs are third party professional fees and other costs that are incurred in conjunction with closing a transaction. EBITDA and Adjusted EBITDA should not be considered an alternative to net income, income before income taxes, cash flows from operating activities, or any other measure of financial performance calculated in accordance with generally accepted accounting principles as those items are used to measure operating performance, liquidity or the ability to service debt obligations. We believe that EBITDA provides additional information for evaluating our ability to make the quarterly distribution and is presented solely as a supplemental measure. We believe that Adjusted EBITDA provides additional information for evaluating our financial performance without regard to our financing methods, capital structure and historical cost basis. EBITDA and Adjusted EBITDA, as we define them, may not be comparable to EBITDA and Adjusted EBITDA or similarly titled measures used by other corporations or partnerships.

Liquidity and Sources of Capital

Cash Flows and Contractual Obligations

Net operating cash inflows were $28.0 million and $23.2 million for the three-month periods ending December 31, 2012 and 2011, respectively. The $4.8 million increase in operating cash flows was primarily attributable to a decrease of $16.6 million in cash cost of early extinguishment of debt, a $25.2 million decrease in cash interest expense and a $50.1 million decline in cash operating expenses. These increases in operating cash flows were offset by a $100.8 million decline in gross profit. The remainder of the increase in operating cash flows was attributable to other changes in working capital items, including the timing of payments on payables and the collection of receivables.      

Net investing cash outflows were $475.6 million and $74.2 million for the three-month periods ending December 31, 2012 and 2011, respectively. Net cash outflows were primarily impacted by a $403.6 million increase in cash outlays related to acquisitions as well as a $2.7 million decrease in proceeds from the sale of assets, partially offset by a $4.9 million decrease in capital expenditures.

44

Net financing cash inflows were $449.4 million and $58.2 million for the three-month periods ending December 31, 2012 and 2011, respectively. The net change was primarily impacted by a $428.3 million increase in net borrowings along with a $47.2 million decrease in distributions. Partially offsetting these increases was a decrease of $68.0 million in net proceeds from the issuance of Inergy Midstream common units.

We believe that anticipated cash from operations and borrowing capacity under our Credit Agreement will be sufficient to meet our liquidity needs for the foreseeable future. If our plans or assumptions change or are inaccurate, or we make acquisitions, we may need to raise additional capital. While global financial markets and economic conditions have been disrupted and volatile in the past, the conditions have improved more recently. However, we give no assurance that we can raise additional capital to meet these needs. We have identified capital expansion project opportunities in our storage and transportation operations. As of December 31, 2012, we have firm purchase commitments totaling approximately $0.5 million related to certain of our growth projects, and Inergy Midstream has firm purchase commitments totaling approximately $7.9 million related to certain of its growth projects. Additional commitments or expenditures, if any, we may make toward any one or more of these projects are at our discretion. Any discontinuation of the construction of these projects will likely result in less future cash flow and earnings.

See Note 7 for a description of our Credit Agreement, the NRGM Credit Facility and the NRGM Notes.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

We have a revolving line of credit subject to the risk of loss associated with movements in interest rates. At December 31, 2012, we had floating rate obligations totaling $107.1 million borrowed under our revolving line of credit (net of certain interest rate swaps, which convert our revolving line of credit to a fixed rate). Inergy Midstream also has a revolving credit facility subject to the risk of loss associated with movements in interest rates. At December 31, 2012, Inergy Midstream had floating rate obligations totaling $179.8 million. Floating rate obligations expose us and Inergy Midstream to the risk of increased interest expense in the event of increases in short-term interest rates.

If the floating rate were to fluctuate by 100 basis points from December 2012 levels, our interest expenditures would change by a total of approximately $1.1 million per year. If the floating rate of Inergy Midstream's revolving line of credit were to fluctuate by 100 basis points from December 2012 levels, Inergy Midstream's interest expense would change by approximately $1.8 million per year.

Commodity Price, Market and Credit Risk

Inherent in our marketing, supply and logistics business are certain business risks, including market risk and credit risk. Market risk is the risk that the value of the portfolio will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. We take an active role in managing and controlling market and credit risk and have established control procedures, which are reviewed on an ongoing basis. We monitor market risk through a variety of techniques, including daily reporting of the portfolio’s position to senior management. We attempt to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with assets from price risk management activities as of December 31, 2012 and 2011, were energy marketers, propane retailers, resellers, and dealers.

We engage in hedging and risk management transactions, including various types of forward contracts, options, swaps and futures contracts, to reduce the effect of price volatility on our product costs, protect the value of our inventory positions and to help ensure the availability of propane during periods of short supply. We attempt to balance our contractual portfolio by purchasing volumes only when we have a matching purchase commitment from our marketing customers. However, we may experience net unbalanced positions from time to time, which we believe to be immaterial in amount. In addition to our ongoing policy to maintain a balanced position, for accounting purposes we are required, on an ongoing basis, to track and report the market value of our derivative portfolio.

We rarely take title to any commodity in our storage and transportation business.

45

Fair Value

The fair value of the derivatives and inventory exchange contracts related to price risk management activities as of December 31, 2012, and September 30, 2012, were assets of $30.8 million and $37.5 million, respectively, and liabilities of $24.2 million and $20.9 million, respectively.

We use observable market values for determining the fair value of our trading instruments. In cases where actively quoted prices are not available, other external sources are used that incorporate information about commodity prices in actively quoted markets, quoted prices in less active markets and other market fundamental analysis. Our risk management department regularly compares valuations to independent sources and models on a quarterly basis.

Sensitivity Analysis

A theoretical change of 10% in the underlying commodity value would result in a $0.3 million change in the market value of the contracts as there were 3.1 million gallons of net unbalanced positions at December 31, 2012.

Item 4. Controls and Procedures

We maintain controls and procedures designed to provide a reasonable assurance that information required to be disclosed in our reports that we file or submit under the Securities Exchange Act of 1934 are recorded, processed, summarized and reported within the time periods specified by the rules and forms of the SEC, and that information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure. An evaluation was performed under the supervision and with the participation of our management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as such terms are defined in Rule 13a-15(e) and 15d-15(e) of the Exchange Act). Based upon that evaluation, management, including the Chief Executive Officer and the Chief Financial Officer, concluded that our disclosure controls and procedures were effective as of December 31, 2012, at the reasonable assurance level. There have been no changes in our internal control over financial reporting except as discussed below (as defined in Rule 13(a)-15(f) or Rule 15d-15(f) of the Exchange Act) during the period ended December 31, 2012, that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

Changes in Internal Control over Financial Reporting

In fiscal 2013, we completed the acquisition of the COLT Hub. See Note 4 “Business Acquisitions” for a discussion of the acquisition and related financial data.

We are currently in the process of evaluating the internal controls and procedures of our current acquisition. Further, we are in the process of integrating their operations. Management will continue to evaluate our internal control over financial reporting as we execute integration activities, however, integration activities could materially affect our internal control over financial reporting in future periods.

46

PART II – OTHER INFORMATION

Item 1. Legal Proceedings

Part I, Item 1. Financial Statements, Note 9 to the Consolidated Financial Statements, of this Form 10-Q is hereby incorporated herein by reference.

Item 1A. Risk Factors

In addition to the risk factors disclosed in "Item 1A, Risk Factors" in the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2012, we have the following risk factors related to the acquisition of the COLT Hub.

Our profitability depends on the volume of crude oil handled by the COLT Hub. 

The COLT Hub is located in the heart of the Bakken shale oil-producing play and generates fee-based revenues under multiyear contracts by providing crude oil storage, transportation and terminal services, including rail loading and truck loading/unloading services.  A material decrease in crude oil production or refining, as a result of depressed commodity prices, natural decline rates attributable to oil reservoirs, a decrease in exploration and development activities or otherwise, could adversely impact Inergy Midstream's ability to execute or renew contracts with customers and, in turn, result in a decline in the volume of crude oil processed by the COLT Hub.  Our profitability could be materially impacted by a decline in the volume of crude oil loaded, stored or transported by the COLT Hub.

Demand for crude oil is dependent upon numerous factors, including price, the impact of future economic conditions, fuel conservation measures, alternative fuel requirements, governmental regulation or technological advances in fuel economy and energy generation devices, all of which could impact demand.  Fluctuations in demand for crude oil, such as fluctuations caused by refinery downtime or shutdown, can have a negative effect on our operating results.  Reduced demand in the Bakken play can negatively affect the throughput on the COLT Hub.  In addition, the crude oil volumes that support the COLT Hub are dependent on the level of product from crude oil wells in the Williston basin (including the Bakken and Three Fork plays).  We have no control over the level of drilling or production activity in these plays, the amount of reserves in these plays, or the rate at which production will decline in these plays.  Sustained reductions in exploration or production activity in the Bakken, or in the price of Bakken crude oil relative to crude oil from other production basins or plays, could lead to reduced utilization of the COLT Hub.

The COLT Hub faces intense competition.

Competitors of the COLT Hub primarily include crude oil pipelines, independent terminal developers, and other midstream companies of varying sizes, financial resources and experience. Certain competitors have capital resources many times greater than ours and control (or otherwise have access to) greater volumes of crude oil. 

Pipelines are generally the lowest-cost method for shipping crude oil, whereas rail can provide a cost-efficient alternative for transporting crude oil over long distances and trucks are typically limited to short-haul movements due to significant cost escalation with distance.  Today, inadequate pipeline infrastructure exists to cost-effectively transport Bakken crude oil supplies to premium demand markets along the East and West coasts.  Rail primarily bridges the gap created by this takeaway capacity constraint and, in this regard, rail plays a critical role in the overall transportation solution designed to move these crude oil supplies to market.  As additional crude oil pipelines are constructed over time, pipelines may displace rail as the preferred long-haul option for moving Bakken crude oil to premium demand markets.  If the crude oil pipelines required to alleviate the existing infrastructure constraints develop sooner than anticipated (in turn displacing the demand for rail takeaway capacity sooner than expected), then the volumes of crude oil transported, stored and loaded through the COLT Hub may decrease.  Our profitability could be materially impacted by an earlier-than-forecast decline in the volume of crude oil served by the COLT Hub.

In addition, there are low barriers to entry with respect to the development, construction and operation of crude oil loading and storage terminals in the Bakken similar to the COLT Hub.  These low barriers to entry, together with the lack of pipeline infrastructure necessary to cost-effectively move crude oil volumes to premium demand markets, has resulted in multiple crude oil terminals being constructed or proposed.  Accordingly, to the extent competing crude oil rail and storage terminals are constructed and alternate rail options become availability to shippers, the COLT Hub could be adversely affected by increased competition.

47

A change in the jurisdictional characterization of the COLT Hub by federal, state or local regulatory agencies could result in increased regulation, which could affect existing costs and rates.

The COLT Hub includes (i) the COLT terminal, which consists primarily of 600,000 barrels of crude oil storage, two 8,700-foot rail loops, an eight-bay truck unloading rack and crude oil gathering system interconnects; (ii) the Dry Fork terminal, which consists primarily of 120,000 barrels of crude oil storage and interconnections with the Enbridge and Tesoro crude oil pipelines, and (iii) the COLT Connector, a 21-mile, 10-inch bidirectional crude oil pipeline that connects the COLT and Dry Fork terminals. Intrastate crude oil pipelines that do not provide interstate service are not subject to regulation by the FERC.  However, the distinction between FERC-regulated interstate pipeline transportation and intrastate pipeline transportation is a fact-based determination. The classification and regulation of the COLT Connector is subject to change based on future determinations by FERC, federal courts, Congress or regulatory commissions, courts or legislatures in North Dakota.

The COLT Connector moves crude oil owned by third parties either from the COLT terminal's storage tanks to the Dry Fork storage tank, or from the Dry Fork storage tank to the COLT terminal's storage tanks.  Inergy Midstream believes the existing configuration and use of the COLT Hub and the services it provides to third parties satisfy the traditional tests that FERC has used to determine that the COLT crude oil facilities and services are not in interstate commerce.  However, Inergy Midstream cannot provide assurance that FERC will not in the future, either at the request of other entities or on its own initiative, determine that some or all of our crude oil pipeline facilities and the services Inergy Midstream provides through the COLT Hub are within its jurisdiction, or that such a determination would not adversely affect Inergy Midstream's results of operations.  If some or all of the COLT Hub becomes subject to FERC jurisdiction, and not otherwise exempt from any applicable regulatory requirements, ICL would be required to file a tariff with FERC and, if ICL's tariff rates were subject to protest, provide a cost justification for the transportation rate subject to protest and provide service to all potential shippers without undue discrimination.  In addition, if the services Inergy Midstream provides through the COLT Hub regulated by FERC under the Interstate Commerce Act, the COLT Hub services could be subject to a protest and/or complaint before FERC.  If FERC were to determine, in response to a complaint, that the rates are unjust and unreasonable, ICL could be required to pay reparations and refunds dating to two years before the filing of the complaint. Furthermore, if in the future services offered by the COLT Hub become subject to substantive state regulation, they could be subject to a protest and/or complaint before the North Dakota Public Service Commission.

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

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

48

Item 6. Exhibits

2.1	Securities Purchase Agreement, dated as of November 3, 2012, among Rangeland Equity Holdings, LLC and Inergy Midstream, L.P. (incorporated herein by reference to Exhibit 2.1 to Inergy, L.P.'s Form 8-K filed on November 5, 2012)
3.1	Certificate of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Registration Statement on Form S-1 (Registration No. 333-56976) filed on March 14, 2001)
3.1A	Certificate of Correction of Certificate of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on May 12, 2003)
3.2	Second Amended and Restated Agreement of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on February 13, 2004)
3.2A	Amendment No. 1 to Second Amended and Restated Agreement of Limited Partnership of Inergy L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Form 10-Q filed on May 14, 2004)
3.2B	Amendment No. 2 to Second Amended and Restated Agreement of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on January 24, 2005)
3.2C	Amendment No. 3 to Second Amended and Restated Agreement of Limited Partnership of Inergy, L.P. (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K/A filed on August 17, 2005)
3.2D	Third Amended and Restated Agreement of Limited Partnership of Inergy, L.P., dated as of November 5, 2010 (incorporated herein by reference to Exhibit 3.1 to Inergy, L.P.'s Form 8-K filed on November 5, 2010)
3.3	Certificate of Formation of Inergy GP, LLC (incorporated herein by reference to Exhibit 3.5 to Inergy, L.P.'s Registration Statement on Form S-1/A (Registration No. 333-56976) filed on May 7, 2001)
3.4	Limited Liability Company Agreement of Inergy GP, LLC (incorporated herein by reference to Exhibit 3.6 to Inergy, L.P.'s Registration Statement on Form S-1/A (Registration No. 333-56976) filed on May 7, 2001)
10.1	Common Unit Purchase Agreement, dated as of November 3, 2012, among Inergy Midstream, L.P. and the Purchasers named therein (incorporated herein by reference to Exhibit 10.1 to Inergy, L.P.'s Form 8-K filed on November 5, 2012)
*31.1	Certification of Chief Executive Officer of Inergy, L.P. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*31.2	Certification of Chief Financial Officer of Inergy, L.P. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*32.1	Certification of Chief Executive Officer of Inergy, L.P. pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
*32.2	Certification of Chief Financial Officer of Inergy, L.P. pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
**101.INS	XBRL Instance Document
**101.SCH	XBRL Taxonomy Extension Schema Document
**101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
**101.LAB	XBRL Taxonomy Extension Label Linkbase Document
**101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document
**101.DEF	XBRL Taxonomy Extension Definition Linkbase Document

*

Filed herewith

**

Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

49

SIGNATURE

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		INERGY, L.P.
		By:	INERGY GP, LLC
			(its general partner)
Date:	February 5, 2013	By:	/s/ MICHAEL J. CAMPBELL
			Michael J. Campbell
			Senior Vice President and Chief Financial Officer
			(Duly Authorized Officer and Principal Financial Officer)

50

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, John J. Sherman, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Inergy, L.P. (the “registrant”);

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 the financial reporting (as defined in Exchange Act Rules 13a-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 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 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: February 5, 2013

/s/ John J. Sherman

John J. Sherman

Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Michael J. Campbell, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Inergy, L.P. (the “registrant”);

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 the financial reporting (as defined in Exchange Act Rules 13a-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 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 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: February 5, 2013

/s/ Michael J. Campbell

Michael J. Campbell

Senior Vice President and Chief Financial Officer

EX-32.1

Exhibit 32.1

Certification of the Chief Executive Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Inergy, L.P. (the “Company”) on Form 10-Q for the period ended December 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John J. Sherman, Chief Executive Officer of Inergy, L.P., certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ John J. Sherman

John J. Sherman

Chief Executive Officer

February 5, 2013

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

Certification of the Chief Financial Officer

Pursuant to 18 U.S.C. Section 1350

As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Inergy, L.P. (the “Company”) on Form 10-Q for the period ended December 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael J. Campbell, Chief Financial Officer of Inergy, L.P., certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Michael J. Campbell

Michael J. Campbell

Chief Financial Officer

February 5, 2013

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Business Acquisitions (Pro Forma Revenues) (Details) (Rangeland Energy, LLC, USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Rangeland Energy, LLC
Business Acquisition [Line Items]
Revenue	$ 443.8	$ 668.6
Net income	$ 1.3	$ (10.2)

XML

Subsequent Events (Detail) (USD $)	0 Months Ended	3 Months Ended			0 Months Ended
	Feb. 14, 2012	Dec. 31, 2012	Dec. 31, 2011	Jun. 30, 2011	Jan. 25, 2013 Subsequent event
Subsequent Event [Line Items]
Declared distribution date					Jan. 25, 2013
Distribution declared per unit					$ 0.290
Distribution payable date	Feb. 14, 2012	Nov. 14, 2012	Nov. 14, 2011		Feb. 14, 2013
Record Date		Nov. 07, 2012	Nov. 07, 2011	Feb. 07, 2012	Feb. 07, 2013

XML

Commitments and Contingencies (Detail) (USD $) In Millions, unless otherwise specified			3 Months Ended			0 Months Ended	1 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2012 Watkins Glen Ngl Development Project bbl	Dec. 31, 2012 Marc I Pipeline in mi	Dec. 31, 2012 Identified Growth Projects	Sep. 23, 2011 Marc I Pipeline Anadarko	Jun. 30, 2010 Marc I Pipeline Anadarko	Dec. 31, 2012 Commodity
Purchase Commitment, Excluding Long-term Commitment [Line Items]
Firm purchase commitments					$ 8.4			$ 317.2
Storage capacity barrels			2,100,000
Pipeline Length (in miles)				39
Diameter of Pipeline (in inches)				30
Expected minimum firm transportation capacity, in dekatherms per day				550
Counterparty Option To Purchase Maximum Ownership Interest						25.00%	25.00%
Self-insurance reserves	21.2	23.8
Self-insurance reserve expected to be paid in next fiscal year	$ 15.0

XML

Partners' Capital (Narrative) (Detail) (USD $)	0 Months Ended	3 Months Ended			0 Months Ended
	Feb. 14, 2012	Dec. 31, 2012	Dec. 31, 2011	Jun. 30, 2011	Jan. 25, 2013 Subsequent event
Distribution Made to Member or Limited Partner [Line Items]
Declared distribution date					Jan. 25, 2013
Distribution declared per unit					$ 0.290
Payment Date	Feb. 14, 2012	Nov. 14, 2012	Nov. 14, 2011		Feb. 14, 2013
Per Unit Rate	$ 0.705	$ 0.290
Record Date		Nov. 07, 2012	Nov. 07, 2011	Feb. 07, 2012	Feb. 07, 2013

XML

Summary of Significant Accounting Policies (Estimated Economic Lives Of Intangible Assets) (Detail)	3 Months Ended
	Dec. 31, 2012
Minimum | Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, weighted average useful life	15 years
Minimum | Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, weighted average useful life	2 years
Minimum | Deferred financing costs
Finite-Lived Intangible Assets [Line Items]
Intangible assets, weighted average useful life	4 years
Maximum | Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, weighted average useful life	20 years
Maximum | Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, weighted average useful life	10 years
Maximum | Deferred financing costs
Finite-Lived Intangible Assets [Line Items]
Intangible assets, weighted average useful life	10 years

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Risk Management (Tables)

3 Months Ended

Dec. 31, 2012

Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]

Notional Amounts And Terms Of Company's Derivative Financial Instruments

The notional amounts and terms of the Company’s derivative financial instruments include the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	6.8	7.8	7.8	9.2
Natural gas (MMBTUs)	13.6	13.6	11.8	11.6

Summary Of Fair Value Of Derivative Instruments

The following tables detail the amount and location on the Company’s consolidated balance sheets and consolidated statements of operations related to all of its commodity and debt derivatives (in millions):

	Amount of Gain (Loss) Recognized in Net Income from Derivatives
	Three Months Ended December 31,
	2012			2011
Derivatives in fair value hedging relationships:
Commodity (a)	$	2.9		$	4.3
Debt(b)	—			0.1
Total fair value of derivatives	$	2.9		$	4.4
	Amount of Gain (Loss) Recognized in Net Income on Item Being Hedged
	Three Months Ended December 31,
	2012			2011
Derivatives in fair value hedging relationships:
Commodity (a)	$	(0.8	)	$	(3.3	)
Debt(b)	—			(0.1		)
Total fair value of derivatives	$	(0.8	)	$	(3.4	)
	Amount of Gain (Loss) Recognized in OCI on Effective Portion of Derivatives
	Three Months Ended December 31,
	2012			2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	—		$	(3.2	)
Debt (e)	—			(0.1		)
Total fair value of derivatives	$	—		$	(3.3	)
	Amount of Gain (Loss) Reclassified from OCI to Net Income
	Three Months Ended December 31,
	2012			2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	(3.4	)	$	(0.7	)
Debt (e)	(0.7		)	—
Total fair value of derivatives	$	(4.1	)	$	(0.7	)

	Amount of Gain (Loss) Recognized  in Net Income on Ineffective Portion of Derivatives and Amount Excluded from Testing
	Three Months Ended December 31,
	2012		2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	—	$	—
Debt (e)	—		—
Total fair value of derivatives	$	—	$	—
	Amount of Gain (Loss) Recognized in Net Income from Derivatives
	Three Months Ended December 31,
	2012		2011
Derivatives not designated as hedging instruments:
Commodity (d)	$	5.5	$	2.8

(a) The gain (loss) on both the derivative and the item being hedged are located in cost of product sold in the consolidated statements of operations.

