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Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2006

¨	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: 0-32453

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 x No ¨

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

Large accelerated filer x Accelerated filer ¨ Non-accelerated filer ¨

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

Act). Yes ¨ No x

The following units were outstanding at February 1, 2007:


Common Units		45,263,253
Special Units		769,941

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, 2006 (unaudited) and September 30, 2006		3

Unaudited Consolidated Statements of Operations for the Three Months Ended December 31, 2006 and 2005		5

Unaudited Consolidated Statement of Partners’ Capital for the Three Months Ended December 31, 2006		6

Unaudited Consolidated Statements of Cash Flows for the Three Months Ended December 31, 2006 and 2005		7

Unaudited Notes to Consolidated Financial Statements		9

Item 2 – Management’s Discussion and Analysis of Financial Condition and Results of Operations		20

Item 3 – Quantitative and Qualitative Disclosures About Market Risk		27

Item 4 – Controls and Procedures		29

Part II – Other Information

Item 1 – Legal Proceedings		30

Item 1A – Risk Factors		30

Item 2 – Unregistered Sales of Equity Securities and Use of Proceeds		30

Item 3 – Defaults Upon Senior Securities		30

Item 4 – Submission of Matters to a Vote of Security Holders		30

Item 5 – Other Information		30

Item 6 – Exhibits		30

Signature		31

PART I. FINANCIAL INFORMATION

Item 1.

Financial Statements of Inergy L.P.

INERGY L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in millions, except unit information)


	December 31, 2006		September 30, 2006
	*(unaudited)*
Assets
Current assets:
Cash	$	14.2	$	12.0
Accounts receivable, less allowance for doubtful accounts of $3.1 and $2.9 at December 31, 2006 and September 30, 2006, respectively		162.0		99.5
Inventories		88.5		108.1
Assets from price risk management activities		54.7		46.2
Prepaid expenses and other current assets		22.2		29.8

Total current assets		341.6		295.6

Property, plant and equipment		878.5		847.9
Less: accumulated depreciation		137.5		124.4

Property, plant and equipment, net		741.0		723.5

Intangible assets:
Customer accounts		226.5		226.0
Covenants not to compete		61.8		54.2
Trademarks		32.8		32.8
Deferred financing and other costs		23.2		23.3

		344.3		336.3
Less: accumulated amortization		59.5		52.8

Intangible assets, net		284.8		283.5

Goodwill		359.1		332.4

Other assets		4.2		4.0

Total assets	$	1,730.7	$	1,639.0

INERGY, L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (continued)

(in millions, except unit information)


	December 31, 2006		September 30, 2006
	*(unaudited)*
Liabilities and partners’ capital

Current liabilities:
Accounts payable	$	135.6	$	81.5
Accrued expenses		54.3		62.9
Customer deposits		78.2		98.0
Liabilities from price risk management activities		43.3		49.0
Current portion of long-term debt		16.8		16.9

Total current liabilities		328.2		308.3

Long-term debt, less current portion		714.4		642.8

Other long-term liabilities		10.9		11.8

Partners’ capital
Common unitholders (45,258,253 and 45,005,153 units issued and outstanding as of December 31, 2006 and September 30, 2006, respectively)		649.9		648.8
Special unitholders (769,941 units issued and outstanding as of December 31, 2006 and September 30, 2006)		25.0		25.0
Non-managing general partner and affiliate		2.3		2.3

Total partners’ capital		677.2		676.1

Total liabilities and partners’ capital	$	1,730.7	$	1,639.0

See accompanying notes to the consolidated financial statements.

INERGY, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in millions, except unit and per unit data)

(unaudited)


	Three Months Ended December 31,
	2006			2005
Revenue:
Propane	$	327.4		$	367.3
Other		80.3			83.0

		407.7			450.3
Cost of product sold (excluding depreciation and amortization as shown below)
Propane		230.7			285.2
Other		47.9			52.6

		278.6			337.8

Gross profit		129.1			112.5
Expenses:
Operating and administrative		65.6			68.8
Depreciation and amortization		20.5			19.7
Loss on disposal of assets		0.7			0.4

Operating income		42.3			23.6

Other income (expense):
Interest expense, net		(13.7	)		(13.2	)
Finance charge income		0.6			0.6
Other income		0.2			0.1

Income before income taxes		29.4			11.1
Provision for income taxes		—			0.4

Net income	$	29.4		$	10.7

Partners’ interest information:
Non-managing general partners’ and affiliate’s interest in net income:	$	6.1		$	3.9

Limited partners’ interest in net income:
Common unit interest	$	23.3		$	5.9
Senior subordinated interest		—			0.7
Junior subordinated interest		—			0.2

Total limited partners’ interest in net income:	$	23.3		$	6.8

Net income per limited partner unit:
Basic	$	0.52		$	0.17

Diluted	$	0.51		$	0.17

Weighted average common limited partners’ units outstanding (in thousands):
Basic
Common units		45,128			35,253

Senior subordinated units		—			3,822

Junior subordinated units		—			1,145

Diluted		45,343			40,712

See accompanying notes to the consolidated financial statements

INERGY, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL

(in millions)

(unaudited)


	Common Unit Capital			Non- Managing General Partner and Affiliate			Special Units Capital		Total Partners’ Capital
Balance at September 30, 2006	$	648.8		$	2.3		$	25.0	$	676.1
Net proceeds from common unit options exercised		2.5			—			—		2.5
Contribution from unit based compensation charges		0.1			—			—		0.1
Distributions		(25.1	)		(6.1	)		—		(31.2	)
Comprehensive income:
Net income		23.3			6.1			—		29.4
Unrealized gain on cash flow hedges, net of reclassification of realized losses on cash flow hedges into earnings of $(6.1) million		0.3			—			—		0.3

Comprehensive income										29.7

Balance at December 31, 2006	$	649.9		$	2.3		$	25.0	$	677.2

See accompanying notes to the consolidated financial statements.

INERGY, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

(unaudited)


	Three Months Ended December 31,
	2006			2005
Operating activities
Net income	$	29.4		$	10.7
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation		14.4			15.3
Amortization		6.1			4.4
Amortization of deferred financing costs		0.6			0.5
Unit-based compensation charges		0.1			0.1
Provision for doubtful accounts		—			0.9
Loss on disposal of assets		0.7			0.4
Net assets (liabilities) from price risk management activities		(13.9	)		(22.2	)
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable		(63.1	)		(106.2	)
Inventories		20.1			40.1
Prepaid expenses and other current assets		7.6			10.8
Other assets (liabilities)		(0.2	)		—
Accounts payable		53.3			53.6
Accrued expenses		(8.6	)		(0.4	)
Customer deposits		(19.8	)		(18.6	)

Net cash provided by (used in) operating activities		26.7			(10.6	)

Investing activities
Acquisitions, net of cash acquired		(45.0	)		(156.0	)
Purchases of property, plant and equipment		(22.1	)		(5.0	)
Deferred acquisition costs incurred		(0.2	)		(0.1	)
Proceeds from sale of assets		2.9			0.9

Net cash used in investing activities		(64.4	)		(160.2	)

INERGY, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (continued)

(in millions)

(unaudited)


	Three Months Ended December 31,
	2006			2005
Financing activities
Proceeds from the issuance of long-term debt	$	156.6		$	328.8
Principal payments on long-term debt		(88.0	)		(140.0	)
Distributions		(31.2	)		(25.1	)
Payments for deferred financing costs		—			(0.9	)
Net proceeds from issuance of common units		—			24.9
Net proceeds from unit options exercised		2.5			—

Net cash provided by financing activities		39.9			187.7


Net increase in cash		2.2			16.9
Cash at beginning of period		12.0			9.5

Cash at end of period	$	14.2		$	26.4

Supplemental disclosure of cash flow information
Cash paid during the period for interest	$	16.4		$	16.5

Supplemental schedule of noncash investing and financing activities
Additions to covenants not to compete through the issuance of noncompete obligations	$	2.7		$	4.3

Additions to property, plant and equipment through accounts payable and accrued expenses	$	3.4		$	0.3

Increase (decrease) in the fair value of long-term debt and related interest rate swap liability	$	0.4		$	(1.5	)

Acquisitions, net of cash acquired:
Current assets	$	0.1		$	30.4
Property, plant and equipment		14.0			116.3
Intangible assets		7.8			4.8
Goodwill		26.8			38.2
Other assets		—			0.7
Current liabilities		(1.0	)		(30.1	)
Non-compete liabilities		(2.7	)		(4.3	)

	$	45.0		$	156.0

See accompanying notes to the consolidated financial statements.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 1 – Organization and Basis of Presentation

Organization

The consolidated financial statements of Inergy, L.P. (“Inergy”, “The Partnership” or the “Company”) include the accounts of Inergy and its subsidiaries, including Inergy Propane, LLC (“Inergy Propane”), Inergy Midstream, LLC (collectively, the “Operating Companies”) and Inergy Finance Corp.

Inergy Partners, LLC (“Inergy Partners” or the “Non-Managing General Partner”), a subsidiary of Inergy Holdings, L.P. (“Holdings”), owns the Non-Managing General Partner interest in the Company. Inergy GP, LLC (“Inergy GP” or the “Managing General Partner”), a wholly owned subsidiary of Holdings, has sole responsibility for conducting the Company’s business and managing its operations. Holdings is a holding company whose principal business, through its subsidiaries, is its management of and ownership in the Company. Holdings also directly owns the incentive distribution rights with respect to Inergy, L.P.

Pursuant to a partnership agreement, Inergy GP or any of its affiliates is entitled to reimbursement for all direct and indirect expenses incurred or payments it makes on behalf of Inergy and all other necessary or appropriate expenses allocable to Inergy or otherwise reasonably incurred by Inergy GP in connection with operating the Company’s business. These costs, which totaled approximately $0.8 million and $1.8 million for the three months ended December 31, 2006 and 2005, respectively, include compensation, bonuses and benefits paid to officers and employees of Inergy GP and its affiliates.

As of December 31, 2006, Holdings owns an aggregate 9.3% interest in Inergy, L.P., inclusive of ownership of all of the non-managing general partner and the managing general partner. This ownership is comprised of an approximate 1.0% general partnership interest and an approximate 8.3% limited partnership interest.

Nature of Operations

Inergy is engaged primarily in the sale, distribution, storage, marketing, trading, processing and fractionation of propane, natural gas and other natural gas liquids. The retail propane market is seasonal because propane is used primarily for heating in residential and commercial buildings, as well as for agricultural purposes. Inergy’s operations are primarily concentrated in the Midwest, Northeast, and South regions of the United States.

Basis of Presentation

The financial information contained herein as of December 31, 2006 and for the three-month periods ended December 31, 2006 and 2005 is unaudited. The Company 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. The Company 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. The retail distribution business is largely seasonal due to propane’s primary use as a heating source in residential and commercial buildings. Accordingly, the results of operations for the three-month period ended December 31, 2006 are not indicative of the results of operations that may be expected for the entire fiscal year.

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, 2006.

Reclassifications

Certain prior period amounts have been reclassified to conform to the current period presentation. These reclassifications had no effect on net income.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 2 – 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. Inergy records all derivative instruments on the balance sheet as either assets or liabilities measured at fair value under the provisions of Statement of Financial Accounting Standards 133, “Accounting for Derivative Instruments and Hedging Activities” (“SFAS 133”), as amended. 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, as defined in SFAS 133. 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. These 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. Any ineffective portion of the fair value hedges is recognized as cost of product sold in the current period. During the three months ended December 31, 2006, Inergy recognized an immaterial net loss related to the ineffective portion of its fair value hedging instruments and a net gain of $1.2 million related to the portion of fair value hedging instruments that Inergy 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. 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. Any ineffective portion of the gain or loss is recognized as cost of product sold in the current period. Accumulated other comprehensive income (loss) was $(16.3) million and $0.3 million at December 31, 2006 and 2005, respectively.

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 propane and other liquids are recognized at the later of the time the product is shipped or delivered to the customer. Gas processing and fractionation fees are recognized upon delivery of the product. Revenue from the sale of propane appliances and equipment is recognized at the later of the time of sale or installation. Revenue from repairs and maintenance is recognized upon completion of the service. Revenue from storage contracts is recognized during the period in which storage services are provided.