(b) The gain (loss) on both the derivative and the item being hedged are located in interest expense in the consolidated statements of operations.

(c) The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in cost of product sold.

(d) The gain (loss) is recognized in cost of product sold.

(e) The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in interest expense.

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Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheet) (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2011
Current assets:
Cash and cash equivalents	$ 1.8	$ 0	$ 18.7	$ 11.5
Accounts receivable	201.7	133.6
Inventories	63.5	87.1
Total current assets	316.9	278.5
Property, plant and equipment, net	1,813.2	1,710.5
Other assets	11.1	11.5
Total assets	2,678.9	2,207.6
Current liabilities:
Accounts payable	143.5	120.8
Total current liabilities	237.8	239.0
Long-term liabilities:
Long-term debt, less current portion	1,024.2	739.8
Other long-term liabilities	22.7	23.4
Partners' capital	1,113.6	1,046.2
Interest of non-controlling partners in subsidiary	260.3	138.6
Total partners’ capital	1,373.9	1,184.8
Total liabilities and partners’ capital	2,678.9	2,207.6
Parent Company
Current assets:
Cash and cash equivalents	0.1	2.9	3.0	3.0
Accounts receivable	0	0
Inventories	0	0
Other	0	0
Total current assets	0.1	2.9
Property, plant and equipment, net	0	0
Goodwill and intangible assets, net	20.2	20.2
Investment in subsidiary	1,468.7	1,380.6
Other assets	0	0
Total assets	1,489.0	1,403.7
Current liabilities:
Accounts payable	0	0
Other	2.0	4.6
Total current liabilities	2.0	4.6
Long-term liabilities:
Long-term debt, less current portion	346.3	324.8
Other long-term liabilities	27.1	28.1
Total long-term liabilities	373.4	352.9
Partners' capital	1,113.6	1,046.2
Interest of non-controlling partners in subsidiary	0	0
Total partners’ capital	1,113.6	1,046.2
Total liabilities and partners’ capital	1,489.0	1,403.7
Guarantor Subsidiaries
Current assets:
Cash and cash equivalents	1.7	(2.9)	15.6	8.5
Accounts receivable	178.5	114.3
Inventories	57.4	81.5
Other	40.2	52.7
Total current assets	277.8	245.6
Property, plant and equipment, net	831.4	842.6
Goodwill and intangible assets, net	60.3	61.1
Investment in subsidiary	0	0
Other assets	8.3	7.6
Total assets	1,177.8	1,156.9
Current liabilities:
Accounts payable	139.3	116.9
Other	53.5	61.0
Total current liabilities	192.8	177.9
Long-term liabilities:
Long-term debt, less current portion	(0.1)	0
Other long-term liabilities	15.1	15.1
Total long-term liabilities	15.0	15.1
Partners' capital	970.0	963.9
Interest of non-controlling partners in subsidiary	0	0
Total partners’ capital	970.0	963.9
Total liabilities and partners’ capital	1,177.8	1,156.9
Non-Guarantor Subsidiaries
Current assets:
Cash and cash equivalents	0	0	0.1	0
Accounts receivable	23.2	19.3
Inventories	6.1	5.6
Other	9.7	5.4
Total current assets	39.0	30.3
Property, plant and equipment, net	981.8	867.9
Goodwill and intangible assets, net	457.2	125.8
Investment in subsidiary	0	0
Other assets	2.8	3.9
Total assets	1,480.8	1,027.9
Current liabilities:
Accounts payable	4.2	3.9
Other	38.8	52.9
Total current liabilities	43.0	56.8
Long-term liabilities:
Long-term debt, less current portion	678.0	415.0
Other long-term liabilities	0.8	0.8
Total long-term liabilities	678.8	415.8
Partners' capital	498.7	416.7
Interest of non-controlling partners in subsidiary	260.3	138.6
Total partners’ capital	759.0	555.3
Total liabilities and partners’ capital	1,480.8	1,027.9
Consolidation, Eliminations
Current assets:
Cash and cash equivalents	0	0	0	0
Accounts receivable	0	0
Inventories	0	0
Other	0	(0.3)
Total current assets	0	(0.3)
Property, plant and equipment, net	0	0
Goodwill and intangible assets, net	0	0
Investment in subsidiary	(1,468.7)	(1,380.6)
Other assets	0	0
Total assets	(1,468.7)	(1,380.9)
Current liabilities:
Accounts payable	0	0
Other	0	(0.3)
Total current liabilities	0	(0.3)
Long-term liabilities:
Long-term debt, less current portion	0	0
Other long-term liabilities	0	0
Total long-term liabilities	0	0
Partners' capital	(1,468.7)	(1,380.6)
Interest of non-controlling partners in subsidiary	0	0
Total partners’ capital	(1,468.7)	(1,380.6)
Total liabilities and partners’ capital	(1,468.7)	(1,380.9)
Consolidated Entities
Current assets:
Cash and cash equivalents	1.8	0	18.7	11.5
Accounts receivable	201.7	133.6
Inventories	63.5	87.1
Other	49.9	57.8
Total current assets	316.9	278.5
Property, plant and equipment, net	1,813.2	1,710.5
Goodwill and intangible assets, net	537.7	207.1
Investment in subsidiary	0	0
Other assets	11.1	11.5
Total assets	2,678.9	2,207.6
Current liabilities:
Accounts payable	143.5	120.8
Other	94.3	118.2
Total current liabilities	237.8	239.0
Long-term liabilities:
Long-term debt, less current portion	1,024.2	739.8
Other long-term liabilities	43.0	44.0
Total long-term liabilities	1,067.2	783.8
Partners' capital	1,113.6	1,046.2
Interest of non-controlling partners in subsidiary	260.3	138.6
Total partners’ capital	1,373.9	1,184.8
Total liabilities and partners’ capital	$ 2,678.9	$ 2,207.6

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Risk Management (Summary Of Fair Value Of Derivative Instruments) (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012		Dec. 31, 2011
Derivative [Line Items]
Change in Unrealized Gain (Loss) on Hedged Item in Fair Value Hedge	$ 4.1		$ (2.6)
Fair Value Hedging | Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in Net Income from Derivatives	2.9		4.4
Change in Unrealized Gain (Loss) on Hedged Item in Fair Value Hedge	0.8		3.4
Cash Flow Hedging | Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in OCI on Effective Portion of Derivatives	0		(3.3)
Amount of Gain (Loss) Reclassified from OCI to Net Income	(4.1)		(0.7)
Amount of Gain (Loss) Recognized in Net Income on Ineffective Portion of Derivatives and Amount Excluded from Testing	0		0
Commodity contract | Not Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in Net Income from Derivatives	5.5	[1]	2.8	[1]
Commodity contract | Fair Value Hedging | Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in Net Income from Derivatives	2.9	[2]	4.3	[2]
Change in Unrealized Gain (Loss) on Hedged Item in Fair Value Hedge	0.8	[2]	3.3	[2]
Commodity contract | Cash Flow Hedging | Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in OCI on Effective Portion of Derivatives	0	[3]	(3.2)	[3]
Amount of Gain (Loss) Reclassified from OCI to Net Income	(3.4)	[3]	(0.7)	[3]
Amount of Gain (Loss) Recognized in Net Income on Ineffective Portion of Derivatives and Amount Excluded from Testing	0	[3]	0	[3]
Interest rate contract | Fair Value Hedging | Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in Net Income from Derivatives	0	[4]	0.1	[4]
Change in Unrealized Gain (Loss) on Hedged Item in Fair Value Hedge	0	[4]	0.1	[4]
Interest rate contract | Cash Flow Hedging | Designated as Hedges
Derivative [Line Items]
Amount of Gain (Loss) Recognized in OCI on Effective Portion of Derivatives	0	[5]	(0.1)	[5]
Amount of Gain (Loss) Reclassified from OCI to Net Income	(0.7)	[5]	0	[5]
Amount of Gain (Loss) Recognized in Net Income on Ineffective Portion of Derivatives and Amount Excluded from Testing	$ 0	[5]	$ 0	[5]

[1] The gain (loss) is recognized in cost of product sold.

[2] The gain (loss) on both the derivative and the item being hedged are located in cost of product sold in the consolidated statements of operations.

[3] The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in cost of product sold.

[4] The gain (loss) on both the derivative and the item being hedged are located in interest expense in the consolidated statements of operations.

[5] The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in interest expense.

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Business Acquisitions (Narrative) (Details) (USD $)							3 Months Ended		0 Months Ended
	Dec. 31, 2012	Dec. 07, 2012	Sep. 30, 2012	Dec. 31, 2011	Dec. 07, 2012 Senior Notes	Dec. 31, 2012 Rangeland Energy, LLC	Dec. 31, 2012 COLT Hub [Member] bbl mi rail_loops	Dec. 07, 2012 COLT Hub [Member] ft truck_bays	Dec. 07, 2012 Inergy Midstream Common units	Dec. 07, 2012 Inergy Midstream Rangeland Energy, LLC
Business Acquisition [Line Items]
Percentage of voting interests acquired										100.00%
Cash acquisition, net of cash acquired										$ 425,000,000
Proceeds from issuance of private placement common units									225,000,000
Unsecured debt					500,000,000
Goodwill	330,800,000	165,000,000	165,800,000	501,200,000
Crude Oil Storage Capacity							720,000
Number of Rail Loops							2
Length of Rail Loops								8,700
Storage Facility, Number of Truck Bays								8
Pipeline Length (in miles)							21
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
2013						8,900,000
2014						10,900,000
2015						10,900,000
2016						9,800,000
2017 and thereafter						$ 9,500,000

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Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Cash Flows) (Detail) (USD $)	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities	$ 28,000,000	$ 23,200,000
Cash flows from investing activities:
Acquisitions, net of cash acquired	(423,400,000)	(19,800,000)
Purchases of property, plant and equipment	(52,200,000)	(57,100,000)
Net cash used in investing activities	(475,600,000)	(74,200,000)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	203,200,000	577,700,000
Principal payments on long-term debt	(183,500,000)	(803,200,000)
Distributions	(36,700,000)	(83,900,000)
Distributions paid to non-controlling partners	(7,200,000)	0
Net cash provided by financing activities	449,400,000	58,200,000
Net increase in cash	1,800,000	7,200,000
Cash at beginning of period	0	11,500,000
Cash at end of period	1,800,000	18,700,000
Parent Company
Cash flows from operating activities	0	0
Cash flows from investing activities:
Acquisitions, net of cash acquired	0	0
Purchases of property, plant and equipment	0	0
US Salt, LLC contribution, net	0
Payments associated with the disposal of retail propane operations	0
Other	0	0
Net cash used in investing activities	0	0
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0	255,000,000
Principal payments on long-term debt	0	(255,000,000)
Distributions	(59,200,000)	(202,100,000)
Distributions paid to non-controlling partners	0
Distributions received	59,200,000	202,100,000
Net proceeds from the issuance of common units	0	0
US Salt, LLC contribution, net	0
Other	(2,800,000)	0
Net cash provided by financing activities	(2,800,000)	0
Net increase in cash	(2,800,000)	0
Cash at beginning of period	2,900,000	3,000,000
Cash at end of period	100,000	3,000,000
Guarantor Subsidiaries
Cash flows from operating activities	5,800,000	(8,700,000)
Cash flows from investing activities:
Acquisitions, net of cash acquired	100,000	(19,800,000)
Purchases of property, plant and equipment	(8,600,000)	(17,700,000)
US Salt, LLC contribution, net	0
Payments associated with the disposal of retail propane operations	0
Other	0	2,700,000
Net cash used in investing activities	(8,500,000)	(34,800,000)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	203,200,000	577,700,000
Principal payments on long-term debt	(183,500,000)	(548,200,000)
Distributions	(36,700,000)	(83,900,000)
Distributions paid to non-controlling partners	0
Distributions received	22,800,000	118,200,000
Net proceeds from the issuance of common units	0	0
US Salt, LLC contribution, net	0
Other	1,500,000	(13,200,000)
Net cash provided by financing activities	7,300,000	50,600,000
Net increase in cash	4,600,000	7,100,000
Cash at beginning of period	(2,900,000)	8,500,000
Cash at end of period	1,700,000	15,600,000
Non-Guarantor Subsidiaries
Cash flows from operating activities	22,200,000	31,900,000
Cash flows from investing activities:
Acquisitions, net of cash acquired	(423,500,000)	0
Purchases of property, plant and equipment	(43,600,000)	(39,400,000)
US Salt, LLC contribution, net	0
Payments associated with the disposal of retail propane operations	0
Other	0	0
Net cash used in investing activities	(467,100,000)	(39,400,000)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	581,100,000	341,800,000
Principal payments on long-term debt	(317,800,000)	(516,600,000)
Distributions	(22,800,000)	(118,200,000)
Distributions paid to non-controlling partners	(7,200,000)
Distributions received	0	0
Net proceeds from the issuance of common units	224,700,000	292,700,000
US Salt, LLC contribution, net	0
Other	(13,100,000)	7,900,000
Net cash provided by financing activities	444,900,000	7,600,000
Net increase in cash	0	100,000
Cash at beginning of period	0	0
Cash at end of period	0	100,000
Consolidation, Eliminations
Cash flows from operating activities	0	0
Cash flows from investing activities:
Acquisitions, net of cash acquired	0	0
Purchases of property, plant and equipment	0	0
US Salt, LLC contribution, net	0
Other	0	0
Net cash used in investing activities	0	0
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	0	0
Principal payments on long-term debt	0	0
Distributions	82,000,000	320,300,000
Distributions paid to non-controlling partners	0
Distributions received	(82,000,000)	(320,300,000)
Net proceeds from the issuance of common units	0	0
US Salt, LLC contribution, net	0
Other	0	0
Net cash provided by financing activities	0	0
Net increase in cash	0	0
Cash at beginning of period	0	0
Cash at end of period	0	0
Consolidated Entities
Cash flows from operating activities	28,000,000	23,200,000
Cash flows from investing activities:
Acquisitions, net of cash acquired	(423,400,000)	(19,800,000)
Purchases of property, plant and equipment	(52,200,000)	(57,100,000)
US Salt, LLC contribution, net	0
Payments associated with the disposal of retail propane operations	0
Other	0	2,700,000
Net cash used in investing activities	(475,600,000)	(74,200,000)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	784,300,000	1,174,500,000
Principal payments on long-term debt	(501,300,000)	(1,319,800,000)
Distributions	(36,700,000)	(83,900,000)
Distributions paid to non-controlling partners	(7,200,000)
Distributions received	0	0
Net proceeds from the issuance of common units	224,700,000	292,700,000
US Salt, LLC contribution, net	0
Other	(14,400,000)	(5,300,000)
Net cash provided by financing activities	449,400,000	58,200,000
Net increase in cash	1,800,000	7,200,000
Cash at beginning of period	0	11,500,000
Cash at end of period	$ 1,800,000	$ 18,700,000

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Partners' Capital (Summary Of Quarterly Distributions Of Available Cash) (Detail) (USD $) In Millions, except Per Share data, unless otherwise specified	0 Months Ended	3 Months Ended
	Feb. 14, 2012	Dec. 31, 2012	Dec. 31, 2011	Jun. 30, 2011
Partners' Capital Account, Distributions [Abstract]
Record Date		Nov. 07, 2012	Nov. 07, 2011	Feb. 07, 2012
Payment Date	Feb. 14, 2012	Nov. 14, 2012	Nov. 14, 2011
Per Unit Rate	$ 0.705	$ 0.290
Distribution Amount		$ 36.4	$ 83.9

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Summary of Significant Accounting Policies

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Financial Instruments and Price Risk Management

Inergy utilizes certain derivative financial instruments to (i) manage its exposure to commodity price risk, specifically, the related change in the fair value of inventories, as well as the variability of cash flows related to forecasted transactions; (ii) ensure adequate physical supply of commodity will be available; and (iii) manage its exposure to interest rate risk associated with fixed and variable rate borrowings. Inergy records all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded either through current earnings or as other comprehensive income, depending on the type of transaction.

Inergy is party to certain commodity derivative financial instruments that are designated as hedges of selected inventory positions, and qualify as fair value hedges. Inergy is also periodically party to certain interest rate swap agreements designed to manage interest rate risk exposure. Inergy’s overall objective for entering into fair value hedges is to manage its exposure to fluctuations in commodity prices and changes in the fair market value of its inventories and fixed and variable rate borrowings. The commodity derivatives are recorded at fair value on the balance sheets as price risk management assets or liabilities and the related change in fair value is recorded to earnings in the current period as cost of product sold. The interest rate derivatives are recorded at fair value on the balance sheets in other assets or liabilities and the related change in fair value is recorded to earnings in the current period as interest expense.

Any ineffective portion of the fair value hedges is recognized as cost of product sold in the current period. Inergy recognized net gains of $2.1 million and $1.0 million in the three months ended December 31, 2012 and 2011, respectively, related to the ineffective portion of its fair value hedging instruments. In addition, Inergy recognized no gain or loss for the three months endedDecember 31, 2012 and 2011, related to the portion of fair value hedging instruments that it excluded from its assessment of hedge effectiveness.

Inergy also enters into derivative financial instruments that qualify as cash flow hedges, which hedge the exposure of variability in expected future cash flows predominantly attributable to forecasted purchases to supply fixed price sale contracts and variable interest payments. These derivatives are recorded on the balance sheet at fair value as price risk management assets or liabilities. The effective portion of the gain or loss on these cash flow hedges is recorded in other comprehensive income in partner's capital and reclassified into earnings in the same period in which the hedge transaction affects earnings. In certain situations under the rules, the ineffective portion of the gain or loss is recognized as cost of product sold in the current period. Accumulated other comprehensive loss was $11.2 million and $14.9 million at December 31, 2012 and September 30, 2012, respectively. Included in accumulated other comprehensive loss at December 31, 2012 was a loss of $3.9 million attributable to commodity instruments, a loss of $6.9 million attributable to interest rate swaps, and a loss of $0.4 million attributable to SPH units. Approximately $3.6 million is expected to be reclassified to earnings from other comprehensive income over the next twelve months.

Inergy’s policy is to offset fair value amounts of derivative instruments and cash collateral paid or received with the same counterparty under a master netting arrangement.

The cash flow impact of derivative financial instruments is reflected as cash flows from operating activities in the consolidated statements of cash flows.

Revenue Recognition

Sales of NGLs and salt are recognized at the time product is shipped or delivered to the customer depending on the sales terms. NGL processing and fractionation fees are recognized upon delivery of the product. Revenues from the COLT Hub are recognized when the contractual services are provided, such as loading of customer rail cars. Revenues from storage and transportation contracts are recognized during the period in which the storage and transportation services are provided, such as loading of customer rail cars.

Expense Classification

Cost of product sold consists of tangible products sold including NGLs and salt, as well as certain direct costs incurred in providing storage and transportation services (period ended December 31, 2011 also includes costs of tangible product associated with retail propane sales). Operating and administrative expenses consist of all expenses incurred other than those described above in cost of product sold and depreciation and amortization. Certain operating and administrative expenses and depreciation and amortization are incurred in the distribution of the product sales and storage sales but are not included in cost of product sold. These amounts were $35.9 million and $54.1 million for the three months ended December 31, 2012 and 2011, respectively.

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the periods presented. Actual results could differ from those estimates.

Inventories

Inventories for marketing, supply and logistics operations, which mainly consist of NGLs, are stated at the lower of cost or market and are computed using the average cost method. These inventories are designated under a fair value hedge program and are consequently marked to market. NGL inventories being hedged and carried at market value at December 31, 2012 and September 30, 2012, amount to $48.4 million and $73.2 million, respectively. Inventories for storage and transportation operations are stated at the lower of cost or market and are computed predominantly using the average cost method.

Shipping and Handling Costs

Shipping and handling costs are recorded as part of cost of product sold at the time product is shipped or delivered to the customer except as discussed in “Expense Classification.”

Property, Plant and Equipment

Property, plant and equipment are stated at historical cost less accumulated depreciation. Inergy capitalizes all construction-related direct labor and material costs as well as the cost of funds used during construction. Amounts capitalized for cost of funds used during construction amounted to $3.1 million and $3.4 million for the three months ended December 31, 2012 and 2011, respectively. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:

	Years
Land, buildings and improvements	15 – 70
Office furniture and equipment	3 – 7
Vehicles	3 – 10
Pipelines	15
Tanks and plant equipment	3 – 30
Base gas	10

Salt deposits are depleted on a unit of production method.

Identifiable Intangible Assets

The Company has recorded certain identifiable intangible assets, including customer accounts, covenants not to compete and deferred financing costs. Customer accounts and covenants not to compete have arisen from acquisitions. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt. Additionally, an acquired intangible asset should be separately recognized if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer's intent to do so.

Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows:

	Years
Customer accounts	15 - 20
Covenants not to compete	2 - 10
Deferred financing costs	4 - 10

Goodwill

Goodwill is recognized for various acquisitions as the excess of the cost of the acquisitions over the fair value of the related net assets at the date of acquisition. Goodwill is subject to at least an annual assessment for impairment by applying a fair-value-based test.

Inergy completed its annual impairment test for each of its reporting units and determined that no impairment existed as of September 30, 2012. No indicators of impairment were identified requiring an interim impairment test during the three-month period ended December 31, 2012.

Income Taxes

Inergy is a publicly-traded master limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. Inergy Sales and Service, Inc. (“Services”), a subsidiary of Inergy, does not generate at least 90% of its gross income from qualifying sources, and as such, federal and state income taxes are provided on the taxable income of Services. The earnings of the Company and its limited liability subsidiaries are included in the Federal and state income tax returns of the individual members or partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes for Inergy have been included in the accompanying financial statements as income taxes due to the nature of the tax in those particular states. In addition, Federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities (IPCHA and Services). The Company is required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which differences are expected to reverse.

Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.

Sales Tax

Inergy accounts for the collection and remittance of sales tax on a net tax basis. As a result, these amounts are not reflected in the consolidated statements of operations.

Income Per Unit

Inergy calculates basic net income per limited partner unit by utilizing the two class method. Diluted net income per limited partner unit is computed by dividing net income by the weighted-average number of units outstanding and the effect of dilutive units granted under the Long Term Incentive Plan and the Class B units. All outstanding Class B units converted to common units during the quarter ended December 31, 2012. No Class B units were outstanding as of December 31, 2012.

Asset Retirement Obligations

An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. The fair value of certain AROs could not be made as settlement dates (or range of dates) associated with these assets were not estimable.

Accounting for Unit-Based Compensation

Inergy sponsors a Long Term Incentive Plan and all share-based payments to employees, including grants of employee stock options, are recognized in the consolidated statements of operations based on their fair values.

The amount of compensation expense recorded by the Company was $3.1 million and $3.1 million during the three months endedDecember 31, 2012 and 2011, respectively.

Segment Information

There are certain accounting requirements that establish standards for reporting information about operating segments, as well as related disclosures about products and services, geographic areas and major customers. Further, they define operating segments as components of an enterprise for which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assess performance. In determining its operating segments, Inergy examined the way it organizes its business internally for making operating decisions and assessing business performance. See Note 10 for disclosures related to Inergy’s two operating and reporting segments.

Fair Value

Cash and cash equivalents, accounts receivable (net of allowance for doubtful accounts) and payables are carried at cost, which approximates fair value due to their liquid and short-term nature. As of December 31, 2012, the estimated fair value of Inergy's fixed-rate Senior Notes, based on available trading information, totaled $11.9 million compared with the aggregate principal amount at maturity of $11.5 million. As of December 31, 2012, the estimated fair value of Inergy Midstream's fixed-rate Senior Notes, based on available trading information, totaled $515.3 million compared with the aggregate principal amount at maturity of $500.0 million. The fair value of debt was determined based on market quotes from Bloomberg. This is considered a level 1 pricing source within the fair value hierarchy. At December 31, 2012, Inergy's credit agreement (“Credit Agreement”) consists of a $550 million revolving loan facility (“Revolving Loan Facility”). The carrying value at December 31, 2012, of amounts outstanding under the Credit Agreement of $332.1 million approximate fair value due primarily to the floating interest rate associated with the Credit Agreement.  At December 31, 2012, Inergy Midstream's $600 million revolving credit facility (“NRGM Credit Facility”) had amounts outstanding of $179.8 million, which approximated fair value due primarily to the floating interest rate associated with borrowings under the NRGM Credit Facility. See Note 7 for a discussion of the Company's debt.

Assets and liabilities from price risk management are carried at fair value as discussed in Note 6. At December 31, 2012, the estimated fair value of assets, on a net basis, from price risk management activities amounted to $30.8 million and liabilities, on a net basis, from price risk management amounted to $24.2 million.

Recently Issued Accounting Pronouncements

On December 16, 2011, the Financial Accounting Standards Board issued ASU No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This ASU requires disclosures to provide information to help reconcile differences in the offsetting requirements under U.S. Generally Accepted Accounting Principles and International Financial Reporting Standards. The disclosure requirements of this ASU mandate that entities disclose both gross and net information about financial instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an enforceable master netting arrangement or similar agreement. ASU No. 2011-11 also requires disclosure of collateral received and posted in connection with master netting arrangements or similar arrangements. The scope of this ASU includes derivative contracts, repurchase agreements, and securities borrowing and lending arrangements. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The Company is currently reviewing the effects of ASU No. 2011-11.

XML

Risk Management (Narrative) (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012
Derivative [Line Items]
Collateral posted for commodity derivative instruments	9.4
Commodity contract
Derivative [Line Items]
Aggregate fair value of commodity derivative instruments	4.0
Collateral posted for commodity derivative instruments	3.0
NYMEX margin deposit
Derivative [Line Items]
NYMEX margin deposit	6.1
Price Risk Contracts | Maximum
Derivative [Line Items]
Derivative, Remaining Maturity	26 months
Derivative Contracts, Contracts Expiring in Next Twleve Months, Percent	99.00%

XML

Condensed Consolidating Financial Information (Tables)

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Condensed Consolidating Balance Sheet

Condensed Consolidating Balance Sheet
December 31, 2012
(in millions)
	Parent		Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	0.1	$	1.7		$	—	$	—		$	1.8
Accounts receivable	—		178.5			23.2		—			201.7
Inventories	—		57.4			6.1		—			63.5
Other	—		40.2			9.7		—			49.9
Total current assets	0.1		277.8			39.0		—			316.9
Property, plant and equipment, net	—		831.4			981.8		—			1,813.2
Goodwill and intangible assets, net	20.2		60.3			457.2		—			537.7
Investment in subsidiary	1,468.7		—			—		(1,468.7		)	—
Other assets	—		8.3			2.8		—			11.1
Total assets	$	1,489.0	$	1,177.8		$	1,480.8	$	(1,468.7	)	$	2,678.9
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	139.3		$	4.2	$	—		$	143.5
Other	2.0		53.5			38.8		—			94.3
Total current liabilities	2.0		192.8			43.0		—			237.8
Long-term liabilities:
Long-term debt, less current portion	346.3		(0.1		)	678.0		—			1,024.2
Other long-term liabilities	27.1		15.1			0.8		—			43.0
Total long-term liabilities	373.4		15.0			678.8		—			1,067.2
Partners' capital	1,113.6		970.0			498.7		(1,468.7		)	1,113.6
Interest of non-controlling partners in subsidiary	—		—			260.3		—			260.3
Total partners' capital	1,113.6		970.0			759.0		(1,468.7		)	1,373.9
Total liabilities and partners' capital	$	1,489.0	$	1,177.8		$	1,480.8	$	(1,468.7	)	$	2,678.9

Condensed Consolidating Balance Sheet
September 30, 2012
(in millions)
	Parent		Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	2.9	$	(2.9	)	$	—	$	—		$	—
Accounts receivable	—		114.3			19.3		—			133.6
Inventories	—		81.5			5.6		—			87.1
Other	—		52.7			5.4		(0.3		)	57.8
Total current assets	2.9		245.6			30.3		(0.3		)	278.5
Property, plant and equipment, net	—		842.6			867.9		—			1,710.5
Goodwill and intangible assets, net	20.2		61.1			125.8		—			207.1
Investment in subsidiary	1,380.6		—			—		(1,380.6		)	—
Other assets	—		7.6			3.9		—			11.5
Total assets	$	1,403.7	$	1,156.9		$	1,027.9	$	(1,380.9	)	$	2,207.6
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	116.9		$	3.9	$	—		$	120.8
Other	4.6		61.0			52.9		(0.3		)	118.2
Total current liabilities	4.6		177.9			56.8		(0.3		)	239.0
Long-term liabilities:
Long-term debt, less current portion	324.8		—			415.0		—			739.8
Other long-term liabilities	28.1		15.1			0.8		—			44.0
Total long-term liabilities	352.9		15.1			415.8		—			783.8
Partners' capital	1,046.2		963.9			416.7		(1,380.6		)	1,046.2
Interest of non-controlling partners in subsidiary	—		—			138.6		—			138.6
Total partners' capital	1,046.2		963.9			555.3		(1,380.6		)	1,184.8
Total liabilities and partners' capital	$	1,403.7	$	1,156.9		$	1,027.9	$	(1,380.9	)	$	2,207.6

Condensed Consolidating Statements of Operations

Condensed Consolidating Statements of Operations
Three Months Ended December 31, 2012
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenue:
Retail	$	—		$	—		$	—		$	—		$	—
Marketing, supply and logistics	—			368.0			2.8			—			370.8
Storage and transportation	—			23.6			47.6			(3.4		)	67.8
	—			391.6			50.4			(3.4		)	438.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			—			—			—			—
Marketing, supply and logistics	—			338.5			0.3			—			338.8
Storage and transportation	—			12.6			10.6			(3.4		)	19.8
	—			351.1			10.9			(3.4		)	358.6
Expenses:
Operating and administrative	—			20.8			11.7			—			32.5
Depreciation and amortization	—			21.1			15.2			—			36.3
Loss on disposal of assets	—			0.2			0.6			—			0.8
Operating income	—			(1.6		)	12.0			—			10.4
Other income (expense):
Interest expense, net	(2.6		)	—			(5.5		)	—			(8.1		)
Early extinguishment of debt	—			—			—			—			—
Gain on disposal of retail propane operations	—			—			—			—			—
Loss on Suburban Propane Partners, L.P. units	—			—			—			—			—
Other income	—			0.6			—			—			0.6
Equity in net income of subsidiary	5.4			—			—			(5.4		)	—
Income (loss) before income taxes	2.8			(1.0		)	6.5			(5.4		)	2.9
Provision for income taxes	—			0.1			—			—			0.1
Net income (loss)	2.8			(1.1		)	6.5			(5.4		)	2.8
Net income attributable to non-controlling partners in subsidiary	—			—			(1.5		)	—			(1.5		)
Net income (loss) attributable to partners	$	2.8		$	(1.1	)	$	5.0		$	(5.4	)	$	1.3

Condensed Consolidating Statements of Operations
Three Months Ended December 31, 2011
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenue:
Retail	$	—		$	295.0	$	—		$	—		$	295.0
Marketing, supply and logistics	—			314.4		—			—			314.4
Storage and transportation	—			14.4		46.8			(2.0		)	59.2
	—			623.8		46.8			(2.0		)	668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			178.8		—			—			178.8
Marketing, supply and logistics	—			295.1		—			—			295.1
Storage and transportation	—			4.8		11.1			(2.0		)	13.9
	—			478.7		11.1			(2.0		)	487.8
Expenses:
Operating and administrative	—			76.5		6.1			—			82.6
Depreciation and amortization	—			36.7		12.0			—			48.7
Loss on disposal of assets	—			1.4		—			—			1.4
Operating income	—			30.5		17.6			—			48.1
Other income (expense):
Interest expense, net	(28.0		)	—		—			—			(28.0		)
Early extinguishment of debt	(24.9		)	—		—			—			(24.9		)
Other income	—			1.3		—			—			1.3
Equity in net income of subsidiary	49.3			—		—			(49.3		)	—
Income (loss) before income taxes	(3.6		)	31.8		17.6			(49.3		)	(3.5		)
Provision for income taxes	—			0.1		—			—			0.1
Net income (loss)	(3.6		)	31.7		17.6			(49.3		)	(3.6		)
Net income attributable to non-controlling partners in subsidiary	—			—		(0.4		)	—			(0.4		)
Net income (loss) attributable to partners	$	(3.6	)	$	31.7	$	17.2		$	(49.3	)	$	(4.0	)

Condensed Consolidating Statements of Cash Flows

Condensed Consolidating Statements of Cash Flows
Three Months Ended December 31, 2012
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	—		$	5.8		$	22.2		$	—		$	28.0
Cash flows from investing activities
Acquisitions, net of cash acquired	—			0.1			(423.5		)	—			(423.4		)
Purchases of property, plant and equipment	—			(8.6		)	(43.6		)	—			(52.2		)
US Salt, LLC contribution, net	—			—			—			—			—
Payments associated with the disposal of retail propane operations	—			—			—			—			—
Other	—			—			—			—			—
Net cash used in investing activities	—			(8.5		)	(467.1		)	—			(475.6		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	—			203.2			581.1			—			784.3
Principal payments on long-term debt	—			(183.5		)	(317.8		)	—			(501.3		)
Distributions paid	(59.2		)	(36.7		)	(22.8		)	82.0			(36.7		)
Distributions paid to non-controlling partners	—			—			(7.2		)	—			(7.2		)
Distributions received	59.2			22.8			—			(82.0		)	—
Net proceeds from the issuance of common units	—			—			224.7			—			224.7
US Salt, LLC contribution, net	—			—			—			—			—
Other	(2.8		)	1.5			(13.1		)	—			(14.4		)
Net cash provided by (used in) financing activities	(2.8		)	7.3			444.9			—			449.4
Net increase (decrease) in cash	(2.8		)	4.6			—			—			1.8
Cash at beginning of period	2.9			(2.9		)	—			—			—
Cash at end of period	$	0.1		$	1.7		$	—		$	—		$	1.8

Condensed Consolidating Statements of Cash Flows
Three Months Ended December 31, 2011
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	—		$	(8.7	)	$	31.9		$	—		$	23.2
Cash flows from investing activities
Acquisitions, net of cash acquired	—			(19.8		)	—			—			(19.8		)
Purchases of property, plant and equipment	—			(17.7		)	(39.4		)	—			(57.1		)
Other	—			2.7			—			—			2.7
Net cash used in investing activities	—			(34.8		)	(39.4		)	—			(74.2		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	255.0			577.7			341.8			—			1,174.5
Principal payments on long-term debt	(255.0		)	(548.2		)	(516.6		)	—			(1,319.8		)
Distributions paid	(202.1		)	(83.9		)	(118.2		)	320.3			(83.9		)
Distributions received	202.1			118.2			—			(320.3		)	—
Net proceeds from the issuance of common units	—			—			292.7			—			292.7
Other	—			(13.2		)	7.9			—			(5.3		)
Net cash provided by financing activities	—			50.6			7.6			—			58.2
Net increase in cash	—			7.1			0.1			—			7.2
Cash at beginning of period	3.0			8.5			—			—			11.5
Cash at end of period	$	3.0		$	15.6		$	0.1		$	—		$	18.7

XML

Segments (Tables)

3 Months Ended

Dec. 31, 2012

Segment Reporting [Abstract]

Summary Of Segment Information

	Three Months Ended December 31, 2012
	Marketing, Supply and Logistics Operations		Storage and Transportation Operations		Intersegment Operations		Corporate Assets		Total
Retail revenues	$	—	$	—	$	—	$	—	$	—
Marketing, supply and logistics revenues	370.8		—		—		—		370.8
Storage and transportation revenues	—		67.8		—		—		67.8
Gross profit (excluding depreciation and amortization)	32.0		48.0		—		—		80.0
Identifiable assets	235.9		29.3		—		—		265.2
Goodwill	168.8		141.8		—		20.2		330.8
Property, plant and equipment	455.7		1,835.3		—		6.9		2,297.9
Expenditures for property, plant and equipment	2.9		33.9		—		—		36.8

	Three Months Ended December 31, 2011
	Marketing, Supply and Logistics Operations		Storage and Transportation Operations		Intersegment Operations			Corporate Assets		Total
Retail revenues	$	295.0	$	—	$	—		$	—	$	295.0
Marketing, supply and logistics revenues	314.8		—		(0.4		)	—		314.4
Storage and transportation revenues	—		59.2		—			—		59.2
Gross profit (excluding depreciation and amortization)	135.5		45.3		—			—		180.8
Identifiable assets	370.5		28.6		—			—		399.1
Goodwill	339.2		141.8		—			20.2		501.2
Property, plant and equipment	1,083.5		1,575.5		—			12.5		2,671.5
Expenditures for property, plant and equipment	8.2		41.8		—			0.1		50.1

XML

Long-Term Debt (Components Of Long-Term Debt) (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012
Debt Instrument [Line Items]
Senior unsecured notes	$ 11.5	$ 11.5
Obligations under noncompetition agreements and notes to former owners of businesses acquired	2.9	3.5
Total debt	1,026.3	743.2
Less: current portion	(2.1)	(3.4)
Total long-term debt	1,024.2	739.8
Revolving Loan Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	332.1	311.7
Nrgm Credit Facility
Debt Instrument [Line Items]
Credit agreement outstanding carrying value	179.8	416.5
Senior unsecured notes	$ 500.0	$ 0

XML

Partnership Organization and Basis of Presentation (Narrative) (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012 segment Facilities Tractors Transports	Dec. 31, 2011
Partnership Organization And Basis Of Presentation [Line Items]
Percent of cash distributed, maximum	25.00%
Number of Operating Segments	2
Number of Tractors	275
Number of Transports	457
Number of Facilities	4
Retail	$ 0	$ 295.0
Retail	0	178.8
Inergy Midstream
Partnership Organization And Basis Of Presentation [Line Items]
Incentive distribution rights, percentage	50.00%
Propane revenue
Partnership Organization And Basis Of Presentation [Line Items]
Retail		478.7
Other revenue
Partnership Organization And Basis Of Presentation [Line Items]
Other		189.9
Cost of propane
Partnership Organization And Basis Of Presentation [Line Items]
Retail		374.4
Other cost of product sold
Partnership Organization And Basis Of Presentation [Line Items]
Other		$ 113.4