Expense Classification

Cost of product sold consists of tangible products sold including all propane and other natural gas liquids sold and all propane related appliances sold. Operating and administrative expenses consist of all expenses incurred by Inergy other than those described above in cost of product sold and depreciation and amortization. Certain of Inergy’s operating and administrative expenses and depreciation and amortization are incurred in the distribution of the product sales but are not included in cost of product sold. These amounts were $21.6 million and $20.5 million for the three months ended December 31, 2006 and 2005, respectively.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

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 at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the year. Actual results could differ from those estimates.

Inventories

Inventories for retail operations, which mainly consist of propane gas and other liquids, are stated at the lower of cost or market and are computed using the average-cost method. Wholesale propane inventories are designated under a fair value hedge program and are consequently marked to market. All wholesale propane inventories being hedged and carried at market value at December 31, 2006 and September 30, 2006 amount to $42.3 million and $67.8 million, respectively. Inventories for midstream operations are stated at the lower of cost or market determined using the first-in-first-out 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 cost. Depreciation is computed by the straight-line method over the estimated useful lives of the assets, as follows:


		Years
Buildings and improvements		25-40
Office furniture and equipment		3–10
Vehicles		5–10
Tanks and plant equipment		5–30

Identifiable Intangible Assets

The Company has recorded certain identifiable intangible assets, including customer accounts, covenants not to compete, trademarks, deferred financing costs and deferred acquisition costs. Customer accounts, covenants not to compete, and trademarks have arisen from the various acquisitions by Inergy. Deferred financing costs represent financing costs incurred in obtaining financing and are amortized over the term of the related debt. Additionally, an acquired intangible asset is 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
Covenants not to compete		2–10
Deferred financing costs		1–10

Trademarks have been assigned an indefinite economic life and are not being amortized, but are subject to an annual impairment evaluation.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Income Per Unit

The Company calculates basic net income per unit by dividing net income, after considering the Non-Managing General Partner’s interest, including priority distributions, and the subordinated unitholder’s interest, by the weighted average number of limited partner units outstanding. Basic net income per unit is calculated for subordinated units by dividing the earnings allocated to each class of subordinated units by the weighted average number of units outstanding. Under this method, the calculation of net income per unit reflects an allocation of earnings to each class of units that is consistent with the partnership agreement’s treatment of the respective classes’ capital accounts. Diluted net income per limited partner unit is computed by dividing net income, after considering the Non-Managing General Partner’s interest, by the sum of (a) weighted average number of common units, (b) the additional common units that would be issued assuming the subordinated units were converted to common units, and (c) the effect of other dilutive units.

The following table presents the calculation of basic and diluted net income per limited partner unit (in millions, except unit and per unit data):


	Three Months Ended December 31,
	2006		2005
Numerator:
Net income	$	29.4	$	10.7

Less: Non-Managing General Partner’s interest in net income		6.1		3.9

Limited partners’ interest in net income – diluted	$	23.3	$	6.8
Less: Senior subordinated interest in net income		—		0.7
Less: Junior subordinated interest in net income		—		0.2

Common unit interest in net income – basic	$	23.3	$	5.9

Denominator (in thousands):
Weighted average common units outstanding – basic		45,128		35,253
Effect of converting senior subordinated units		—		3,822
Effect of converting junior subordinated units		—		1,145
Effect of dilutive units		215		492

Weighted average limited partners’ units outstanding – dilutive		45,343		40,712

Net income per limited partner unit:
Basic	$	0.52	$	0.17
Diluted	$	0.51	$	0.17

Net income per limited partner unit for the senior subordinated units and the junior subordinated units was the same as net income per common limited partner unit for the three months ended December 31, 2005.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Accounting for Unit-Based Compensation

Inergy has a unit-based employee compensation plan, which is accounted for under the provisions of Statement of Financial Accounting Standards (“SFAS”) No. 123(R), “Share-Based Payment” (“SFAS 123(R)”). SFAS 123(R) supersedes APB Opinion No. 25, “Accounting for Stock Issued to Employees” (“APB 25”), and amends SFAS No. 95, “Statement of Cash Flows.” SFAS 123(R) requires all share-based payments to employees, including grants of employee stock options, to be recognized in the income statement based on their fair values.

The Company adopted SFAS 123(R) on October 1, 2005 using the modified prospective method. Under the modified prospective method, compensation cost is recognized beginning with the effective date (a) for all share-based payments granted after the effective date and (b) for all awards granted to employees prior to effective date of SFAS 123(R) that remain unvested as of the effective date. Under this method, SFAS 123(R) applies to new awards and to awards modified, repurchased, or cancelled after the adoption date of October 1, 2005. The compensation cost for the portion of awards for which the requisite service has not been rendered that are outstanding as of October 1, 2005 will be recognized as the requisite service is rendered. The compensation cost for that portion of awards is based on the fair value of those awards as of the grant-date and was calculated for pro forma disclosures under SFAS 123. The compensation cost for those earlier awards is attributed to periods beginning on or after October 1, 2005 using the attribution method that was used under SFAS 123.

The amount of compensation expense recorded by the Company under the provisions of SFAS 123(R) during the three months ended December 31, 2006 was approximately $0.1 million, and includes unit-based compensation expense for options on Inergy Holdings, L.P. units issued to the Company’s employees.

Segment Information

SFAS No. 131, “Disclosures about Segments of an Enterprise and Related Information” (“SFAS 131”) establishes standards for reporting information about operating segments, as well as related disclosures about products and services, geographic areas, and major customers. Further, SFAS 131 defines 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 assessing performance. In determining reportable segments under the provisions of SFAS 131, Inergy examined the way it organizes its business internally for making operating decisions and assessing business performance. See Note 8 for disclosures related to Inergy’s propane and midstream segments.

Recently Issued Accounting Pronouncements

SFAS No. 157, “Fair Value Measurements” (“SFAS 157”) was issued in September 2006 to define fair value, establish a framework for measuring fair value according to generally accepted accounting principles, and expand disclosures about fair value measurements. SFAS 157 is required to be adopted by Inergy for the fiscal year ended September 30, 2008. The Company will be evaluating the potential financial statement impact of SFAS 157 to its consolidated financial statements.