XML

Summary of Significant Accounting Policies (Narrative) (Detail) (USD $)	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2012
Summary Of Significant Accounting Policies [Line Items]
Net gain (loss) recognized on ineffective portion of fair value hedges	$ 2,100,000	$ 1,000,000
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness, Net	0	0
Accumulated other comprehensive income (loss)	11,200,000		(14,900,000)
Expected to be reclassified to earnings from other comprehensive income	3,600,000
Operating and administrative expenses and depreciation and amortization not included in cost of product sold	35,900,000	54,100,000
Inventory hedged at market value	48,400,000		73,200,000
Amounts capitalized for cost of funds used during construction	3,100,000	3,400,000
Percentage of gross income from qualifying sources required to be subject to federal income tax, minimum	90.00%
Unit-based compensation expense	3,100,000	3,100,000
Senior notes	11,500,000		11,500,000
Assets from price risk management activities	30,800,000		37,500,000
Liabilities from price risk management activities	24,200,000		20,900,000
Revolving Loan Facility
Summary Of Significant Accounting Policies [Line Items]
Credit facility amount, borrowing capacity	550,000,000
NRGM Credit Facility
Summary Of Significant Accounting Policies [Line Items]
Credit facility amount, borrowing capacity	600,000,000
Commodities Investment
Summary Of Significant Accounting Policies [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	(3,900,000)
Interest Rate Swap
Summary Of Significant Accounting Policies [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	(6,900,000)
SPH Units
Summary Of Significant Accounting Policies [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	400,000
Unit based compensation
Summary Of Significant Accounting Policies [Line Items]
Unit-based compensation expense	3,100,000	3,100,000
Senior Notes | Inergy
Summary Of Significant Accounting Policies [Line Items]
Estimated fair value of the fixed-rate Senior Notes	11,900,000
Senior Notes | NRGM Credit Facility
Summary Of Significant Accounting Policies [Line Items]
Estimated fair value of the fixed-rate Senior Notes	515,300,000
Revolving Loan Facility
Summary Of Significant Accounting Policies [Line Items]
Credit agreement outstanding carrying value	332,100,000		311,700,000
Nrgm Credit Facility
Summary Of Significant Accounting Policies [Line Items]
Senior notes	500,000,000		0
Credit agreement outstanding carrying value	$ 179,800,000		$ 416,500,000

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Partnership Organization and Basis of Presentation

3 Months Ended

Dec. 31, 2012

Disclosure Partnership Organization And Basis Of Presentation Narrative [Abstract]

Partnership Organization and Basis of Presentation

Partnership Organization and Basis of Presentation

Organization

The accompanying consolidated financial statements include the accounts of Inergy, L.P. (“Inergy” or "the Company") and its wholly owned subsidiaries, including among others, Inergy Partners, LLC (“Partners”), Tres Palacios Gas Storage LLC ("TPGS"), IPCH Acquisition Corp. (“IPCHA”), Inergy Finance Corp. and Inergy Operations, LLC. The accompanying consolidated financial statements also include the accounts of Inergy's majority-owned subsidiary, Inergy Midstream, L.P. (“Inergy Midstream”), and its wholly-owned subsidiaries.

NRGM GP, LLC Change of Control Event

In connection with the Inergy Midstream initial public offering ("IPO"), Inergy and Inergy Holdings GP, LLC (“Holdings GP”), the indirect owner of Inergy's general partner, entered into a membership interest purchase agreement under which, under certain circumstances, Holdings GP will be required to purchase from Inergy, and Inergy will be required to sell to Holdings GP, all of the membership interests in MGP GP, LLC, the entity that controls Inergy Midstream's general partner, for nominal consideration. MGP GP, LLC is a wholly owned subsidiary of Inergy and the general partner of Inergy Midstream Holdings, L.P., which is the sole member of Inergy Midstream's general partner and direct holder of all of its IDRs. Under the agreement, Holdings GP is required to purchase MGP GP, LLC in the event that (i) a change of control of Inergy occurs at a time when Inergy is entitled to receive less than 50% of all cash distributed with respect to Inergy Midstream's limited partner interests and IDRs or (ii) through dilution or a distribution to the Inergy common unitholders of Inergy's interests in Inergy Midstream, Inergy is entitled to receive less than 25% of all cash distributed with respect to Inergy Midstream's limited partner interests and IDRs.

Nature of Operations

Inergy's financial statements reflect two operating and reporting segments: (i) marketing, supply and logistics operations and (ii) storage and transportation operations. Inergy's marketing, supply and logistics operations provide natural gas liquids ("NGLs") and crude oil marketing, supply and logistics services to producers, refiners, petrochemical companies, marketers, and others that effectively provide flow assurances to our customers. Inergy's marketing, supply and logistics assets primarily includes its West Coast operations, a fleet of 275 tractors and 457 transports managed by a team of experienced employees in the NGL business, and a crude oil loading and storage terminal (the "COLT Hub") that was acquired by Inergy Midstream on December 7, 2012. The historical results of the retail propane operations that were contributed to Suburban Propane Partners, L.P. (“SPH”) on August 1, 2012 are also included in this segment.

Inergy's storage and transportation operations provide natural gas and NGL storage and transportation services to third parties, as well as the production and sale of salt products. Inergy's storage and transportation assets include the Tres Palacios natural gas storage facility in Texas. Through its ownership interest in Inergy Midstream, Inergy has an investment in four natural gas storage facilities in New York (Stagecoach, Thomas Corners, Steuben and Seneca Lake), natural gas transportation assets in New York and Pennsylvania (the North-South Facilities, the MARC I Pipeline, and the East Pipeline), an NGL storage facility in New York (Bath storage facility) and a solution-mining and salt production company in New York (US Salt).

Basis of Presentation

The financial information contained herein as of December 31, 2012, and for the three-month periods endedDecember 31, 2012 and 2011, is unaudited. Inergy believes this information has been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and Article 10 of Regulation S-X. Inergy also believes this information includes all adjustments (consisting only of normal recurring adjustments) necessary to present fairly the financial position, results of operations and cash flows for the periods then ended.

On August 1, 2012, Inergy contributed its retail propane operations to SPH.  ASC 205 requires that in order for a transaction to be considered discontinued operations, the gross cash flows related to the continuing involvement with the discontinued operations must be immaterial. The financial statements do not report the retail propane operations as discontinued as the involvement of Inergy with the retail propane operations subsequent to contribution is expected to be material due to a propane supply arrangement between Inergy and SPH.

The accompanying consolidated financial statements should be read in conjunction with the consolidated financial statements of Inergy, L.P. and subsidiaries and the notes thereto included in Form 10-K as filed with the Securities and Exchange Commission for the fiscal year ended September 30, 2012.

Reclassifications

The consolidated statement of operations for the three months endedDecember 31, 2011 reflects a reclassification within revenue and a reclassification within cost of product sold to conform to the current period presentation. For the three months endedDecember 31, 2011, propane and other revenue was $478.7 million and $189.9 million, respectively, and propane and other cost of product sold was $374.4 million and $113.4 million, respectively. These reclassifications had no effect on net income.

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Summary of Significant Accounting Policies (Estimated Useful Lives Of Property, Plant And Equipment) (Detail)	3 Months Ended
	Dec. 31, 2012
Building and improvements | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Building and improvements | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	70 years
Office furniture and equipment | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Office furniture and equipment | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	7 years
Vehicles | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Vehicles | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	10 years
Pipelines | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Pipelines | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	15 years
Plant equipment | Minimum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	3 years
Plant equipment | Maximum
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	30 years
Base gas
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	10 years

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Fair Value Measurements (Assets And Liabilities Measured At Fair Value On Recurring Basis) (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012		Sep. 30, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	$ 30.8		$ 37.5
Inventory	48.4		73.2
SPH units	5.5		5.9
Total assets at fair value	84.7		116.6
Liabilities from price risk management	24.2		20.9
Interest rate swaps	0		7.5
Total liabilities at fair value	24.2		28.4
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	2.5		2.7
Inventory	0		0
SPH units	5.5		5.9
Total assets at fair value	8.0		8.6
Liabilities from price risk management	2.9		2.0
Interest rate swaps	0		0
Total liabilities at fair value	2.9		2.0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	40.4		51.3
Inventory	48.4		73.2
SPH units	0		0
Total assets at fair value	88.8		124.5
Liabilities from price risk management	30.2		31.1
Interest rate swaps	6.8		7.5
Total liabilities at fair value	37.0		38.6
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	0		0
Inventory	0		0
SPH units	0		0
Total assets at fair value	0		0
Liabilities from price risk management	0		0
Interest rate swaps	0		0
Total liabilities at fair value	0		0
Total
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	42.9		54.0
Inventory	48.4		73.2
SPH units	5.5		5.9
Total assets at fair value	96.8		133.1
Liabilities from price risk management	33.1		33.1
Interest rate swaps	6.8		7.5
Total liabilities at fair value	39.9		40.6
Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	5.7		9.8
Inventory	0		0
SPH units	0		0
Total assets at fair value	5.7		9.8
Liabilities from price risk management	4.2		11.3
Interest rate swaps	0		7.5
Total liabilities at fair value	4.2		18.8
Not Designated as Hedges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	37.2		44.2
Inventory	0		0
SPH units	0		0
Total assets at fair value	37.2		44.2
Liabilities from price risk management	28.9		21.8
Interest rate swaps	0		0
Total liabilities at fair value	28.9		21.8
Netting Agreements
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from price risk management	(12.1)	[1]	(16.5)	[1]
Inventory	0	[1]	0	[1]
SPH units	0	[1]	0	[1]
Total assets at fair value	(12.1)	[1]	(16.5)	[1]
Liabilities from price risk management	(8.9)	[1]	(12.2)	[1]
Interest rate swaps	0	[1]	0	[1]
Total liabilities at fair value	$ (8.9)	[1]	$ (12.2)	[1]

[1] Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

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Condensed Consolidating Financial Information (Condensed Consolidating Statements of Comprehensive Income) (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ 2.8	$ (3.6)
Change in unrealized fair value on cash flow hedges (Note 2)	4.1	(2.6)
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	(0.4)	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	6.5	(6.2)
Parent Company
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	2.8	(3.6)
Change in unrealized fair value on cash flow hedges (Note 2)	0.7	(0.1)
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	(0.4)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	3.1	(3.7)
Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(1.1)	31.7
Change in unrealized fair value on cash flow hedges (Note 2)	3.4	(2.5)
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	2.3	29.2
Non-Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	6.5	17.6
Change in unrealized fair value on cash flow hedges (Note 2)	0	0
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	6.5	17.6
Consolidation, Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(5.4)	(49.3)
Change in unrealized fair value on cash flow hedges (Note 2)	0	0
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(5.4)	(49.3)
Consolidated Entities
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	2.8	(3.6)
Change in unrealized fair value on cash flow hedges (Note 2)	4.1	(2.6)
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	(0.4)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 6.5	$ (6.2)

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Consolidated Balance Sheets (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012
Assets
Cash and cash equivalents	$ 1.8	$ 0
Accounts receivable, less allowance for doubtful accounts of $0.4 million at December 31, 2012 and September 30, 2012, respectively	201.7	133.6
Inventories (Note 3)	63.5	87.1
Assets from price risk management activities	30.8	37.5
Prepaid expenses and other current assets	19.1	20.3
Total current assets	316.9	278.5
Property, plant and equipment (Note 3)	2,297.9	2,160.7
Less: accumulated depreciation	484.7	450.2
Property, plant and equipment, net	1,813.2	1,710.5
Intangible assets (Note 3):
Customer accounts	194.4	41.2
Other intangible assets	36.2	21.3
Intangible assets, gross	230.6	62.5
Less: accumulated amortization	23.7	21.2
Intangible assets, net	206.9	41.3
Goodwill	330.8	165.8
Other assets	11.1	11.5
Total assets	2,678.9	2,207.6
Current liabilities:
Accounts payable	143.5	120.8
Accrued expenses	68.0	93.9
Liabilities from price risk management activities	24.2	20.9
Current portion of long-term debt (Note 7)	2.1	3.4
Total current liabilities	237.8	239.0
Long-term debt, less current portion (Note 7)	1,024.2	739.8
Other long-term liabilities	22.7	23.4
Deferred income taxes	20.3	20.6
Partners’ capital (Note 8):
Limited partner unitholders (131,740,895 and 125,795,836 common units issued and outstanding at December 31, 2012 and September 30, 2012, respectively, and 5,882,105 Class B units issued and outstanding at September 30, 2012)	1,113.6	1,046.2
Total Inergy, L.P. partners’ capital	1,113.6	1,046.2
Interest of non-controlling partners in subsidiaries	260.3	138.6
Total partners’ capital	1,373.9	1,184.8
Total liabilities and partners’ capital	$ 2,678.9	$ 2,207.6

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Long-Term Debt (Narrative) (Detail) (USD $)	3 Months Ended												3 Months Ended			1 Months Ended			3 Months Ended														3 Months Ended									1 Months Ended	3 Months Ended					3 Months Ended		1 Months Ended	3 Months Ended		3 Months Ended
	Dec. 31, 2012	Dec. 07, 2012	Sep. 30, 2012	Apr. 13, 2012 Inergy Midstream	Dec. 31, 2012 Credit Agreement	Sep. 30, 2012 Credit Agreement	Dec. 31, 2012 Revolving Loan Facility	Sep. 30, 2012 Revolving Loan Facility	Dec. 31, 2012 Nrgm Credit Facility	Sep. 30, 2012 Nrgm Credit Facility	Dec. 31, 2012 Minimum	Jul. 26, 2012 Maximum Long-term Debt Credit Agreement	Dec. 31, 2012 COLT Hub [Member]	Dec. 31, 2012 COLT Hub [Member] Minimum	Dec. 31, 2012 Revolving Loan Facility	Nov. 24, 2009 Revolving Loan Facility Original Credit Agreement	Apr. 13, 2012 Revolving Loan Facility Original Credit Agreement	Jul. 28, 2011 Revolving Loan Facility Original Credit Agreement	Dec. 31, 2012 Revolving Loan Facility Amended and Restated	Apr. 13, 2012 Revolving Loan Facility Amended and Restated	Jul. 28, 2011 Revolving Loan Facility Amended and Restated	Dec. 31, 2012 Revolving Loan Facility Credit Agreement LIBO Rate, Adjustment	Dec. 31, 2012 Revolving Loan Facility Minimum LIBO Rate	Sep. 30, 2012 Revolving Loan Facility Minimum LIBO Rate	Dec. 31, 2012 Revolving Loan Facility Minimum Credit Agreement LIBO Rate	Dec. 31, 2012 Revolving Loan Facility Minimum Credit Agreement Adjusted LIBO Rate	Dec. 31, 2012 Revolving Loan Facility Maximum LIBO Rate	Sep. 30, 2012 Revolving Loan Facility Maximum LIBO Rate	Dec. 31, 2012 Revolving Loan Facility Maximum Credit Agreement LIBO Rate	Dec. 31, 2012 Revolving Loan Facility Maximum Credit Agreement Adjusted LIBO Rate	Nov. 24, 2009 General Partnership Facility	Nov. 24, 2009 Working Capital Facility	Dec. 31, 2012 Term Loan Facility	Dec. 31, 2012 Term Loan Facility Interest Rate Swaps Accounted For As Cash Flow Hedges Interest Rate Swaps Maturing 2015	Feb. 02, 2011 Term Loan Facility Amended and Restated	Feb. 02, 2011 Term Loan Facility Credit Agreement LIBO Rate, Adjustment	Feb. 02, 2011 Term Loan Facility Credit Agreement Federal Funds Rate	Feb. 02, 2011 Term Loan Facility Minimum Credit Agreement LIBO Rate	Feb. 02, 2011 Term Loan Facility Minimum Credit Agreement Adjusted LIBO Rate	Feb. 02, 2011 Term Loan Facility Maximum Credit Agreement LIBO Rate	Feb. 02, 2011 Term Loan Facility Maximum Credit Agreement Adjusted LIBO Rate	Apr. 16, 2012 Nrgm Credit Facility	Dec. 31, 2012 Nrgm Credit Facility	Dec. 21, 2011 Nrgm Credit Facility Inergy Midstream	Dec. 31, 2012 Nrgm Credit Facility Adjusted LIBO Rate	Dec. 31, 2012 Nrgm Credit Facility Federal Funds Rate	Dec. 31, 2012 Nrgm Credit Facility Amended and Restated	Dec. 31, 2012 Nrgm Credit Facility Minimum	Dec. 31, 2012 Nrgm Credit Facility Minimum Adjusted LIBO Rate	Apr. 16, 2012 Nrgm Credit Facility Maximum	Dec. 31, 2012 Nrgm Credit Facility Maximum	Dec. 31, 2012 Nrgm Credit Facility Maximum Adjusted LIBO Rate	Dec. 31, 2012 Long-term Debt
Debt Instrument [Line Items]
Credit facility borrowing amount																$ 525,000,000		$ 525,000,000
Credit agreement outstanding carrying value															550,000,000		700,000,000			550,000,000	700,000,000										450,000,000	75,000,000			300,000,000									500,000,000
Revolving credit maturity date																Nov. 22, 2013			Jul. 28, 2016														Feb. 02, 2015
Variable interest rate																						1.00%			0.75%	1.75%			2.00%	3.00%						1.00%	0.50%	1.00%	2.00%	2.25%	3.25%				1.00%	0.50%	0.50%	0.75%	1.75%		1.75%	2.75%
Line of Credit Facility, Covenant Terms, Percentage of Cash Proceeds from Asset Dispositions to Reduce Borrowings											50.00%
Line of Credit Facility, Covenant Terms, Unapplied Cash from Asset Disposition, Threshold											50,000,000
Common Stock, Shares Authorized				5,000,000
Authorized common units that can be acquired												100,000,000
Early extinguishment of debt																																																					1,187,000,000
Total funded debt to consolidated EBITDA (as defined in the Credit Agreement)	4.75
Consolidated EBITDA to consolidated interest expense (as defined in the Credit Agreement)	2.50
Credit agreement outstanding carrying value							332,100,000	311,700,000	179,800,000	416,500,000
Line of Credit Facility, Interest Rate at Period End																							1.96%	2.99%			4.00%	5.00%
Credit Agreement amount available					168,700,000	184,000,000
Letters of credit outstanding					49,200,000	54,300,000																																					2,000,000
Number of interest rate swaps entered during period																																		6
Fixed rate, range low end	0.84%
Fixed rate, range high end	2.52%
Aggregate notional amount, cash flow hedges	225,000,000
Increase available borrowings																																										100,000,000								150,000,000	250,000,000
Consolidated Leverage Ratio, Maximum, Post Acquisitions													5.50
Line of Credit Facility, Covenant Term, Acquisition Threshold														50,000,000
Senior Secured Leverage Ratio Maximum																																											3.75
LIne of Credit Facility, Covenant Terms, Cumulative Issuance of Junior Debt																																											200,000,000
Credit facility sub-limit																																																			10,000,000
Sub-limit advances																																																			100,000,000
Remaining capacity																																											418,200,000
Senior notes	$ 11,500,000		$ 11,500,000						$ 500,000,000	$ 0
Debt Instrument, Interest Rate, Stated Percentage		6.00%
Adjusted LIBO Rate, minimum																																											0.75%
Adjusted LIBO Rate, maximum																																											1.75%
Line of credit facility commitment fee percentage, minimum																																																0.30%
Line of credit facility commitment fee percentage, maximum																																																			0.50%
Consolidated leverage ratio, maximum																																											5
Interest coverage ratio, maximum																																											2.50

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Consolidated Statement of Partners' Capital (USD $) In Millions	Total	Common Unit Capital	Non-Controlling Partners	Inergy Midstream	Inergy Midstream Common Unit Capital	Inergy Midstream Non-Controlling Partners
Balance at September 30, 2012 at Sep. 30, 2012	$ 1,184.8	$ 1,046.2	$ 138.6
Net proceeds from issuance of common units by Inergy Midstream, L.P.				224.7	0	224.7
Net proceeds from common unit options exercised	0.7	0.7	0
Unit-based compensation charges	3.1	2.2	0.9
Retirement of common units	(2.0)	(2.0)	0
Distributions	(43.9)	(36.7)	(7.2)
Gain (loss) on issuance of Inergy Midstream, L.P. units	0	98.2	(98.2)
Change in unrealized fair value on cash flow hedges and change in Suburban Propane Partners, L.P. units	3.7	3.7	0
Net income (loss)	2.8	1.3	1.5
Balance at December 31, 2012 at Dec. 31, 2012	$ 1,373.9	$ 1,113.6	$ 260.3

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Certain Balance Sheet Information (Property, Plant And Equipment) (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,297.9	$ 2,160.7	$ 2,671.5
Less: accumulated depreciation	484.7	450.2
Property, plant and equipment, net	1,813.2	1,710.5
Pipelines
Property, Plant and Equipment [Line Items]
Property, plant and equipment	578.1	381.3
Plant equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	721.1	619.3
Buildings, land and storage rights
Property, Plant and Equipment [Line Items]
Property, plant and equipment	594.9	513.9
Vehicles
Property, Plant and Equipment [Line Items]
Property, plant and equipment	45.3	44.1
Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	164.7	409.6
Base gas
Property, Plant and Equipment [Line Items]
Property, plant and equipment	134.1	134.0
Salt deposits
Property, Plant and Equipment [Line Items]
Property, plant and equipment	41.6	41.6
Office furniture and equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 18.1	$ 16.9

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Certain Balance Sheet Information (Tables)

3 Months Ended

Dec. 31, 2012

Balance Sheet Related Disclosures [Abstract]

Inventories

Inventories consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
NGLs	$	56.9	$	80.8
Parts, supplies and other	6.6		6.3
Total inventory	$	63.5	$	87.1

Property, Plant And Equipment

Property, plant and equipment consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Plant equipment	$	721.1	$	619.3
Buildings, land and storage rights	594.9		513.9
Pipelines	578.1		381.3
Vehicles	45.3		44.1
Construction in process	164.7		409.6
Base gas	134.1		134.0
Salt deposits	41.6		41.6
Office furniture and equipment	18.1		16.9
	2,297.9		2,160.7
Less: accumulated depreciation	484.7		450.2
Total property, plant and equipment, net	$	1,813.2	$	1,710.5

Intangible Assets

Intangible assets consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Customer accounts	$	194.4	$	41.2
Covenants not to compete	8.3		4.2
Deferred financing and other costs	27.9		17.1
	230.6		62.5
Less: accumulated amortization	23.7		21.2
Total intangible assets, net	$	206.9	$	41.3

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Certain Balance Sheet Information (Intangible Assets) (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	$ 230.6	$ 62.5
Less: accumulated amortization	23.7	21.2
Total intangible assets, net	206.9	41.3
Customer accounts
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	194.4	41.2
Covenants not to compete
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	8.3	4.2
Deferred financing and other costs
Finite-Lived Intangible Assets [Line Items]
Intangible assets, Gross	$ 27.9	$ 17.1

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Fair Value Measurements (Tables)

3 Months Ended

Dec. 31, 2012

Fair Value, Assets and Liabilities Measured on Recurring Basis [Abstract]

Assets And Liabilities Measured At Fair Value On Recurring Basis

	December 31, 2012
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Designated as Hedges		Not Designated as Hedges		Netting Agreements(a)			Total
Assets
Assets from price risk management	$	2.5	$	40.4	$	—	$	42.9	$	5.7	$	37.2	$	(12.1	)	$	30.8
Inventory	—		48.4		—		48.4		—		—		—			48.4
SPH units	5.5		—		—		5.5		—		—		—			5.5
Total assets at fair value	$	8.0	$	88.8	$	—	$	96.8	$	5.7	$	37.2	$	(12.1	)	$	84.7
Liabilities
Liabilities from price risk management	$	2.9	$	30.2	$	—	$	33.1	$	4.2	$	28.9	$	(8.9	)	$	24.2
Interest rate swaps	—		6.8		—		6.8		—		—		—			—
Total liabilities at fair value	$	2.9	$	37.0	$	—	$	39.9	$	4.2	$	28.9	$	(8.9	)	$	24.2

	September 30, 2012
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Designated as Hedges		Not Designated as Hedges		Netting Agreements(a)			Total
Assets
Assets from price risk management	$	2.7	$	51.3	$	—	$	54.0	$	9.8	$	44.2	$	(16.5	)	$	37.5
Inventory	—		73.2		—		73.2		—		—		—			73.2
SPH units	5.9		—		—		5.9		—		—		—			5.9
Total assets at fair value	8.6		124.5		—		133.1		9.8		44.2		(16.5		)	116.6
Liabilities
Liabilities from price risk management	$	2.0	$	31.1	$	—	$	33.1	$	11.3	$	21.8	$	(12.2	)	$	20.9
Interest rate swap	—		7.5		—		7.5		7.5		—		—			7.5
Total liabilities at fair value	$	2.0	$	38.6	$	—	$	40.6	$	18.8	$	21.8	$	(12.2	)	$	28.4

(a) Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

XML

Consolidated Statements Of Cash Flows (USD $)	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Operating activities
Net income (loss)	$ 2,800,000	$ (3,600,000)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and depletion	34,800,000	39,900,000
Amortization	1,500,000	8,800,000
Amortization of deferred financing costs, swap premium and bond discount	3,300,000	1,500,000
Unit-based compensation charges	3,100,000	3,100,000
Provision for doubtful accounts	100,000	(100,000)
Loss on disposal of assets	800,000	1,400,000
Deferred income taxes	(300,000)	(100,000)
Early extinguishment of debt	0	8,300,000
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable	(64,900,000)	(69,500,000)
Inventories	23,600,000	56,000,000
Prepaid expenses and other current assets	1,300,000	(4,500,000)
Other assets (liabilities)	200,000	(100,000)
Accounts payable and accrued expenses	8,100,000	(700,000)
Customer deposits	0	(7,400,000)
Net liabilities from price risk management activities	13,600,000	(9,800,000)
Net cash provided by operating activities	28,000,000	23,200,000
Investing activities
Acquisitions, net of cash acquired	(423,400,000)	(19,800,000)
Purchases of property, plant and equipment	(52,200,000)	(57,100,000)
Proceeds from sale of assets	0	2,700,000
Net cash used in investing activities	(475,600,000)	(74,200,000)
Financing activities
Proceeds from the issuance of long-term debt	203,200,000	577,700,000
Principal payments on long-term debt	(183,500,000)	(803,200,000)
Proceeds from the issuance of promissory note	0	255,000,000
Principal payment on promissory note	0	(255,000,000)
Distributions	(36,700,000)	(83,900,000)
Distributions paid to non-controlling partners	(7,200,000)	0
Payments for deferred financing costs	(13,100,000)	(4,600,000)
Retirement of common units	(2,000,000)	(1,100,000)
Net proceeds from Inergy, L.P. common unit options exercised	700,000	400,000
Net cash provided by financing activities	449,400,000	58,200,000
Net increase in cash	1,800,000	7,200,000
Cash at beginning of period	0	11,500,000
Cash at end of period	1,800,000	18,700,000
Supplemental schedule of noncash investing and financing activities
Change in the value of intangible assets and equity	0	(3,000,000)
Net change to property, plant and equipment through accounts payable and accrued expenses	(15,400,000)	(7,000,000)
Change in the fair value of interest rate swap liability and related long-term debt	0	(100,000)
Acquisitions, net of cash acquired:
Current assets	3,300,000	4,700,000
Property, plant and equipment	100,900,000	10,500,000
Intangible assets	157,200,000	2,000,000
Goodwill	165,000,000	3,200,000
Other assets	0	100,000
Current liabilities	(3,500,000)	0
Debt	500,000	(700,000)
Total acquisitions, net of cash acquired	423,400,000	19,800,000
Inergy Midstream
Financing activities
Proceeds from the issuance of long-term debt	581,100,000	86,800,000
Principal payments on long-term debt	(317,800,000)	(6,600,000)
Net proceeds from issuance of Inergy Midstream, L.P. common units	$ 224,700,000	$ 292,700,000

XML

Consolidated Balance Sheets (Parenthetical) (USD $) In Millions, except Share data, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012
Allowance for doubtful accounts	$ 0.4	$ 0.4
Common units, issued	131,740,895	125,795,836
Common units, outstanding	131,740,895	125,795,836
Class B
Common units, issued	0	5,882,105
Common units, outstanding	0	5,882,105

XML

Segments

3 Months Ended

Dec. 31, 2012

Segment Reporting [Abstract]

Segments

Segments

Inergy's financial statements reflect two operating and reporting segments: (i) marketing, supply and logistics operations and (ii) storage and transportation operations. Inergy's marketing, supply and logistics operations provide NGLs and crude oil marketing, supply and logistics services to producers, refiners, petrochemical companies, marketers, and others that effectively provide flow assurances to our customers. Inergy's storage and transportation operations provide natural gas and NGL storage and transportation services to third parties, as well as the production and sale of salt products.

The identifiable assets associated with each reporting segment include accounts receivable and inventories. Goodwill, property, plant and equipment and expenditures for property, plant and equipment are also presented for each segment. The net asset/liability from price risk management, as reported in the accompanying consolidated balance sheets, is primarily related to the marketing, supply and logistics segment.

Revenues, gross profit, identifiable assets, goodwill, property, plant and equipment and expenditures for property, plant and equipment for each of Inergy's reporting segments are presented below (in millions):

	Three Months Ended December 31, 2012
	Marketing, Supply and Logistics Operations		Storage and Transportation Operations		Intersegment Operations		Corporate Assets		Total
Retail revenues	$	—	$	—	$	—	$	—	$	—
Marketing, supply and logistics revenues	370.8		—		—		—		370.8
Storage and transportation revenues	—		67.8		—		—		67.8
Gross profit (excluding depreciation and amortization)	32.0		48.0		—		—		80.0
Identifiable assets	235.9		29.3		—		—		265.2
Goodwill	168.8		141.8		—		20.2		330.8
Property, plant and equipment	455.7		1,835.3		—		6.9		2,297.9
Expenditures for property, plant and equipment	2.9		33.9		—		—		36.8

	Three Months Ended December 31, 2011
	Marketing, Supply and Logistics Operations		Storage and Transportation Operations		Intersegment Operations			Corporate Assets		Total
Retail revenues	$	295.0	$	—	$	—		$	—	$	295.0
Marketing, supply and logistics revenues	314.8		—		(0.4		)	—		314.4
Storage and transportation revenues	—		59.2		—			—		59.2
Gross profit (excluding depreciation and amortization)	135.5		45.3		—			—		180.8
Identifiable assets	370.5		28.6		—			—		399.1
Goodwill	339.2		141.8		—			20.2		501.2
Property, plant and equipment	1,083.5		1,575.5		—			12.5		2,671.5
Expenditures for property, plant and equipment	8.2		41.8		—			0.1		50.1

XML

Document and Entity Information	3 Months Ended
	Dec. 31, 2012
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Dec. 31, 2012
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q1
Trading Symbol	NRGY
Entity Registrant Name	INERGY L P
Entity Central Index Key	0001136352
Current Fiscal Year End Date	--09-30
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding

XML

Condensed Consolidating Financial Information

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Condensed Consolidating Financial Information

Condensed Consolidating Financial Information

Inergy is a holding company and owns no operating assets and has no significant operations independent of its subsidiaries. Obligations under its outstanding senior notes and credit agreement listed in Note 8 are jointly and severally guaranteed by Inergy's wholly owned domestic subsidiaries. Subsequent to Inergy Midstream's IPO on December 21, 2011, Inergy Midstream and its wholly owned subsidiaries no longer guarantee Inergy's senior notes or credit agreement.

The tables below present condensed consolidated financial statements for Inergy (parent) on a stand-alone, unconsolidated basis, and its combined guarantor and combined non-guarantor subsidiaries as of December 31, 2012 and September 30, 2012, and for the three months ended December 31, 2012 and 2011. The financial information may not necessarily be indicative of the results of operations, cash flows or financial position had the subsidiaries operated as independent entities.

Condensed Consolidating Balance Sheet
December 31, 2012
(in millions)
	Parent		Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	0.1	$	1.7		$	—	$	—		$	1.8
Accounts receivable	—		178.5			23.2		—			201.7
Inventories	—		57.4			6.1		—			63.5
Other	—		40.2			9.7		—			49.9
Total current assets	0.1		277.8			39.0		—			316.9
Property, plant and equipment, net	—		831.4			981.8		—			1,813.2
Goodwill and intangible assets, net	20.2		60.3			457.2		—			537.7
Investment in subsidiary	1,468.7		—			—		(1,468.7		)	—
Other assets	—		8.3			2.8		—			11.1
Total assets	$	1,489.0	$	1,177.8		$	1,480.8	$	(1,468.7	)	$	2,678.9
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	139.3		$	4.2	$	—		$	143.5
Other	2.0		53.5			38.8		—			94.3
Total current liabilities	2.0		192.8			43.0		—			237.8
Long-term liabilities:
Long-term debt, less current portion	346.3		(0.1		)	678.0		—			1,024.2
Other long-term liabilities	27.1		15.1			0.8		—			43.0
Total long-term liabilities	373.4		15.0			678.8		—			1,067.2
Partners' capital	1,113.6		970.0			498.7		(1,468.7		)	1,113.6
Interest of non-controlling partners in subsidiary	—		—			260.3		—			260.3
Total partners' capital	1,113.6		970.0			759.0		(1,468.7		)	1,373.9
Total liabilities and partners' capital	$	1,489.0	$	1,177.8		$	1,480.8	$	(1,468.7	)	$	2,678.9

Condensed Consolidating Balance Sheet
September 30, 2012
(in millions)
	Parent		Guarantor Subsidiaries			Non- Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Current assets:
Cash and cash equivalents	$	2.9	$	(2.9	)	$	—	$	—		$	—
Accounts receivable	—		114.3			19.3		—			133.6
Inventories	—		81.5			5.6		—			87.1
Other	—		52.7			5.4		(0.3		)	57.8
Total current assets	2.9		245.6			30.3		(0.3		)	278.5
Property, plant and equipment, net	—		842.6			867.9		—			1,710.5
Goodwill and intangible assets, net	20.2		61.1			125.8		—			207.1
Investment in subsidiary	1,380.6		—			—		(1,380.6		)	—
Other assets	—		7.6			3.9		—			11.5
Total assets	$	1,403.7	$	1,156.9		$	1,027.9	$	(1,380.9	)	$	2,207.6
Liabilities and partners' capital
Current liabilities:
Accounts payable	$	—	$	116.9		$	3.9	$	—		$	120.8
Other	4.6		61.0			52.9		(0.3		)	118.2
Total current liabilities	4.6		177.9			56.8		(0.3		)	239.0
Long-term liabilities:
Long-term debt, less current portion	324.8		—			415.0		—			739.8
Other long-term liabilities	28.1		15.1			0.8		—			44.0
Total long-term liabilities	352.9		15.1			415.8		—			783.8
Partners' capital	1,046.2		963.9			416.7		(1,380.6		)	1,046.2
Interest of non-controlling partners in subsidiary	—		—			138.6		—			138.6
Total partners' capital	1,046.2		963.9			555.3		(1,380.6		)	1,184.8
Total liabilities and partners' capital	$	1,403.7	$	1,156.9		$	1,027.9	$	(1,380.9	)	$	2,207.6

Condensed Consolidating Statements of Operations
Three Months Ended December 31, 2012
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenue:
Retail	$	—		$	—		$	—		$	—		$	—
Marketing, supply and logistics	—			368.0			2.8			—			370.8
Storage and transportation	—			23.6			47.6			(3.4		)	67.8
	—			391.6			50.4			(3.4		)	438.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			—			—			—			—
Marketing, supply and logistics	—			338.5			0.3			—			338.8
Storage and transportation	—			12.6			10.6			(3.4		)	19.8
	—			351.1			10.9			(3.4		)	358.6
Expenses:
Operating and administrative	—			20.8			11.7			—			32.5
Depreciation and amortization	—			21.1			15.2			—			36.3
Loss on disposal of assets	—			0.2			0.6			—			0.8
Operating income	—			(1.6		)	12.0			—			10.4
Other income (expense):
Interest expense, net	(2.6		)	—			(5.5		)	—			(8.1		)
Early extinguishment of debt	—			—			—			—			—
Gain on disposal of retail propane operations	—			—			—			—			—
Loss on Suburban Propane Partners, L.P. units	—			—			—			—			—
Other income	—			0.6			—			—			0.6
Equity in net income of subsidiary	5.4			—			—			(5.4		)	—
Income (loss) before income taxes	2.8			(1.0		)	6.5			(5.4		)	2.9
Provision for income taxes	—			0.1			—			—			0.1
Net income (loss)	2.8			(1.1		)	6.5			(5.4		)	2.8
Net income attributable to non-controlling partners in subsidiary	—			—			(1.5		)	—			(1.5		)
Net income (loss) attributable to partners	$	2.8		$	(1.1	)	$	5.0		$	(5.4	)	$	1.3

Condensed Consolidating Statements of Operations
Three Months Ended December 31, 2011
(in millions)
	Parent			Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenue:
Retail	$	—		$	295.0	$	—		$	—		$	295.0
Marketing, supply and logistics	—			314.4		—			—			314.4
Storage and transportation	—			14.4		46.8			(2.0		)	59.2
	—			623.8		46.8			(2.0		)	668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	—			178.8		—			—			178.8
Marketing, supply and logistics	—			295.1		—			—			295.1
Storage and transportation	—			4.8		11.1			(2.0		)	13.9
	—			478.7		11.1			(2.0		)	487.8
Expenses:
Operating and administrative	—			76.5		6.1			—			82.6
Depreciation and amortization	—			36.7		12.0			—			48.7
Loss on disposal of assets	—			1.4		—			—			1.4
Operating income	—			30.5		17.6			—			48.1
Other income (expense):
Interest expense, net	(28.0		)	—		—			—			(28.0		)
Early extinguishment of debt	(24.9		)	—		—			—			(24.9		)
Other income	—			1.3		—			—			1.3
Equity in net income of subsidiary	49.3			—		—			(49.3		)	—
Income (loss) before income taxes	(3.6		)	31.8		17.6			(49.3		)	(3.5		)
Provision for income taxes	—			0.1		—			—			0.1
Net income (loss)	(3.6		)	31.7		17.6			(49.3		)	(3.6		)
Net income attributable to non-controlling partners in subsidiary	—			—		(0.4		)	—			(0.4		)
Net income (loss) attributable to partners	$	(3.6	)	$	31.7	$	17.2		$	(49.3	)	$	(4.0	)

Condensed Consolidating Statements of Comprehensive Income
Three Months Ended December 31, 2012
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries	Eliminations		Consolidated
Net income (loss)	2.8		(1.1	)	6.5	(5.4	)	2.8
Change in unrealized fair value on cash flow hedges	0.7		3.4		—	—		4.1
Change in Suburban Propane Partners, L.P. units	(0.4	)	—		—	—		(0.4	)
Comprehensive income (loss)	3.1		2.3		6.5	(5.4	)	6.5

Condensed Consolidating Statements of Comprehensive Income
Three Months Ended December 31, 2011
(in millions)
	Parent		Guarantor Subsidiaries		Non- Guarantor Subsidiaries	Eliminations		Consolidated
Net income (loss)	(3.6	)	31.7		17.6	(49.3	)	(3.6	)
Change in unrealized fair value on cash flow hedges	(0.1	)	(2.5	)	—	—		(2.6	)
Comprehensive income (loss)	(3.7	)	29.2		17.6	(49.3	)	(6.2	)

Condensed Consolidating Statements of Cash Flows
Three Months Ended December 31, 2012
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	—		$	5.8		$	22.2		$	—		$	28.0
Cash flows from investing activities
Acquisitions, net of cash acquired	—			0.1			(423.5		)	—			(423.4		)
Purchases of property, plant and equipment	—			(8.6		)	(43.6		)	—			(52.2		)
US Salt, LLC contribution, net	—			—			—			—			—
Payments associated with the disposal of retail propane operations	—			—			—			—			—
Other	—			—			—			—			—
Net cash used in investing activities	—			(8.5		)	(467.1		)	—			(475.6		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	—			203.2			581.1			—			784.3
Principal payments on long-term debt	—			(183.5		)	(317.8		)	—			(501.3		)
Distributions paid	(59.2		)	(36.7		)	(22.8		)	82.0			(36.7		)
Distributions paid to non-controlling partners	—			—			(7.2		)	—			(7.2		)
Distributions received	59.2			22.8			—			(82.0		)	—
Net proceeds from the issuance of common units	—			—			224.7			—			224.7
US Salt, LLC contribution, net	—			—			—			—			—
Other	(2.8		)	1.5			(13.1		)	—			(14.4		)
Net cash provided by (used in) financing activities	(2.8		)	7.3			444.9			—			449.4
Net increase (decrease) in cash	(2.8		)	4.6			—			—			1.8
Cash at beginning of period	2.9			(2.9		)	—			—			—
Cash at end of period	$	0.1		$	1.7		$	—		$	—		$	1.8