SFAS No. 155, “Accounting for Certain Hybrid Financial Instruments” (“SFAS 155”) amends SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,” and SFAS No. 140, “Accounting for Transfers and Servicing of Financial Assets and Extinguishment of Liabilities.” SFAS 155 permits fair value remeasurement for any hybrid financial instrument that contains an embedded derivative that otherwise would require bifurcation. It also establishes a requirement to evaluate securitized financial assets to identify interests that are freestanding derivatives or that are hybrid financial instruments that contain an embedded derivative requiring bifurcation. For Inergy, SFAS 155 is effective for all financial instruments acquired or issued on or after October 1, 2006. The adoption of SFAS 155 has not had a material impact on the Company’s consolidated financial statements.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 3 – Certain Balance Sheet Information

Inventories consist of the following at December 31, 2006 and September 30, 2006, respectively (in millions):


	December 31, 2006		September 30, 2006
Propane gas and other liquids	$	76.1	$	96.1
Appliances, parts and supplies		12.4		12.0

	$	88.5	$	108.1

Property, plant and equipment consists of the following at December 31, 2006 and September 30, 2006, respectively (in millions):


	December 31, 2006		September 30, 2006
Tanks and plant equipment	$	588.8	$	578.4
Land and buildings		138.9		135.5
Vehicles		91.0		89.3
Construction in process		39.7		24.7
Office furniture and equipment		20.1		20.0

		878.5		847.9
Less: accumulated depreciation		137.5		124.4

Property, plant and equipment, net	$	741.0	$	723.5

At December 31, 2006 and September 30, 2006, the Company had capitalized interest of $1.0 million and $0.4 million, respectively, related to certain Midstream asset expansion projects. These amounts are reflected in construction in process.

Note 4 – Long-Term Debt

Long-term debt consisted of the following (in millions):


	December 31, 2006		September 30, 2006
Credit agreement	$	91.9	$	22.7
Senior unsecured notes		621.8		621.4
Obligations under noncompetition agreements and notes to former owners of businesses acquired		17.5		15.6

		731.2		659.7
Less current portion		16.8		16.9

	$	714.4	$	642.8

The Company’s credit agreement (the “Credit Agreement”) consists of a $75 million revolving working capital facility (the “Working Capital Facility”) and a $350 million revolving acquisition facility (the “Acquisition Facility”). On October 1, 2006, Inergy amended the Credit Agreement with existing lenders primarily to increase the effective amount of working capital borrowings available through the utilization of the Acquisition Facility from $75 million to $125 million. Other terms, conditions, and covenants remained materially unchanged. The Credit Agreement is guaranteed by each of Inergy’s domestic subsidiaries.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

At December 31, 2006 the balance outstanding under the Credit Agreement was $91.9 million, including $70.0 million under the Acquisition Facility and $21.9 million under the Working Capital Facility. At September 30, 2006, the balance outstanding under the Credit Agreement was $22.7 million, all under the Working Capital Facility. The interest rates of these revolvers are based on prime rate and LIBOR plus the applicable spreads, which were between 7.10% and 8.50% at December 31, 2006, and between 7.08% and 8.50% at September 30, 2006, for all outstanding debt under the Credit Agreement. Unused borrowings under the Credit Agreement amounted to $292.4 million and $369.4 million at December 31, 2006 and September 30, 2006, respectively. Outstanding standby letters of credit under the Credit Agreement amounted to $40.7 million and $32.9 million at December 31, 2006 and September 30, 2006, respectively.

Inergy is party to five interest rate swap agreements scheduled to mature in December 2014, each designed to hedge $25 million in underlying fixed rate senior unsecured notes in order to manage interest rate risk exposure. These swap agreements, which expire on the same date as the maturity date of the related senior unsecured notes due 2014 and contain call provisions consistent with the underlying senior unsecured notes, require the counterparty to pay the Company an amount based on the stated fixed interest rate due every six months. In exchange, Inergy is required to make semi-annual floating interest rate payments on the same dates to the counterparty based on an annual interest rate equal to the 6-month LIBOR interest rate plus spreads between 0.92% and 2.20% applied to the same notional amount of $125 million. The swap agreements have been recognized as fair value hedges. Amounts to be received or paid under the agreements are accrued and recognized over the life of the agreements as an adjustment to interest expense. At December 31, 2006, Inergy had recorded an approximate $3.2 million reduction in the fair market value of the related senior unsecured notes with a corresponding change in the fair value of its interest rate swaps, which are recorded in other long-term liabilities.

At December 31, 2006, the Company was in compliance with all of its debt covenants.

Note 5 – Business Acquisitions

During October 2006, Inergy closed the following three asset acquisitions: Bath Storage Facility, Columbus Butane Company, Inc., and Hometown Propane, Inc. In November 2006, Inergy acquired the propane assets of Mideastern Oil Company, Inc. Additionally, in December 2006, Inergy acquired the assets of the Jacksonville, Florida location of Sun Belt Energy of Florida, LLC and Stevens Gas Service, Inc. These six acquisitions increased Inergy’s market share and the aggregate purchase price, net of cash acquired was $44.3 million. The purchase price allocation for these acquisitions has been prepared on a preliminary basis pending final asset valuation and asset rationalization, and changes are expected when additional information becomes available.

As a result of the above acquisitions, the Company allocated $27.0 million to goodwill. In addition, the Company allocated $7.9 million to intangible assets, consisting primarily of customer accounts and non-compete agreements.

The operating results for these acquisitions are included in the consolidated results of operations from the dates of acquisition through December 31, 2006.

Note 6 – Partner’s Capital

Special Units

In August 2005, Inergy issued 769,941 special units (the “Special Units”), representing a new class of equity securities in Inergy that are not entitled to a current cash distribution and will convert into common units representing limited partnership interests in Inergy at a specified conversion rate upon the commercial operation of the Stagecoach expansion project. As of December 31, 2006, the Special Units were convertible into 892,573 common units.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Quarterly Distributions of Available Cash

On November 14, 2006, a quarterly distribution of $0.555 per limited partner unit was paid to unitholders of record on November 7, 2006 with respect to the fourth fiscal quarter of 2006, which totaled $31.2 million. On February 14, 2007, a quarterly distribution of $0.565 per limited partner unit will be paid to unitholders of record on February 7, 2007 for a total distribution of $32.1 million with respect to the first fiscal quarter of 2007.

On November 14, 2005, a quarterly distribution of $0.52 per limited partner unit was paid to unitholders of record on November 7, 2005 with respect to the fourth fiscal quarter of 2005, which totaled $25.1 million. Inergy distributed $0.53 per limited partner unit on February 14, 2006 to unitholders of record on February 7, 2006 for a total distribution of $25.9 million with respect to the first fiscal quarter of 2006.

Long-Term Incentive Plan

Inergy’s managing general partner sponsors the Long-Term Incentive Plan for its employees, consultants, and directors and the employees of its affiliates that perform services for Inergy. The long-term incentive plan currently permits the grant of awards covering an aggregate of 1,735,100 common units, which can be granted in the form of unit options and/or restricted units; however, not more than 565,600 restricted units may be granted under the plan.

Restricted Units

During the 2006 fiscal period, the compensation committee granted 58,756 restricted units. During the current fiscal period, the compensation committee granted an additional 20,500 restricted units. Of the 79,256 restricted units, 20,000 vest over a three year period beginning three years from the grant date, 3,756 vest over a three year period beginning one year from the grant date, while the remaining 55,500 restricted units cliff vest five years from the grant date. Some of these units are subject to the achievement of certain specified performance objectives and failure to meet the performance objectives will result in forfeiture and cancellation of the restricted units. The Company recognizes expense on these units each quarter using an estimate of the units expected to vest multiplied by the closing price of the Company’s common unit on the date of grant.

Of the total 79,256 restricted units outstanding, the weighted average remaining contract life is 9.6 years.

The compensation expense recorded by the Company related to these restricted unit awards was less than $0.1 million for the three months ended December 31, 2006.

Unit Options

Unit options issued under the long-term incentive plan have an exercise price equal to the fair market value of the units on the date of the grant. In general, unit options will expire after 10 years and are subject to the vesting provisions as outlined in the unit option agreement. In addition, most unit option grants made under the plan provide that the unit options will become exercisable upon a change of control of the managing general partner or Inergy.

A summary of Inergy’s unit option activity for the three months ended December 31, 2006 is as follows:


	Range of Exercise Prices		Weighted- Average Exercise Price		Number of Units
Outstanding at September 30, 2006	$	8.19 - $31.32	$	16.37	711,964
Granted		—		—	—
Exercised	$	10.00 - $27.14	$	11.11	(232,600	)
Canceled		—		—	—

Outstanding at December 31, 2006	$	8.19 - $31.32	$	18.92	479,364

Exercisable at December 31, 2006	$	8.19 - $13.75	$	11.07	31,864

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

The weighted-average remaining contract lives for outstanding options and for exercisable options at December 31, 2006 were approximately six years and four years, respectively. The fair value of each option grant was estimated as of the grant date using the Black-Scholes option pricing model using the assumptions outlined in the table below. Expected volatility was based on a combination of historical and implied volatilities of the Company’s units over a period at least as long as the options’ expected term. The expected life represents the period of time that the options granted are expected to be outstanding. The risk-free rate is based on the applicable U.S. Treasury yield curve in effect at the time of the grant of the unit options.


Weighted-average fair value of options granted	$	1.28
Expected volatility		0.234
Distribution yield		7.4	%
Expected life of option in years		5
Risk-free interest rate		3.5	%

The aggregate intrinsic values of outstanding options and of exercisable options at December 31, 2006 were $5.3 million and $0.6 million, respectively. The aggregate intrinsic value of unit options exercised during the three months ended December 31, 2006 was $4.0 million. There were no options exercised during the three months ended December 31, 2005. Aggregate intrinsic value represents the positive difference between the Company’s closing unit price on the last trading day of the fiscal period, which was $29.81 on December 29, 2006, and the exercise price multiplied by the number of options outstanding.

As of December 31, 2006, there was $4.1 million of total unrecognized compensation cost related to unvested unit-based compensation awards granted to employees under the restricted unit and unit option plans, including approximately $1.9 million related to Holdings unvested unit-based compensation awards. That cost is expected to be recognized over a five-year period.

Note 7 – Commitments and Contingencies

Inergy periodically enters into agreements with suppliers to purchase fixed quantities of propane, distillates, natural gas and liquids at fixed prices. At December 31, 2006, the total of these firm purchase commitments was approximately $272.7 million. The Company also enters into agreements with suppliers to purchase quantities of propane, distillates, natural gas and liquids at variable prices at future dates at the then prevailing market prices.

At December 31, 2006, Inergy was contingently liable for letters of credit outstanding totaling $40.7 million, which guarantees various transactions.

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.

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. At December 31, 2006 and September 30, 2006, Inergy’s self-insurance reserves were $13.8 million and $11.2 million, respectively.

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 8 – Segments

Inergy’s financial statements reflect two operating and reportable segments: propane operations and midstream operations. Inergy’s propane operations include propane sales to end users, the sale of propane-related appliances and service work for propane-related equipment, the sale of distillate products and wholesale distribution of propane and marketing and price risk management services to other users, retailers and resellers of propane. Inergy’s midstream operations include storage of natural gas for third parties, fractionation of natural gas liquids, processing of natural gas and the distribution of natural gas liquids. Results of operations for acquisitions that occurred during the three months ended December 31, 2006, excluding the Bath Storage Facility, are included in the propane segment. The results of operations for the Bath Storage Facility are included in the midstream segment.

The identifiable assets associated with each reportable segment include accounts receivable and inventories. Goodwill is also presented for each segment. The net asset/liability from price risk management, as reported in the accompanying consolidated balance sheets, is related to the propane segment.