Condensed Consolidating Statements of Cash Flows
Three Months Ended December 31, 2011
(in millions)
	Parent			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Cash flows from operating activities	$	—		$	(8.7	)	$	31.9		$	—		$	23.2
Cash flows from investing activities
Acquisitions, net of cash acquired	—			(19.8		)	—			—			(19.8		)
Purchases of property, plant and equipment	—			(17.7		)	(39.4		)	—			(57.1		)
Other	—			2.7			—			—			2.7
Net cash used in investing activities	—			(34.8		)	(39.4		)	—			(74.2		)
Cash flows from financing activities:
Proceeds from the issuance of long-term debt	255.0			577.7			341.8			—			1,174.5
Principal payments on long-term debt	(255.0		)	(548.2		)	(516.6		)	—			(1,319.8		)
Distributions paid	(202.1		)	(83.9		)	(118.2		)	320.3			(83.9		)
Distributions received	202.1			118.2			—			(320.3		)	—
Net proceeds from the issuance of common units	—			—			292.7			—			292.7
Other	—			(13.2		)	7.9			—			(5.3		)
Net cash provided by financing activities	—			50.6			7.6			—			58.2
Net increase in cash	—			7.1			0.1			—			7.2
Cash at beginning of period	3.0			8.5			—			—			11.5
Cash at end of period	$	3.0		$	15.6		$	0.1		$	—		$	18.7

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Consolidated Statements Of Operations (USD $) In Millions, except Share data in Thousands, unless otherwise specified	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Revenue:
Retail	$ 0	$ 295.0
Marketing, supply and logistics	370.8	314.4
Storage and transportation	67.8	59.2
Total revenue	438.6	668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	178.8
Marketing, supply and logistics	338.8	295.1
Storage and transportation	19.8	13.9
Total cost of product sold	358.6	487.8
Expenses:
Operating and administrative	32.5	82.6
Depreciation and amortization	36.3	48.7
Loss on disposal of assets	0.8	1.4
Operating income	10.4	48.1
Other income (expense):
Interest expense, net	(8.1)	(28.0)
Early extinguishment of debt	0	(24.9)
Other income	0.6	1.3
Income (loss) before income taxes	2.9	(3.5)
Provision for income taxes	0.1	0.1
Net income (loss)	2.8	(3.6)
Net income attributable to non-controlling partners	(1.5)	(0.4)
Net income (loss) attributable to partners	1.3	(4.0)
Total limited partners’ interest in net income (loss)	$ 1.3	$ (4.0)
Net income (loss) per limited partner unit:
Basic (dollars)	0.01	(0.03)
Diluted (dollars)	0.01	(0.03)
Weighted-average limited partners’ units outstanding (in thousands):
Basic (units)	128,769	122,556
Dilutive (units)	2,813	0
Diluted (units)	131,582	122,556

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Fair Value Measurements

3 Months Ended

Dec. 31, 2012

Fair Value, Assets and Liabilities Measured on Recurring Basis [Abstract]

Fair Value Measurements

Fair Value Measurements

FASB Accounting Standards Codification Subtopic 820-10 (“820-10”) establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurement) and the lowest priority to unobservable inputs (level 3 measurement). The three levels of the fair value hierarchy are as follows:

• Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed equities and US government treasury securities.

• Level 2—Pricing inputs are other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over the counter (“OTC”) forwards, options and physical exchanges.

• Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

As of December 31, 2012, the Company held certain assets and liabilities that are required to be measured at fair value on a recurring basis. These included the Company’s derivative instruments related to heating oil, crude oil, NGLs and interest rates as well as the portion of inventory that is hedged in a qualifying fair value hedge. The Company’s derivative instruments consist of forwards, swaps, futures, physical exchanges and options.

Certain of the Company’s derivative instruments are traded on the NYMEX. These instruments have been categorized as level 1.

The Company’s derivative instruments also include OTC contracts, which are not traded on a public exchange. The fair values of these derivative instruments are determined based on inputs that are readily available in public markets or can be derived from information available in publicly quoted markets. These instruments have been categorized as level 2.

The Company’s inventory that is the hedged item in a qualifying fair value hedge is valued based on prices quoted from observable sources and verified with broker quotes. This inventory has been categorized as level 2.

The Company’s OTC options are valued based on Black Scholes option pricing model that considers time value and volatility of the underlying commodity. The inputs utilized in the model are based on publicly available information as well as broker quotes. These options have been categorized as level 2.

No changes in valuation techniques were made by the Company during the three months endedDecember 31, 2012.

The assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

The following tables set forth by level within the fair value hierarchy the Company's assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2012 and September 30, 2012 (in millions):

	December 31, 2012
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Designated as Hedges		Not Designated as Hedges		Netting Agreements(a)			Total
Assets
Assets from price risk management	$	2.5	$	40.4	$	—	$	42.9	$	5.7	$	37.2	$	(12.1	)	$	30.8
Inventory	—		48.4		—		48.4		—		—		—			48.4
SPH units	5.5		—		—		5.5		—		—		—			5.5
Total assets at fair value	$	8.0	$	88.8	$	—	$	96.8	$	5.7	$	37.2	$	(12.1	)	$	84.7
Liabilities
Liabilities from price risk management	$	2.9	$	30.2	$	—	$	33.1	$	4.2	$	28.9	$	(8.9	)	$	24.2
Interest rate swaps	—		6.8		—		6.8		—		—		—			—
Total liabilities at fair value	$	2.9	$	37.0	$	—	$	39.9	$	4.2	$	28.9	$	(8.9	)	$	24.2

	September 30, 2012
	Fair Value of Derivatives
	Level 1		Level 2		Level 3		Total		Designated as Hedges		Not Designated as Hedges		Netting Agreements(a)			Total
Assets
Assets from price risk management	$	2.7	$	51.3	$	—	$	54.0	$	9.8	$	44.2	$	(16.5	)	$	37.5
Inventory	—		73.2		—		73.2		—		—		—			73.2
SPH units	5.9		—		—		5.9		—		—		—			5.9
Total assets at fair value	8.6		124.5		—		133.1		9.8		44.2		(16.5		)	116.6
Liabilities
Liabilities from price risk management	$	2.0	$	31.1	$	—	$	33.1	$	11.3	$	21.8	$	(12.2	)	$	20.9
Interest rate swap	—		7.5		—		7.5		7.5		—		—			7.5
Total liabilities at fair value	$	2.0	$	38.6	$	—	$	40.6	$	18.8	$	21.8	$	(12.2	)	$	28.4

(a) Amounts represent the impact of legally enforceable master netting agreements that allow the Company to settle positive and negative positions as well as cash collateral held or placed with the same counterparties.

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Business Acquisitions

3 Months Ended

Dec. 31, 2012

Business Combinations [Abstract]

Business Acquisitions

Business Acquisitions

On December 7, 2012, Inergy Midstream completed the acquisition of 100% of the ownership interest of Rangeland Energy, LLC in exchange for $425 million in cash, net of cash acquired in the transaction and subject to certain closing adjustments. Rangeland Energy, LLC was the owner and operator of the Crude Hub. Concurrently with the closing of the acquisition, Inergy Midstream completed the private placement of $225 million common units and $500 million of senior unsecured notes due 2020. The remaining net proceeds from these offerings were used to repay borrowings under the NRGM Credit Facility.

The primary purpose of this acquisition was to acquire the integrated crude oil loading terminal, storage, and pipeline assets of Rangeland Energy, LLC and its subsidiaries, which are located in Williams County, North Dakota. The COLT Hub primarily consists of 720,000 barrels of crude oil storage, two8,700-foot rail loops, an eight-bay truck unloading rack, and a 21-mile bi-directional crude oil pipeline that connects the hub to gathering systems and interstate crude oil pipelines. The following table summarizes the estimated fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

	December 7, 2012
Current assets	$	3.3
Property, plant and equipment	100.9
Intangible assets	157.2
Total identifiable assets acquired	261.4
Current liabilities	2.9
Total liabilities assumed	2.9
Net identifiable assets acquired	258.5
Goodwill	165.0
Net assets acquired	$	423.5

The $165.0 million of goodwill is reflected in Inergy's marketing, supply and logistics segment. Goodwill recognized in the transaction relates primarily to expanding our geographic footprint into a new growing shale play.  The name of the acquired entity has since been changed from Rangeland Energy, LLC to Inergy Crude Logistics, LLC ("ICL"). Based on the preliminary purchase price allocation, amortization expenses relative to the intangible assets acquired are expected to be $8.9 million, $10.9 million, $10.9 million, $9.8 million, and $9.5 million for the years ended September 30, 2013 through September 30, 2017, respectively.

The following represents the pro forma consolidated statements of operations as if the COLT Hub had been included in the consolidated results of the Company for the full three-month periods endedDecember 31, 2012 and 2011 (in millions):

	(Unaudited) Pro Forma Consolidated Statement of Operations
	Three Months Ended December 31,
	2012		2011
Revenue	$	443.8	$	668.6
Net income	$	1.3	$	(10.2	)

These amounts have been calculated after applying the Company's accounting policies and adjusting the results of Rangeland Energy, LLC to reflect the depreciation that would have been charged assuming the preliminary fair value adjustments to property, plant and equipment and intangible assets had been made at the beginning of the current period.  The purchase price allocation for this acquisition has been prepared on a preliminary basis pending final asset valuation and asset rationalization, and changes are expected when additional information becomes available. Accordingly, the purchase accounting adjustments made in connection with the development of the unaudited pro forma are preliminary and subject to change. The entities acquired were development stage entities (as defined by ASC Topic 915, Development Stage Entities) until commencing principal commercial operations in June 2012.

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Business Acquisitions (Tables)

3 Months Ended

Dec. 31, 2012

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The following table summarizes the estimated fair values of the assets acquired and liabilities assumed at the acquisition date (in millions):

	December 7, 2012
Current assets	$	3.3
Property, plant and equipment	100.9
Intangible assets	157.2
Total identifiable assets acquired	261.4
Current liabilities	2.9
Total liabilities assumed	2.9
Net identifiable assets acquired	258.5
Goodwill	165.0
Net assets acquired	$	423.5

Business Acquisition, Pro Forma Information

The following represents the pro forma consolidated statements of operations as if the COLT Hub had been included in the consolidated results of the Company for the full three-month periods endedDecember 31, 2012 and 2011 (in millions):

	(Unaudited) Pro Forma Consolidated Statement of Operations
	Three Months Ended December 31,
	2012		2011
Revenue	$	443.8	$	668.6
Net income	$	1.3	$	(10.2	)

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Subsequent Events

3 Months Ended

Dec. 31, 2012

Subsequent Events [Abstract]

Subsequent Events

Subsequent Events

The Company has identified subsequent events requiring disclosure through the date of the filing of this Form 10-Q.

On January 25, 2013, Inergy declared a distribution of $0.290 per limited partner unit to be paid on February 14, 2013, to unitholders of record on February 7, 2013.

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Partners' Capital

3 Months Ended

Dec. 31, 2012

Partners' Capital Account, Distributions [Abstract]

Partners' Capital

Partners’ Capital

Class B Units

The Class B units have similar rights and obligations of Inergy common units except that the units will pay distributions in kind rather than in cash for a certain period of time. All of the outstanding Class B units converted into Inergy common units in the first quarter of fiscal 2013. There were no Class B units outstanding as of December 31, 2012. For a complete description of the Class B units, please see the Third Amended and Restated Agreement of Limited Partnership of Inergy, filed on Form 8-K on November 5, 2010.

Quarterly Distributions of Available Cash

A summary of the Company’s limited partner quarterly distribution for the three months endedDecember 31, 2012 and 2011, is presented below:

Three Months Ended December 31, 2012
Record Date	Payment Date	Per Unit Rate		Distribution Amount (in millions)
November 7, 2012	November 14, 2012	$	0.290	$	36.4
				$	36.4
Three Months Ended December 31, 2011
Record Date	Payment Date	Per Unit Rate		Distribution Amount (in millions)
November 7, 2011	November 14, 2011	$	0.705	$	83.9
				$	83.9

On January 25, 2013, Inergy declared a distribution of $0.290 per limited partner unit to be paid on February 14, 2013, to unitholders of record on February 7, 2013 with respect to the first fiscal quarter of 2013. On February 14, 2012, Inergy paid a distribution of $0.705 per limited partner unit to unitholders of record on February 7, 2012 with respect to the first fiscal quarter of 2012.

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Risk Management

3 Months Ended

Dec. 31, 2012

Risk Management - Notional Amounts and Terms of Companys Derivative Financial Instruments [Abstract]

Risk Management

Risk Management

The Company is exposed to certain market risks related to its ongoing business operations. These risks include exposure to changing commodity prices as well as fluctuations in interest rates. The Company utilizes derivative instruments to manage its exposure to fluctuations in commodity prices, which is discussed more fully below. The Company also periodically utilizes derivative instruments to manage its exposure to fluctuations in interest rates, which is discussed more fully in Note 7. Additional information related to derivatives is provided in Note 2 and Note 6.

Commodity Derivative Instruments and Price Risk Management

Risk Management Activities

Inergy sells NGLs to energy related businesses and may use a variety of financial and other instruments including forward contracts involving physical delivery of propane. Inergy will enter into offsetting positions to economically hedge against the exposure its customer contracts create, however does not designate these instruments as hedging instruments for accounting purposes. These instruments are marked to market with the changes in the market value reflected in cost of product sold. Inergy attempts to balance its contractual portfolio in terms of notional amounts and timing of performance and delivery obligations. This balance in the contractual portfolio significantly reduces the volatility in cost of product sold related to these instruments.

Cash Flow Hedging Activity

Prior to the disposition of its retail propane operations, the Company entered into derivative instruments to hedge a significant portion of its exposure to fluctuations in commodity prices as a result of entering into fixed price contracts with certain of its retail customers. The Company designated these instruments as cash flow hedges. As a result of the disposition of the retail propane operations, the Company no longer anticipates utilizing cash flow hedges for commodity price risk. However, existing cash flow hedges in place at the time of the disposition will remain in OCI until the forecasted transaction takes place, the bulk of which will be in the first two quarters of fiscal 2013. The forecasted transaction is still expected to take place due to the supply arrangement with SPH.

Fair Value Hedging Activity

Inergy will enter into derivative instruments to hedge its exposure to fluctuating commodity prices that results from maintaining its NGL inventory. These instruments qualify as fair value hedges. This accounting treatment requires the fair value changes in both the derivative instruments and the hedged inventory to be recorded in cost of product sold.

A significant amount of inventory held in bulk storage facilities is hedged as it is not expected to be sold in the immediate future and is therefore exposed to fluctuations in commodity prices.

Commodity Price and Credit Risk

Notional Amounts and Terms

The notional amounts and terms of the Company’s derivative financial instruments include the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane, crude and heating oil (barrels)	6.8	7.8	7.8	9.2
Natural gas (MMBTUs)	13.6	13.6	11.8	11.6

Notional amounts reflect the volume of transactions, but do not represent the amounts exchanged by the parties to the financial instruments. Accordingly, notional amounts do not reflect the Company’s monetary exposure to market or credit risks.

Fair Value of Derivative Instruments

The following tables detail the amount and location on the Company’s consolidated balance sheets and consolidated statements of operations related to all of its commodity and debt derivatives (in millions):

	Amount of Gain (Loss) Recognized in Net Income from Derivatives
	Three Months Ended December 31,
	2012			2011
Derivatives in fair value hedging relationships:
Commodity (a)	$	2.9		$	4.3
Debt(b)	—			0.1
Total fair value of derivatives	$	2.9		$	4.4
	Amount of Gain (Loss) Recognized in Net Income on Item Being Hedged
	Three Months Ended December 31,
	2012			2011
Derivatives in fair value hedging relationships:
Commodity (a)	$	(0.8	)	$	(3.3	)
Debt(b)	—			(0.1		)
Total fair value of derivatives	$	(0.8	)	$	(3.4	)
	Amount of Gain (Loss) Recognized in OCI on Effective Portion of Derivatives
	Three Months Ended December 31,
	2012			2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	—		$	(3.2	)
Debt (e)	—			(0.1		)
Total fair value of derivatives	$	—		$	(3.3	)
	Amount of Gain (Loss) Reclassified from OCI to Net Income
	Three Months Ended December 31,
	2012			2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	(3.4	)	$	(0.7	)
Debt (e)	(0.7		)	—
Total fair value of derivatives	$	(4.1	)	$	(0.7	)

	Amount of Gain (Loss) Recognized  in Net Income on Ineffective Portion of Derivatives and Amount Excluded from Testing
	Three Months Ended December 31,
	2012		2011
Derivatives in cash flow hedging relationships:
Commodity (c)	$	—	$	—
Debt (e)	—		—
Total fair value of derivatives	$	—	$	—
	Amount of Gain (Loss) Recognized in Net Income from Derivatives
	Three Months Ended December 31,
	2012		2011
Derivatives not designated as hedging instruments:
Commodity (d)	$	5.5	$	2.8

(a) The gain (loss) on both the derivative and the item being hedged are located in cost of product sold in the consolidated statements of operations.

(b) The gain (loss) on both the derivative and the item being hedged are located in interest expense in the consolidated statements of operations.

(c) The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in cost of product sold.

(d) The gain (loss) is recognized in cost of product sold.

(e) The gain (loss) on the amount reclassified from OCI into income, the ineffective portion and the amount excluded from effectiveness testing are included in interest expense.

All contracts subject to price risk had a maturity of twenty-six months or less; however, 99% of the contracts expire within twelve months.

Credit Risk

Inherent in the Company's contractual portfolio are certain credit risks. Credit risk is the risk of loss from nonperformance by suppliers, customers or financial counterparties to a contract. Inergy takes an active role in managing credit risk and has established control procedures, which are reviewed on an ongoing basis. The Company attempts to minimize credit risk exposure through credit policies and periodic monitoring procedures as well as through customer deposits, letters of credit and entering into netting agreements that allow for offsetting counterparty receivable and payable balances for certain financial transactions, as deemed appropriate. The counterparties associated with assets from price risk management activities as of December 31, 2012 and September 30, 2012, were energy marketers and propane retailers, resellers and dealers.

Certain of the Company's derivative instruments have credit limits that require the Company to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as the Company's established credit limit with the respective counterparty. If the Company's credit rating were to change, the counterparties could require the Company to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in the Company's credit rating as well as the requirements of the individual counterparty. The aggregate fair value of all commodity derivative instruments with credit-risk-related contingent features that are in a liability position on December 31, 2012, is $4.0 million for which the Company has posted collateral of $3.0 million and $6.1 million of NYMEX margin deposit in the normal course of business. The Company has received collateral of $9.4 million in the normal course of business. All collateral amounts have been netted against the asset or liability with the respective counterparty.

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Long-Term Debt

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Long-Term Debt

Long-Term Debt

Long-term debt consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Inergy credit agreement	$	332.1	$	311.7
Inergy senior unsecured notes	11.5		11.5
Inergy obligations under noncompetition agreements and notes to former owners of businesses acquired	2.9		3.5
NRGM credit facility	179.8		416.5
NRGM senior unsecured notes	500.0		—
Total debt	1,026.3		743.2
Less: current portion	2.1		3.4
Total long-term debt	$	1,024.2	$	739.8

On November 24, 2009, Inergy entered into a secured credit facility (“Credit Agreement”) which, at the time, provided borrowing capacity of up to $525 million in the form of a $450 million revolving general partnership credit facility and a $75 million working capital credit facility. The Credit Agreement was to mature on November 22, 2013.