Revenues, gross profit, identifiable assets and goodwill for each of Inergy’s reportable segments are presented below (in millions):


	Three Months Ended December 31, 2006
	Propane Operations		Midstream Operations		Intersegment Eliminations		Total
Retail propane revenues	$	219.2	$	—	$	—	$	219.2
Wholesale propane revenues		102.3		5.9		—		108.2
Storage, fractionation and other midstream revenues		—		35.4		—		35.4
Transportation revenues		2.4		—		—		2.4
Propane-related appliance sales revenues		7.6		—		—		7.6
Retail service revenues		5.3		—		—		5.3
Rental service and other revenues		5.9		—		—		5.9
Distillate revenues		23.7		—		—		23.7
Gross profit		116.1		13.0		—		129.1
Identifiable assets		236.5		14.0		—		250.5
Goodwill		261.4		97.7		—		359.1


	Three Months Ended December 31, 2005
	Propane Operations		Midstream Operations		Intersegment Eliminations		Total
Retail propane revenues	$	237.4	$	—	$	—	$	237.4
Wholesale propane revenues		124.7		5.2		—		129.9
Storage, fractionation and other midstream revenues		—		33.6		—		33.6
Transportation revenues		2.7		—		—		2.7
Propane-related appliance sales revenues		8.2		—		—		8.2
Retail service revenues		5.4		—		—		5.4
Rental service and other revenues		5.0		—		—		5.0
Distillate revenues		28.1		—		—		28.1
Gross profit		101.8		10.7		—		112.5
Identifiable assets		293.5		14.3		—		307.8
Goodwill		264.3		23.0		—		287.3

INERGY, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(unaudited)

Note 9 – Subsequent Events

Inergy has completed the acquisition of the 24-mile lateral pipeline connecting its Stagecoach natural gas storage facility to Tennessee Gas Pipeline Company's ("TGP") Line 300 ("Stagecoach Lateral"). The Stagecoach Lateral extends from Inergy's central compression facility in Tioga County, New York, to TGP's Station 319 in Bradford County, Pennsylvania. The facility was placed in service by TGP in January 2002, and it has a certificated capacity of 500 mmcf/day. The purchase price of the Stagecoach Lateral was approximately $35 million plus a customary working capital adjustment.

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, 2006.

The statements in this Quarterly Report on Form 10-Q that are not historical facts, including most importantly, those statements preceded by, or that include the words “may”, “believes”, “expects”, “anticipates” or the negation thereof, or similar expressions, constitute “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Such forward-looking statements include, but are not limited to, statements that: (i) we believe our wholesale supply, marketing and distribution business complements our retail distribution business, (ii) we expect recovery of goodwill through future cash flows associated with acquisitions, and (iii) we believe that anticipated cash from operations and borrowings under our credit facility will be sufficient to meet our liquidity needs for the foreseeable future. Such forward-looking statements involves risks, uncertainties and other factors which may cause the actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. Such factors include, but are not limited to, the following: weather in our area of operations; market price of propane; availability of financing; changes in, or failure to comply with, government regulations; the costs, uncertainties and other effects of legal and administrative proceedings and other risks and uncertainties detailed in our Securities and Exchange Commission filings. For those statements, we claim the protections of the safe harbor for forward-looking statements contained in the Reform Act. We will not undertake and specifically decline any obligation to publicly release the result of any revisions to any forward-looking statements to reflect events or circumstances after the date of such statements or to reflect events or circumstances after anticipated or unanticipated events.

Overview

We are a growing retail and wholesale propane supply, marketing and distribution business. We also own and operate a growing midstream operation, including a high performance, multicycle natural gas storage facility (“Stagecoach”) and a natural gas liquids (“NGL”) business in California, which includes natural gas processing, NGL fractionation, NGL rail and truck terminals, bulk storage, trucking and marketing operations. We have grown primarily through acquisitions of retail propane operations. Since the inception of our predecessor in November 1996 through December 31, 2006, we have acquired 65 companies, 62 propane companies and 3 midstream businesses, for an aggregate purchase price of approximately $1.4 billion, including working capital, assumed liabilities and acquisition costs. We further intend to pursue our growth objectives through, among other things, future acquisitions, maintaining a high percentage of retail sales to residential customers, operating in attractive markets and focusing our operations under established, and locally recognized trade names.

During October 2006, we closed the following three asset acquisitions: Bath Storage Facility, Columbus Butane Company, Inc., and Hometown Propane, Inc. In November 2006, we acquired the propane assets of Mideastern Oil Company, Inc. Additionally, in December 2006, we acquired the assets of the Jacksonville, Florida location of Sun Belt Energy of Florida, LLC and Stevens Gas Service, Inc. These six acquisitions increased our market share and the aggregate purchase price, net of cash acquired was $44.3 million. The purchase price allocation for these acquisitions has been prepared on a preliminary basis pending final asset valuation and asset rationalization, and changes are expected when additional information becomes available.

The retail propane distribution business is largely seasonal due to propane’s primary use as a heating source in residential and commercial buildings. As a result, cash flows from operations are generally highest from November through April when customers pay for propane purchased during the six-month peak heating season of October through March.

Because a substantial portion of our propane is used in the weather-sensitive residential markets, the temperatures realized in our areas of operations, particularly during the six-month peak heating season, have a significant effect on our financial performance. In any given area, warmer-than-normal temperatures will tend to result in reduced propane use, while sustained colder-than-normal temperatures will tend to result in greater propane use. Therefore, we use information on normal temperatures in understanding how historical results of operations are affected by temperatures that are colder or warmer than normal and in preparing forecasts of future

operations, which are based on the assumption that normal weather will prevail in each of our operating regions. “Heating degree days” are a general indicator of how weather impacts propane usage and are calculated for any given period by adding the difference between 65 degrees and the average temperature of each day in the period (if less than 65 degrees).

The retail propane business is a “margin-based” business where the level of profitability is largely dependent on the difference between sales prices and product costs. The unit cost of propane is subject to volatile changes as a result of product supply or other market conditions. Propane unit cost changes can occur rapidly over a short period of time and can impact margins as sales prices may not change as rapidly. There is no assurance that we will be able to fully pass on product cost increases, particularly when product costs increase rapidly. We have generally been successful in passing on higher propane costs to our customers and have historically maintained or increased our gross margin per gallon in periods of rising costs.

We believe our wholesale supply, marketing and distribution business complements our retail distribution business. Through our wholesale operations, we distribute propane and also offer price risk management services to propane retailers, resellers and other related businesses as well as energy marketers and dealers, through a variety of financial and other instruments, including:

•

forward contracts involving the physical delivery of propane;

•

swap agreements which require payments to (or receipt of payments from) counterparties based on the differential between a fixed and variable price for propane; and

•

options, futures contracts on the New York Mercantile Exchange and other contractual arrangements.

We engage in derivative transactions to reduce the effect of price volatility on our product costs 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 wholesale customers. However, we may experience net unbalanced positions from time to time.

Results of Operations

Three Months Ended December 31, 2006 Compared to Three Months Ended December 31, 2005

The following table summarizes the consolidated income statement components for the three months ending December 31, 2006 and 2005, respectively (in millions):


	Three Months Ended December 31,						Change
	2006			2005			In Dollars			Percentage
Revenue	$	407.7		$	450.3		$	(42.6	)	(9.5	)%
Cost of product sold		278.6			337.8			(59.2	)	(17.5	)

Gross profit		129.1			112.5			16.6		14.8
Operating and administrative expenses		65.6			68.8			(3.2	)	(4.7	)
Depreciation and amortization		20.5			19.7			0.8		4.1
Loss on disposal of assets		0.7			0.4			0.3		75.0

Operating income		42.3			23.6			18.7		79.2
Interest expense, net		(13.7	)		(13.2	)		(0.5	)	(3.8	)
Finance charge income		0.6			0.6			—		—
Other income		0.2			0.1			0.1		100.0

Income before income taxes		29.4			11.1			18.3		164.9
Provision for income taxes		—			0.4			(0.4	)	(100.0	)

Net income	$	29.4		$	10.7		$	18.7		174.8	%

The following table summarizes revenues, including associated volume of gallons sold, for the three months ending December 31, 2006 and 2005, respectively (in millions):


	Revenues									Gallons
	Three Months Ended December 31,				Change					Three Months Ended December 31,		Change
	2006		2005		In Dollars			Percentage		2006	2005	In Units		Percentage
Retail propane	$	219.2	$	237.4	$	(18.2	)	(7.7	)%	111.2	125.1	(13.9	)	(11.1	)%
Wholesale propane		108.2		129.9		(21.7	)	(16.7	)	108.8	127.5	(18.7	)	(14.7	)
Other retail		44.9		49.4		(4.5	)	(9.1	)	—	—	—		—
Storage, fractionation and midstream		35.4		33.6		1.8		5.4		—	—	—		—

Total	$	407.7	$	450.3	$	(42.6	)	(9.5	)%	220.0	252.6	(32.6	)	(12.9	)%

Volume. During the three months ended December 31, 2006, we sold 111.2 million retail gallons of propane, a decrease of 13.9 million gallons or 11.1% from the 125.1 million retail gallons sold during the same three-month period in 2005. The decrease was principally due to the warmer weather experienced in the 2006 period and, to a lesser extent, the sale of certain branches during fiscal 2006 and expected volume losses from recent acquisitions. Weather was approximately 11% warmer in our comparable areas of operation in the three months ended December 31, 2006 as compared to the same period in 2005 and approximately 7% warmer than normal. Offsetting the decrease in retail gallons sold was acquisition-related volume, which resulted in an increase of 7.5 million gallons in the quarter ended December 31, 2006.

Wholesale gallons delivered during the three months ended December 31, 2006 were 108.8 million gallons compared to 127.5 million gallons during the same three-month period in 2005. The decrease of 18.7 million gallons was primarily attributable to warmer weather during the 2006 period versus the comparable prior year period in our wholesale areas of operations.

The total natural gas liquid gallons sold by our West Coast operations decreased 1.2 million gallons, or 7.5%, to 14.9 million gallons during the three months ended December 31, 2006 from 16.1 million gallons during the same three-month period in 2005. This decrease was attributable to additional short-term sales contracts executed during the 2005 period with customers that had higher refinery demand, which triggered an increase in their product purchases at that time. Stagecoach has 13.25 bcf of working gas storage capacity which was 100% contracted during each of the three months ended December 31, 2006 and 2005.

Revenues. Revenues for the three months ended December 31, 2006 were $407.7 million, a decrease of $42.6 million, or 9.5%, from $450.3 million during the same three-month period in 2005.

Revenues from retail propane sales were $219.2 million for the three months ended December 31, 2006, a decrease of $18.2 million, or 7.7%, from $237.4 million from the same three-month period in 2005. This decrease was primarily the result of a $40.6 million decline due to lower retail volume sales at our existing locations (as discussed above) partially offset by an increase of $14.9 million due to acquisition-related sales together with an increase of approximately $7.5 million due to higher selling prices of propane.

Revenues from wholesale propane sales were $108.2 million for the three months ended December 31, 2006, a decrease of $21.7 million or 16.7%, from $129.9 million from the same three-month period in 2005. This decrease was primarily the result of a $19.1 million decline as a result of the lesser sales volume (as discussed above), together with a decrease of approximately $2.6 million due to lower wholesale selling prices.

Revenues from other retail sales, primarily service, appliance, transportation, and distillates, were $44.9 million for the three months ended December 31, 2006, a decrease of $4.5 million or 9.1% from $49.4 million during the same three-month period in 2005. This decrease was primarily the result of a $5.9 million decline due to lower volume sales of distillates caused primarily by warmer weather and customer conservation, partially offset by an increase of $1.4 million resulting from recent acquisitions.

Revenues from storage, fractionation and other midstream activities were $35.4 million for the three months ended December 31, 2006, an increase of $1.8 million or 5.4% from $33.6 million during the same three-month period in 2005. This increase resulted from higher storage revenues, including approximately $0.9 million due to the acquisition of the Bath Storage Facility partially offset by lower revenues in our West Coast NGL facility due to lower sales prices of natural gas liquids and lesser sales volumes of natural gas liquids as referenced in the volume section on the previous page.

Cost of Product Sold. Retail propane cost of product sold for the three months ended December 31, 2006 was $126.7 million compared to $159.6 million during the same three-month period in 2005. This $32.9 million, or 20.6%, decrease resulted from an approximate $24.5 million decline due to lower retail volume sales at our existing locations (as discussed above), an approximate $15.9 million decrease due to lesser non-cash charges from derivative contracts associated with retail propane fixed price sales contracts (as discussed below), and an approximate $1.3 million decrease attributable to a slight decline in the average cost of propane. These factors, which contributed to a decline in cost of product sold, were partially offset by an approximate $8.8 million increase due to acquisition-related volume. The $15.9 million lesser non-cash charges from derivative contracts associated with retail fixed price propane sales resulted from the adoption of a cash flow hedging policy during the fourth quarter of fiscal year 2006, which has the effect of matching the revenues and costs associated with product sales to the period in which the product is delivered to the customer. The Company recorded a $0.2 million non-cash charge during the three months ended December 31, 2006 as compared to a non-cash charge of $16.1 million recorded in the same three-month period in 2005.