On February 2, 2011, Inergy amended and restated the Credit Agreement to add a $300 million term loan facility. The term loan was repaid in full in December 2011 as discussed below. The term loan was to mature on February 2, 2015, and did bear interest, at Inergy's option, subject to certain limitations, at a rate equal to the following:

• the Alternate Base Rate, which is defined as the higher of (i) the federal funds rate plus 0.50%; (ii) JP Morgan’s prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 1.00% to 2.25%; or

• the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 2.00% to 3.25%.

On July 28, 2011, Inergy further amended its Credit Agreement to (i) raise the aggregate revolving commitment from $525 million to $700 million with the amount existing as a singular tranche, (ii) reduce the applicable rate on revolving loans and commitment fees, (iii) modify and refresh certain covenants and covenant baskets, and (iv) extend the maturity date from November 22, 2013 to July 28, 2016.

On April 13, 2012, Inergy further amended its Credit Agreement. This amendment, among other things, (i) permitted Inergy to sell up to 5,000,000 of the Inergy Midstream common units that Inergy owns, (ii) permitted Inergy to sell US Salt, (iii) decreased the aggregate revolving commitment and general partnership commitment from $700 million to $550 million, and (iv) adjusted several of the financial covenants.

On July 26, 2012, Inergy further amended its Credit Agreement in order to (i) permit Inergy to enter into a series of transactions as described in the Contribution Agreement dated as of April 25, 2012 among Inergy and SPH, (ii) permit Inergy to repurchase, repay or redeem all or any portion of the senior notes that remain outstanding after the closing of the Contribution Agreement,  (iii) modify certain negative and financial covenants under the Credit Agreement, and  (iv) allow Inergy to redeem, buy back or otherwise acquire up to $100 million of its common units on or prior to March 31, 2013 subject to meeting certain financial covenant requirements. This amendment did not become effective until the contribution of Inergy's retail propane assets to SPH closed on August 1, 2012. In conjunction with the close of this transaction, $1,187.0 million in Inergy senior notes were exchanged for SPH senior notes and cash paid directly to noteholders, thereby eliminating the senior notes from Inergy's consolidated balance sheet on August 1, 2012.

The Credit Agreement contains various covenants and restrictive provisions that limit its ability to, among other things:

• incur additional debt;

• make distributions on or redeem or repurchase units;

• make certain investments and acquisitions;

• incur or permit certain liens to exist;

• enter into certain types of transactions with affiliates;

• merge, consolidate or amalgamate with another company; and

• transfer or otherwise dispose of assets.

The Credit Agreement contains the following financial covenants:

• the ratio of Inergy's total funded debt (as defined in the Credit Agreement) to consolidated EBITDA (as defined in the Credit Agreement) for the four fiscal quarters most recently ended must be no greater than 4.75 to 1.0; and

• the ratio of Inergy's consolidated EBITDA to consolidated interest expense (as defined in the Credit Agreement), for the four fiscal quarters then most recently ended, must not be less than 2.50 to 1.0.

If Inergy should fail to perform its obligations under these and other covenants, the Revolving Loan Facility could be terminated and any outstanding borrowings, together with accrued interest, under the Credit Agreement could be declared immediately due and payable. The Credit Agreement also has cross default provisions that apply to any other material indebtedness of Inergy, excluding the debt of Inergy's majority-owned subsidiary, Inergy Midstream.

All borrowings under the Credit Agreement are generally secured by substantially all of Inergy's assets and the equity interests in all of Inergy's wholly owned subsidiaries, and loans thereunder bear interest, at Inergy's option, subject to certain limitations, at a rate equal to the following:

• the Alternate Base Rate, which is defined as the higher of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 0.75% to 2.00%; or

• the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 1.75% to 3.00%.

We are required to use 50% of the net cash proceeds (that are not applied to purchase replacement assets) from asset dispositions (other than the sale of inventory and motor vehicles in the ordinary course of business, sales of assets among us and our domestic subsidiaries and the sale or disposition of obsolete or worn-out equipment) to reduce borrowings under the Credit Agreement during any fiscal year in which unapplied net cash proceeds are in excess of $50 million.

At December 31, 2012, the balance outstanding under the Credit Agreement was $332.1 million. At September 30, 2012, the balance outstanding under the Credit Agreement was $311.7 million. The interest rates of the Revolving Loan Facility are based on prime rate and LIBOR plus the applicable spreads, resulting in interest rates which were between 1.96% and 4.00% at December 31, 2012, and 2.99% and 5.00% at September 30, 2012. Availability under the Credit Agreement amounted to $168.7 million and $184.0 million at December 31, 2012 and September 30, 2012, respectively. Outstanding standby letters of credit under the Credit Agreement amounted to $49.2 million and $54.3 million at December 31, 2012 and September 30, 2012, respectively.

At December 31, 2012, Inergy was in compliance with the debt covenants in the Credit Agreement and senior unsecured notes.

Inergy is party to six interest rate swap agreements scheduled to mature in 2016 to hedge its exposure to variable interest payments due under the Credit Agreement. These swap agreements require Inergy to pay the counterparty an amount based on fixed rates from 0.84% to 2.52% due quarterly. In exchange, the counterparty is required to make quarterly floating interest rate payments on the same date to Inergy based on the three-month LIBOR applied to the same aggregate notional amount of $225.0 million. These swap agreements have been accounted for as cash flow hedges.

Inergy Midstream

NRGM Credit Facility

On December 21, 2011, Inergy Midstream entered into a $500 million, five-year revolving credit facility (“NRGM Credit Facility”). The NRGM Credit Facility is available to fund acquisitions, working capital and internal growth projects and for general partnership purposes. The NRGM Credit Facility has an accordion feature that allows Inergy Midstream to increase the available borrowings under the facility by up to $250 million, subject to the lenders' agreement and the satisfaction of certain conditions. In addition, its credit facility includes a sub-limit up to $10 million for same-day swing line advances and a sub-limit up to $100 million for letters of credit.

On April 16, 2012, Inergy Midstream exercised a portion of its accordion feature under the NRGM Credit Facility and increased the loan commitments thereunder by $100 million and as a result, the accordion feature available to Inergy Midstream is now $150 million. The aggregate amount of revolving loan commitments under the NRGM Credit Facility is now $600 million, and can be increased by up to $150 million, subject to the lenders' agreement and the satisfaction of certain conditions.

On November 16, 2012, Inergy Midstream amended its revolving credit facility to, among other things, (i) amend the definition of consolidated EBITDA to include projected consolidated EBITDA attributable to fixed fee contracts acquired in the acquisition of the COLT Hub; (ii) increase the maximum total leverage ratio to 5.50 to 1.0 for any two consecutive fiscal quarters ending on or immediately after the date of the consummation of a permitted acquisition in excess of $50 million; and (iii) add a senior secured leverage ratio of 3.75 to 1.0 on and after the cumulative issuance of $200 million or more of permitted junior debt.

At December 31, 2012, the balance outstanding under the NRGM Credit Facility was $179.8 million. At September 30, 2012, the balance outstanding under the NRGM Credit Facility was $416.5 million. Outstanding standby letters of credit under the NRGM Credit Facility amounted to $2.0 million at December 31, 2012. As a result, Inergy Midstream had approximately $418.2 million of remaining capacity at December 31, 2012, subject to compliance with any applicable covenants under such facility.

The NRGM Credit Facility contains various covenants and restrictive provisions that limit its ability to, among other things:

• incur additional debt;

• make distributions on or redeem or repurchase units;

• make certain investments and acquisitions;

• incur or permit certain liens to exist;

• enter into certain types of transactions with affiliates;

• merge, consolidate or amalgamate with another company; and

• transfer or otherwise dispose of assets.

If Inergy Midstream fails to perform its obligations under these and other covenants, the lenders' credit commitment could be terminated and any outstanding borrowings, together with accrued interest, under its credit facility could be declared immediately due and payable. The NRGM Credit Facility also has cross default provisions that apply to any other material indebtedness of Inergy Midstream.

Borrowings under the NRGM Credit Facility are generally secured by pledges of the equity interests in Inergy Midstream's wholly owned subsidiaries, liens on substantially all of its assets and guarantees issued by all of Inergy Midstream's subsidiaries. Borrowings under the NRGM Credit Facility (other than swing line loans) will bear interest at its option at either:

• the Alternate Base Rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) JP Morgan's prime rate; or (iii) the Adjusted LIBO Rate plus 1%; plus a margin varying from 0.75% to 1.75% depending on our most recent total leverage ratio; or

• the Adjusted LIBO Rate, which is defined as the LIBO Rate plus a margin varying from 1.75% to 2.75% depending on Inergy Midstream's most recent total leverage ratio.

Swing line loans bear interest at the Alternate Base Rate plus a margin varying from 0.75% to 1.75%. The unused portion of the NRGM Credit Facility is subject to a commitment fee ranging from 0.30% to 0.50% per annum according to its most recent total leverage ratio. Interest on Alternative Base Rate loans is payable quarterly or, if the Adjusted LIBO Rate applies, it may be paid at more frequent intervals.

The NRGM Credit Facility requires maintenance of a consolidated leverage ratio (as defined in its credit agreement) of not more than 5.00 to 1.0 (subject to increase to 5.50 to 1.0 following certain permitted acquisitions, as indicated above) and an interest coverage ratio (as defined in its credit agreement) of not less than 2.50 to 1.0. The NRGM Credit Facility also requires maintenance of a senior secured leverage ratio (as defined in its credit agreement) of not more than 3.75 to 1.0 on and after the cumulative issuance of $200 million or more of permitted junior debt.

NRGM Senior Notes

On December 7, 2012, Inergy Midstream and NRGM Finance Corp. (“Finance Corp.” and together with Inergy Midstream, the “Issuers”) issued and sold $500 million in a private offering in aggregate principal amount of their 6.0% Senior Notes due 2020 (the “NRGM Notes”) pursuant to a purchase agreement dated November 29, 2012. The Issuers issued the NRGM Notes pursuant to an indenture dated as of December 7, 2012 (the “Indenture”), among the Issuers, the subsidiary guarantors and U.S. Bank National Association, as trustee. The NRGM Notes will mature on December 15, 2020. Interest on the NRGM Notes is payable semi-annually in arrears on June 15 and December 15 of each year, beginning on June 15, 2013. The NRGM Notes are guaranteed on a senior unsecured basis by all of Inergy Midstream's existing subsidiaries (other than Finance Corp.) and certain of the Inergy Midstream's future subsidiaries.

The Indenture restricts Inergy Midstream's ability and the ability of its subsidiaries to: (i) sell assets; (ii) pay distributions on, redeem or repurchase Inergy Midstream's units or redeem or repurchase its subordinated debt; (iii) make investments; (iv) incur or guarantee additional indebtedness or issue preferred units; (v) create or incur certain liens; (vi) enter into agreements that restrict distributions or other payments from Inergy Midstream's restricted subsidiaries to Inergy Midstream; (vii) consolidate, merge or transfer all or substantially all of Inergy Midstream's assets; (viii) engage in transactions with affiliates; (ix) create unrestricted subsidiaries and (x) enter into sale and leaseback transactions. These covenants are subject to a number of important exceptions and qualifications. At any time when the NRGM Notes are rated investment grade by either of Moody’s Investors Service, Inc. or Standard & Poor’s Ratings Services and no Default or Event of Default (each as defined in the Indenture) has occurred and is continuing, many of these covenants will terminate.

Inergy and its wholly owned subsidiaries do not provide credit support or guarantee any amounts outstanding under the NRGM Credit Facility or the NRGM Notes.

At December 31, 2012, Inergy Midstream was in compliance with the debt covenants in the NRGM Credit Facility and the NRGM Notes.

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Commitments and Contingencies

3 Months Ended

Dec. 31, 2012

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Inergy periodically enters into agreements with suppliers to purchase fixed quantities of NGLs, distillates and natural gas at fixed prices. At December 31, 2012, the total of these firm purchase commitments was $317.2 million, all of which will occur over the course of the next twelve months. The Company also enters into non-binding agreements with suppliers to purchase quantities of NGLs, distillates and natural gas at variable prices at future dates at the then prevailing market prices.

Inergy and Inergy Midstream have entered into certain purchase commitments in connection with the identified growth projects primarily related to the Watkins Glen NGL development project and the MARC I Pipeline. The Watkins Glen NGL development project entails the conversion of certain caverns created by US Salt into 2.1 million barrels of NGL storage.  The MARC I Pipeline, which was placed into service in December 2012, is a 39 mile, 30" bi-directional pipeline that extends between the Stagecoach south lateral interconnect with Tennessee Gas Pipeline Company's 300 Line near its compressor station 319 and Transco's Leidy Line near its compressor station 517, and is capable of providing 550 MMcf/d of firm transportation capacity. At December 31, 2012, the total of Inergy's and Inergy Midstream's storage and transportation operations' firm purchase commitments was approximately $8.4 million, and the majority of the purchases associated with these commitments are expected to occur over the course of the next twelve months.

Inergy is periodically involved in litigation proceedings. The results of litigation proceedings cannot be predicted with certainty; however, management believes that Inergy does not have material potential liability in connection with these proceedings that would have a significant financial impact on its consolidated financial condition, results of operations or cash flows.

In June 2010, Inergy Midstream and CNYOG entered into a letter of intent with Anadarko Petroleum Corporation (“Anadarko”) which contemplated that, subject to certain conditions, Anadarko may exercise an option to acquire up to a 25% ownership interest in the MARC I pipeline. On September 23, 2011, Anadarko filed a complaint against the Inergy Midstream entities in the Court of Common Pleas in Lycoming County, Pennsylvania (Cause No. 11-01697) alleging that (i) Anadarko had an option to acquire, and timely exercised its option to acquire, a 25% ownership interest in the MARC I Pipeline, (ii) the Inergy Midstream entities refused to enter into definitive agreements under which Anadarko would acquire a 25% interest in the pipeline and, by doing so, the Inergy Midstream entities breached the letter of intent, and (iii) by refusing to enter into definitive agreements, the Inergy Midstream entities breached a duty of good faith and fair dealing in connection with the letter of intent. Based on these allegations, Anadarko seeks various remedies, including specific performance of the letter of intent and monetary damages.

The Inergy Midstream entities filed an answer to Anadarko's complaint on January 17, 2012 and discovery is ongoing. The Inergy Midstream entities believe that Anadarko's claims are without merit and intends to vigorously defend themselves in the lawsuit. Inergy may be required to indemnify Inergy Midstream for litigation-related costs and damages under the omnibus agreement that governs its relationship with Inergy Midstream and its general partner.

Inergy utilizes third-party insurance subject to varying retention levels of self-insurance, which management considers prudent. Such self-insurance relates to losses and liabilities primarily associated with medical claims, workers' compensation claims and general, product, vehicle and environmental liability. Losses are accrued based upon management's estimates of the aggregate liability for claims incurred using certain assumptions followed in the insurance industry and based on past experience. The primary assumption utilized is actuarially determined loss development factors. The loss development factors are based primarily on historical data. Inergy's self insurance reserves could be affected if future claims development differs from the historical trends. Inergy believes changes in health care costs, trends in health care claims of its employee base, accident frequency and severity and other factors could materially affect the estimate for these liabilities. Inergy continually monitors changes in employee demographics, incident and claim type and evaluates its insurance accruals and adjusts its accruals based on its evaluation of these qualitative data points. Inergy is liable for the development of claims for its disposed retail propane operations, provided they were reported prior to August 1, 2012. At December 31, 2012 and September 30, 2012, Inergy's self-insurance reserves were $21.2 million and $23.8 million, respectively. The Company estimates that $15.0 million of this balance will be paid subsequent to December 31, 2013. As such, $15.0 million has been classified in other long-term liabilities on the consolidated balance sheets.

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Certain Balance Sheet Information (Inventories) (Detail) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012
Inventory [Line Items]
Inventories	$ 63.5	$ 87.1
NGLs
Inventory [Line Items]
Inventories	56.9	80.8
Parts, supplies and other
Inventory [Line Items]
Inventories	$ 6.6	$ 6.3

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Condensed Consolidating Financial Information (Condensed Consolidating Statements Of Operations) (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Revenue:
Retail	$ 0	$ 295.0
Total revenue	438.6	668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	178.8
Total cost of product sold	358.6	487.8
Expenses:
Operating and administrative	32.5	82.6
Depreciation and amortization	36.3	48.7
Loss on disposal of assets	0.8	1.4
Operating income	10.4	48.1
Other income (expense):
Other income	0.6	1.3
Income (loss) before income taxes	2.9	(3.5)
Provision for income taxes	0.1	0.1
Net income (loss)	2.8	(3.6)
Net income attributable to non-controlling partners in subsidiary	(1.5)	(0.4)
Net income (loss) attributable to partners	1.3	(4.0)
Parent Company
Revenue:
Retail	0	0
Marketing, supply and logistics	0	0
Storage and transportation	0	0
Total revenue	0	0
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	0
Marketing, supply and logistics	0	0
Storage and transportation	0	0
Total cost of product sold	0	0
Expenses:
Operating and administrative	0	0
Depreciation and amortization	0	0
Loss on disposal of assets	0	0
Operating income	0	0
Other income (expense):
Interest expense, net	(2.6)	(28.0)
Early extinguishment of debt	0	(24.9)
Gain on disposal of retail propane operations	0
Loss on Suburban Propane Partners, L.P. units	0
Other income	0	0
Equity in net income of subsidiary	5.4	49.3
Income (loss) before income taxes	2.8	(3.6)
Provision for income taxes	0	0
Net income (loss)	2.8	(3.6)
Net income attributable to non-controlling partners in subsidiary	0	0
Net income (loss) attributable to partners	2.8	(3.6)
Guarantor Subsidiaries
Revenue:
Retail	0	295.0
Marketing, supply and logistics	368.0	314.4
Storage and transportation	23.6	14.4
Total revenue	391.6	623.8
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	178.8
Marketing, supply and logistics	338.5	295.1
Storage and transportation	12.6	4.8
Total cost of product sold	351.1	478.7
Expenses:
Operating and administrative	20.8	76.5
Depreciation and amortization	21.1	36.7
Loss on disposal of assets	0.2	1.4
Operating income	(1.6)	30.5
Other income (expense):
Interest expense, net	0	0
Early extinguishment of debt	0	0
Gain on disposal of retail propane operations	0
Loss on Suburban Propane Partners, L.P. units	0
Other income	0.6	1.3
Equity in net income of subsidiary	0	0
Income (loss) before income taxes	(1.0)	31.8
Provision for income taxes	0.1	0.1
Net income (loss)	(1.1)	31.7
Net income attributable to non-controlling partners in subsidiary	0	0
Net income (loss) attributable to partners	(1.1)	31.7
Non-Guarantor Subsidiaries
Revenue:
Retail	0	0
Marketing, supply and logistics	2.8	0
Storage and transportation	47.6	46.8
Total revenue	50.4	46.8
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	0
Marketing, supply and logistics	0.3	0
Storage and transportation	10.6	11.1
Total cost of product sold	10.9	11.1
Expenses:
Operating and administrative	11.7	6.1
Depreciation and amortization	15.2	12.0
Loss on disposal of assets	0.6	0
Operating income	12.0	17.6
Other income (expense):
Interest expense, net	(5.5)	0
Early extinguishment of debt	0	0
Gain on disposal of retail propane operations	0
Loss on Suburban Propane Partners, L.P. units	0
Other income	0	0
Equity in net income of subsidiary	0	0
Income (loss) before income taxes	6.5	17.6
Provision for income taxes	0	0
Net income (loss)	6.5	17.6
Net income attributable to non-controlling partners in subsidiary	(1.5)	(0.4)
Net income (loss) attributable to partners	5.0	17.2
Consolidation, Eliminations
Revenue:
Retail	0	0
Marketing, supply and logistics	0
Storage and transportation	(3.4)	(2.0)
Total revenue	(3.4)	(2.0)
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	0
Marketing, supply and logistics	0	0
Storage and transportation	(3.4)	(2.0)
Total cost of product sold	(3.4)	(2.0)
Expenses:
Operating and administrative	0	0
Depreciation and amortization	0	0
Loss on disposal of assets	0	0
Operating income	0	0
Other income (expense):
Interest expense, net	0	0
Early extinguishment of debt	0	0
Gain on disposal of retail propane operations	0
Loss on Suburban Propane Partners, L.P. units	0
Other income	0	0
Equity in net income of subsidiary	(5.4)	(49.3)
Income (loss) before income taxes	(5.4)	(49.3)
Provision for income taxes	0	0
Net income (loss)	(5.4)	(49.3)
Net income attributable to non-controlling partners in subsidiary	0	0
Net income (loss) attributable to partners	(5.4)	(49.3)
Consolidated Entities
Revenue:
Retail	0	295.0
Marketing, supply and logistics	370.8	314.4
Storage and transportation	67.8	59.2
Total revenue	438.6	668.6
Cost of product sold (excluding depreciation and amortization as shown below):
Retail	0	178.8
Marketing, supply and logistics	338.8	295.1
Storage and transportation	19.8	13.9
Total cost of product sold	358.6	487.8
Expenses:
Operating and administrative	32.5	82.6
Depreciation and amortization	36.3	48.7
Loss on disposal of assets	0.8	1.4
Operating income	10.4	48.1
Other income (expense):
Interest expense, net	(8.1)	(28.0)
Early extinguishment of debt	0	(24.9)
Gain on disposal of retail propane operations	0
Loss on Suburban Propane Partners, L.P. units	0
Other income	0.6	1.3
Equity in net income of subsidiary	0	0
Income (loss) before income taxes	2.9	(3.5)
Provision for income taxes	0.1	0.1
Net income (loss)	2.8	(3.6)
Net income attributable to non-controlling partners in subsidiary	(1.5)	(0.4)
Net income (loss) attributable to partners	$ 1.3	$ (4.0)

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Estimated Useful Lives Of Property, Plant And Equipment

Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:

	Years
Land, buildings and improvements	15 – 70
Office furniture and equipment	3 – 7
Vehicles	3 – 10
Pipelines	15
Tanks and plant equipment	3 – 30
Base gas	10

Estimated Economic Lives Of Intangible Assets

Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows:

	Years
Customer accounts	15 - 20
Covenants not to compete	2 - 10
Deferred financing costs	4 - 10

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Long-Term Debt (Tables)

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Components Of Long-Term Debt

Long-term debt consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Inergy credit agreement	$	332.1	$	311.7
Inergy senior unsecured notes	11.5		11.5
Inergy obligations under noncompetition agreements and notes to former owners of businesses acquired	2.9		3.5
NRGM credit facility	179.8		416.5
NRGM senior unsecured notes	500.0		—
Total debt	1,026.3		743.2
Less: current portion	2.1		3.4
Total long-term debt	$	1,024.2	$	739.8

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Segments (Summary Of Segment Information) (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012 segment	Dec. 31, 2011	Dec. 07, 2012	Sep. 30, 2012
Number of Reportable Segments	2
Total revenue	$ 438.6	$ 668.6
Gross profit (excluding depreciation and amortization)	80.0	180.8
Identifiable assets	265.2	399.1
Goodwill	330.8	501.2	165.0	165.8
Property, plant and equipment	2,297.9	2,671.5		2,160.7
Expenditures for property, plant and equipment	36.8	50.1
Retail revenues
Total revenue	0	295.0
Marketing, supply and logistics revenues
Total revenue	370.8	314.4
Storage and transportation revenues
Total revenue	67.8	59.2
Marketing, Supply and Logistics Operations
Gross profit (excluding depreciation and amortization)	32.0	135.5
Identifiable assets	235.9	370.5
Goodwill	168.8	339.2
Property, plant and equipment	455.7	1,083.5
Expenditures for property, plant and equipment	2.9	8.2
Marketing, Supply and Logistics Operations | Retail revenues
Total revenue	0	295.0
Marketing, Supply and Logistics Operations | Marketing, supply and logistics revenues
Total revenue	370.8	314.8
Marketing, Supply and Logistics Operations | Storage and transportation revenues
Total revenue	0	0
Storage and Transportation Operations
Gross profit (excluding depreciation and amortization)	48.0	45.3
Identifiable assets	29.3	28.6
Goodwill	141.8	141.8
Property, plant and equipment	1,835.3	1,575.5
Expenditures for property, plant and equipment	33.9	41.8
Storage and Transportation Operations | Retail revenues
Total revenue	0	0
Storage and Transportation Operations | Marketing, supply and logistics revenues
Total revenue	0	0
Storage and Transportation Operations | Storage and transportation revenues
Total revenue	67.8	59.2
Intersegment Operations
Gross profit (excluding depreciation and amortization)	0	0
Identifiable assets	0	0
Goodwill	0	0
Property, plant and equipment	0	0
Expenditures for property, plant and equipment	0	0
Intersegment Operations | Retail revenues
Total revenue	0	0
Intersegment Operations | Marketing, supply and logistics revenues
Total revenue	0	(0.4)
Intersegment Operations | Storage and transportation revenues
Total revenue	0	0
Corporate Assets
Gross profit (excluding depreciation and amortization)	0	0
Identifiable assets	0	0
Goodwill	20.2	20.2
Property, plant and equipment	6.9	12.5
Expenditures for property, plant and equipment	0	0.1
Corporate Assets | Retail revenues
Total revenue	0	0
Corporate Assets | Marketing, supply and logistics revenues
Total revenue	0	0
Corporate Assets | Storage and transportation revenues
Total revenue	$ 0	$ 0

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Risk Management (Notional Amounts and Terms of Company's Derivative Financial Instruments) (Details)	Dec. 31, 2012 Btu	Sep. 30, 2012 bbl
Fixed Price Payor
Derivative [Line Items]
Propane, crude and heating oil (barrels)	13,600,000	7,800,000
Fixed Price Receiver
Derivative [Line Items]
Propane, crude and heating oil (barrels)	7,800,000	11,600,000

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Consolidated Statements of Comprehensive Income (USD $) In Millions, unless otherwise specified	3 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Net income (loss)	$ 2.8	$ (3.6)
Change in unrealized fair value on cash flow hedges (Note 2)	4.1	(2.6)
Derivative Instruments, Loss Recognized in Other Comprehensive Income (Loss), Effective Portion	(0.4)	0
Comprehensive income (loss)	$ 6.5	$ (6.2)

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Certain Balance Sheet Information

3 Months Ended

Dec. 31, 2012

Balance Sheet Related Disclosures [Abstract]

Certain Balance Sheet Information

Certain Balance Sheet Information

Inventories consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
NGLs	$	56.9	$	80.8
Parts, supplies and other	6.6		6.3
Total inventory	$	63.5	$	87.1

Property, plant and equipment consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Plant equipment	$	721.1	$	619.3
Buildings, land and storage rights	594.9		513.9
Pipelines	578.1		381.3
Vehicles	45.3		44.1
Construction in process	164.7		409.6
Base gas	134.1		134.0
Salt deposits	41.6		41.6
Office furniture and equipment	18.1		16.9
	2,297.9		2,160.7
Less: accumulated depreciation	484.7		450.2
Total property, plant and equipment, net	$	1,813.2	$	1,710.5

Intangible assets consisted of the following at December 31, 2012 and September 30, 2012, respectively (in millions):

	December 31, 2012		September 30, 2012
Customer accounts	$	194.4	$	41.2
Covenants not to compete	8.3		4.2
Deferred financing and other costs	27.9		17.1
	230.6		62.5
Less: accumulated amortization	23.7		21.2
Total intangible assets, net	$	206.9	$	41.3

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Partners' Capital (Tables)

3 Months Ended

Dec. 31, 2012

Partners' Capital Account, Distributions [Abstract]

Summary Of Quarterly Distributions Of Available Cash

A summary of the Company’s limited partner quarterly distribution for the three months endedDecember 31, 2012 and 2011, is presented below:

Three Months Ended December 31, 2012
Record Date	Payment Date	Per Unit Rate		Distribution Amount (in millions)
November 7, 2012	November 14, 2012	$	0.290	$	36.4
				$	36.4
Three Months Ended December 31, 2011
Record Date	Payment Date	Per Unit Rate		Distribution Amount (in millions)
November 7, 2011	November 14, 2011	$	0.705	$	83.9
				$	83.9

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Business Acquisitions (Assets Acquired, Liabilities Assumed) (Details) (USD $) In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 07, 2012	Sep. 30, 2012	Dec. 31, 2011
Business Combinations [Abstract]
Current assets		$ 3.3
Property, plant and equipment		100.9
Intangible assets		157.2
Total identifiable assets acquired		261.4
Current liabilities		2.9
Total liabilities assumed		2.9
Net identifiable assets acquired		258.5
Goodwill	330.8	165.0	165.8	501.2
Net assets acquired		$ 423.5

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Dec. 31, 2012

Text Block [Abstract]

Financial Instruments and Price Risk Management

Financial Instruments and Price Risk Management

Inergy utilizes certain derivative financial instruments to (i) manage its exposure to commodity price risk, specifically, the related change in the fair value of inventories, as well as the variability of cash flows related to forecasted transactions; (ii) ensure adequate physical supply of commodity will be available; and (iii) manage its exposure to interest rate risk associated with fixed and variable rate borrowings. Inergy records all derivative instruments on the balance sheet as either assets or liabilities measured at fair value. Changes in the fair value of these derivative financial instruments are recorded either through current earnings or as other comprehensive income, depending on the type of transaction.

Inergy is party to certain commodity derivative financial instruments that are designated as hedges of selected inventory positions, and qualify as fair value hedges. Inergy is also periodically party to certain interest rate swap agreements designed to manage interest rate risk exposure. Inergy’s overall objective for entering into fair value hedges is to manage its exposure to fluctuations in commodity prices and changes in the fair market value of its inventories and fixed and variable rate borrowings. The commodity derivatives are recorded at fair value on the balance sheets as price risk management assets or liabilities and the related change in fair value is recorded to earnings in the current period as cost of product sold. The interest rate derivatives are recorded at fair value on the balance sheets in other assets or liabilities and the related change in fair value is recorded to earnings in the current period as interest expense.

Any ineffective portion of the fair value hedges is recognized as cost of product sold in the current period. Inergy recognized net gains of $2.1 million and $1.0 million in the three months ended December 31, 2012 and 2011, respectively, related to the ineffective portion of its fair value hedging instruments. In addition, Inergy recognized no gain or loss for the three months endedDecember 31, 2012 and 2011, related to the portion of fair value hedging instruments that it excluded from its assessment of hedge effectiveness.

Inergy also enters into derivative financial instruments that qualify as cash flow hedges, which hedge the exposure of variability in expected future cash flows predominantly attributable to forecasted purchases to supply fixed price sale contracts and variable interest payments. These derivatives are recorded on the balance sheet at fair value as price risk management assets or liabilities. The effective portion of the gain or loss on these cash flow hedges is recorded in other comprehensive income in partner's capital and reclassified into earnings in the same period in which the hedge transaction affects earnings. In certain situations under the rules, the ineffective portion of the gain or loss is recognized as cost of product sold in the current period. Accumulated other comprehensive loss was $11.2 million and $14.9 million at December 31, 2012 and September 30, 2012, respectively. Included in accumulated other comprehensive loss at December 31, 2012 was a loss of $3.9 million attributable to commodity instruments, a loss of $6.9 million attributable to interest rate swaps, and a loss of $0.4 million attributable to SPH units. Approximately $3.6 million is expected to be reclassified to earnings from other comprehensive income over the next twelve months.

Inergy’s policy is to offset fair value amounts of derivative instruments and cash collateral paid or received with the same counterparty under a master netting arrangement.

The cash flow impact of derivative financial instruments is reflected as cash flows from operating activities in the consolidated statements of cash flows.

Revenue Recognition

Revenue Recognition

Sales of NGLs and salt are recognized at the time product is shipped or delivered to the customer depending on the sales terms. NGL processing and fractionation fees are recognized upon delivery of the product. Revenues from the COLT Hub are recognized when the contractual services are provided, such as loading of customer rail cars. Revenues from storage and transportation contracts are recognized during the period in which the storage and transportation services are provided, such as loading of customer rail cars.

Expense Classification

Expense Classification

Cost of product sold consists of tangible products sold including NGLs and salt, as well as certain direct costs incurred in providing storage and transportation services (period ended December 31, 2011 also includes costs of tangible product associated with retail propane sales). Operating and administrative expenses consist of all expenses incurred other than those described above in cost of product sold and depreciation and amortization. Certain operating and administrative expenses and depreciation and amortization are incurred in the distribution of the product sales and storage sales but are not included in cost of product sold. These amounts were $35.9 million and $54.1 million for the three months ended December 31, 2012 and 2011, respectively.

Use of Estimates

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the periods presented. Actual results could differ from those estimates.

Inventories

Inventories

Inventories for marketing, supply and logistics operations, which mainly consist of NGLs, are stated at the lower of cost or market and are computed using the average cost method. These inventories are designated under a fair value hedge program and are consequently marked to market. NGL inventories being hedged and carried at market value at December 31, 2012 and September 30, 2012, amount to $48.4 million and $73.2 million, respectively. Inventories for storage and transportation operations are stated at the lower of cost or market and are computed predominantly using the average cost method.

Shipping and Handling Costs

Shipping and Handling Costs

Shipping and handling costs are recorded as part of cost of product sold at the time product is shipped or delivered to the customer except as discussed in “Expense Classification.”

Property, Plant and Equipment

Property, Plant and Equipment

Property, plant and equipment are stated at historical cost less accumulated depreciation. Inergy capitalizes all construction-related direct labor and material costs as well as the cost of funds used during construction. Amounts capitalized for cost of funds used during construction amounted to $3.1 million and $3.4 million for the three months ended December 31, 2012 and 2011, respectively. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:

	Years
Land, buildings and improvements	15 – 70
Office furniture and equipment	3 – 7
Vehicles	3 – 10
Pipelines	15
Tanks and plant equipment	3 – 30
Base gas	10

Salt deposits are depleted on a unit of production method.

Identifiable Intangible Assets

Identifiable Intangible Assets

The Company has recorded certain identifiable intangible assets, including customer accounts, covenants not to compete and deferred financing costs. Customer accounts and covenants not to compete have arisen from acquisitions. Deferred financing costs represent financing costs incurred in obtaining financing and are being amortized over the term of the related debt. Additionally, an acquired intangible asset should be separately recognized if the benefit of the intangible asset is obtained through contractual or other legal rights, or if the intangible asset can be sold, transferred, licensed, rented or exchanged, regardless of the acquirer's intent to do so.

Certain intangible assets are amortized on a straight-line basis over their estimated economic lives, as follows:

	Years
Customer accounts	15 - 20
Covenants not to compete	2 - 10
Deferred financing costs	4 - 10

Goodwill

Goodwill

Goodwill is recognized for various acquisitions as the excess of the cost of the acquisitions over the fair value of the related net assets at the date of acquisition. Goodwill is subject to at least an annual assessment for impairment by applying a fair-value-based test.

Inergy completed its annual impairment test for each of its reporting units and determined that no impairment existed as of September 30, 2012. No indicators of impairment were identified requiring an interim impairment test during the three-month period ended December 31, 2012.

Income Taxes

Income Taxes

Inergy is a publicly-traded master limited partnership. Partnerships are generally not subject to federal income tax, although publicly-traded partnerships are treated as corporations for federal income tax purposes and therefore are subject to federal income tax, unless the partnership generates at least 90% of its gross income from qualifying sources. If the qualifying income requirement is satisfied, the publicly-traded partnership will be treated as a partnership for federal income tax purposes. Inergy Sales and Service, Inc. (“Services”), a subsidiary of Inergy, does not generate at least 90% of its gross income from qualifying sources, and as such, federal and state income taxes are provided on the taxable income of Services. The earnings of the Company and its limited liability subsidiaries are included in the Federal and state income tax returns of the individual members or partners. However, legislation in certain states allows for taxation of partnerships, and as such, certain state taxes for Inergy have been included in the accompanying financial statements as income taxes due to the nature of the tax in those particular states. In addition, Federal and state income taxes are provided on the earnings of the subsidiaries incorporated as taxable entities (IPCHA and Services). The Company is required to recognize deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements or tax returns. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial reporting and tax basis of assets and liabilities using expected rates in effect for the year in which differences are expected to reverse.

Net earnings for financial statement purposes may differ significantly from taxable income reportable to unitholders as a result of differences between the tax basis and the financial reporting basis of assets and liabilities and the taxable income allocation requirements under the partnership agreement.

Sales Tax

Sales Tax

Inergy accounts for the collection and remittance of sales tax on a net tax basis. As a result, these amounts are not reflected in the consolidated statements of operations.

Income Per Unit

Income Per Unit

Inergy calculates basic net income per limited partner unit by utilizing the two class method. Diluted net income per limited partner unit is computed by dividing net income by the weighted-average number of units outstanding and the effect of dilutive units granted under the Long Term Incentive Plan and the Class B units. All outstanding Class B units converted to common units during the quarter ended December 31, 2012. No Class B units were outstanding as of December 31, 2012.

Asset Retirement Obligations

Asset Retirement Obligations

An asset retirement obligation (ARO) is an estimated liability for the cost to retire a tangible asset. The fair value of certain AROs could not be made as settlement dates (or range of dates) associated with these assets were not estimable.

Accounting For Unit-Based Compensation

Accounting for Unit-Based Compensation

Inergy sponsors a Long Term Incentive Plan and all share-based payments to employees, including grants of employee stock options, are recognized in the consolidated statements of operations based on their fair values.

The amount of compensation expense recorded by the Company was $3.1 million and $3.1 million during the three months endedDecember 31, 2012 and 2011, respectively.

Segment Information

Segment Information

There are certain accounting requirements that establish standards for reporting information about operating segments, as well as related disclosures about products and services, geographic areas and major customers. Further, they define operating segments as components of an enterprise for which separate financial information is available that is evaluated regularly by the chief operating decision maker in deciding how to allocate resources and assess performance. In determining its operating segments, Inergy examined the way it organizes its business internally for making operating decisions and assessing business performance. See Note 10 for disclosures related to Inergy’s two operating and reporting segments.

Fair Value

Fair Value

Cash and cash equivalents, accounts receivable (net of allowance for doubtful accounts) and payables are carried at cost, which approximates fair value due to their liquid and short-term nature. As of December 31, 2012, the estimated fair value of Inergy's fixed-rate Senior Notes, based on available trading information, totaled $11.9 million compared with the aggregate principal amount at maturity of $11.5 million. As of December 31, 2012, the estimated fair value of Inergy Midstream's fixed-rate Senior Notes, based on available trading information, totaled $515.3 million compared with the aggregate principal amount at maturity of $500.0 million. The fair value of debt was determined based on market quotes from Bloomberg. This is considered a level 1 pricing source within the fair value hierarchy. At December 31, 2012, Inergy's credit agreement (“Credit Agreement”) consists of a $550 million revolving loan facility (“Revolving Loan Facility”). The carrying value at December 31, 2012, of amounts outstanding under the Credit Agreement of $332.1 million approximate fair value due primarily to the floating interest rate associated with the Credit Agreement.  At December 31, 2012, Inergy Midstream's $600 million revolving credit facility (“NRGM Credit Facility”) had amounts outstanding of $179.8 million, which approximated fair value due primarily to the floating interest rate associated with borrowings under the NRGM Credit Facility. See Note 7 for a discussion of the Company's debt.

Assets and liabilities from price risk management are carried at fair value as discussed in Note 6. At December 31, 2012, the estimated fair value of assets, on a net basis, from price risk management activities amounted to $30.8 million and liabilities, on a net basis, from price risk management amounted to $24.2 million.

Recently Issued Accounting Pronouncements

Recently Issued Accounting Pronouncements

On December 16, 2011, the Financial Accounting Standards Board issued ASU No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This ASU requires disclosures to provide information to help reconcile differences in the offsetting requirements under U.S. Generally Accepted Accounting Principles and International Financial Reporting Standards. The disclosure requirements of this ASU mandate that entities disclose both gross and net information about financial instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an enforceable master netting arrangement or similar agreement. ASU No. 2011-11 also requires disclosure of collateral received and posted in connection with master netting arrangements or similar arrangements. The scope of this ASU includes derivative contracts, repurchase agreements, and securities borrowing and lending arrangements. Entities are required to apply the amendments of ASU No. 2011-11 for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. All disclosures provided by those amendments are required to be provided retrospectively for all comparative periods presented. The Company is currently reviewing the effects of ASU No. 2011-11.