Wholesale propane cost of product sold for the three months ended December 31, 2006 was $104.0 million, a decrease of $21.6 million or 17.2%, from $125.6 million during the same three-month period in 2005. Contributing to these lower costs was an approximate $18.5 million decline as a result of lower volumes sold by our wholesale propane operations (as discussed above), together with a $3.1 million decrease attributable to the lower average cost of propane.

Other retail cost of product sold was $25.3 million for the three months ended December 31, 2006, a decrease of $4.0 million or 13.7%, from $29.3 million during the same three-month period in 2005. This decrease was primarily the result of a $4.3 million decline due to lower volume sales of distillates (as discussed above), partially offset by a $0.3 million increase due to acquisition-related sales.

Fractionation, storage, and other midstream cost of product sold was $22.6 million for the three months ended December 31, 2006, a decrease of $0.7 million, or 3.0%, from $23.3 million during the same three-month period in 2005. This decrease was due primarily to lower price per gallon and lower volume of natural gas liquids sold to existing customers as discussed above.

Our retail cost of product sold consists primarily of tangible products sold including all propane, distillates and other natural gas liquids 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 and delivery vehicle costs, including fuel costs, repair and maintenance and lease expense. These costs approximated $17.5 million and $16.6 million for the three months ended December 31, 2006 and 2005, respectively. In addition, depreciation expense associated with the delivery vehicles is reported within depreciation and amortization expense and amounted to $4.1 million and $3.9 million for the three months ended December 31, 2006 and 2005, respectively. Since we include these costs in our operating and administrative expenses 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. Retail propane gross profit was $92.5 million for the three months ended December 31, 2006 compared to $77.8 million in the same three-month period in 2005. This $14.7 million, or 18.9%, increase was attributable to several factors, including an increase in margin per gallon, which accounted for approximately $8.8 million of this increase, as well as a $6.1 million increase related to higher retail gallons sold resulting from acquisitions. Also contributing to higher gross profit was the $15.9 million decrease in cost of product sold relating to the change in non-cash charges from derivative contracts associated with retail propane fixed price sales contracts (as discussed above). These factors, which contributed to a higher gross profit, were partially offset by an approximate $16.1 million reduction in retail propane gross profit at our existing locations as a result of lower volume sales as discussed above.

Wholesale propane gross profit decreased $0.1 million, or 2.3%, to $4.2 million for the three months ended December 31, 2006 compared to $4.3 million in the same three-month period in 2005, as a result of a $0.6 million decline due to lower volume sales, partially offset by a $0.5 million increase attributable to higher margins.

Other retail gross profit decreased $0.5 million, or 2.5%, to $19.6 million for the three months ended December 31, 2006 compared to $20.1 million in the same three-month period in 2005. This decrease was due primarily to a $1.6 million decline resulting from lesser distillate volume sales (as described above), partially offset by a $1.1 million increase due to higher appliance and service gross profit relating to acquisitions.

Fractionation, storage, and other midstream gross profit was $12.8 million for the three months ended December 31, 2006 compared to $10.3 million in the same three-month period in 2005. This $2.5 million, or 24.3%, increase was due primarily to increased storage revenues, together with a $0.9 million increase due to the acquisition of the Bath Storage Facility. The remaining $0.2 million increase is due to other increases in midstream activities.

Operating and Administrative Expenses. Operating and administrative expenses decreased to $65.6 million for the three months ended December 31, 2006 compared to $68.8 million in the same three-month period in 2005. This $3.2 million decrease was primarily attributable to a decrease in insurance costs, personnel expenses and other facility costs of $4.3 million, partially offset by increases in professional services costs and vehicle expenses of $1.1 million. The net decrease in operating expenses was partially the result of integration efficiencies realized in fiscal 2007 relating to prior year acquisitions together with less variable costs as a result of the lesser volumes sold.

Depreciation and Amortization. Depreciation and amortization increased to $20.5 million for the three months ended December 31, 2006 from $19.7 million during the same three-month period in 2005, with the change primarily a result of acquisitions.

Interest Expense. Interest expense increased to $13.7 million for the three months ended December 31, 2006 compared to $13.2 million during the same three-month period in 2005, primarily due to an increase in the average debt outstanding associated with acquisitions as well as higher average interest rates. During the three months ended December 31, 2006, we capitalized $0.6 million of interest related to certain capital improvement projects at our West Coast NGL and Stagecoach facilities as further described below in “Liquidity and Sources of Capital – Capital Resource Activities.”

Net Income. Net income was $29.4 million for the three months ended December 31, 2006 compared to net income of $10.7 million for the same three-month period in 2005. The $18.7 million increase in net income was primarily attributable higher gross profit in the 2006 period together with lower operating expenses.

EBITDA and Adjusted EBITDA. The following table summarizes EBITDA and Adjusted EBITDA for the three months ended December 31, 2006 and 2005, respectively (in millions):


	Three Months Ended December 31,
	2006		2005
EBITDA:
Net income	$	29.4	$	10.7
Interest expense, net		13.7		13.2
Provision for income taxes		—		0.4
Depreciation and amortization		20.5		19.7

EBITDA	$	63.6	$	44.0

Non-cash loss on derivative contracts		0.2		16.1
Long-term incentive and equity compensation expense		0.1		0.1
Loss on disposal of assets		0.7		0.4

Adjusted EBITDA	$	64.6	$	60.6

EBITDA is defined as income before taxes, plus net interest expense (inclusive of write-off of deferred financing costs) and depreciation and amortization expense. For the three months ended December 31, 2006 and 2005, EBITDA was $63.6 million and $44.0 million, respectively. This $19.6 million improvement in EBITDA was primarily attributable to higher gross profit and the decrease in cash operating expenses in 2006. As indicated in the table, Adjusted EBITDA represents EBITDA excluding the gain or loss on derivative contracts associated with retail fixed price propane sales, the gain or loss on the disposal of assets and long-term incentive and equity compensation expenses (including conversion bonuses). Adjusted EBITDA was $64.6 million for three months ended December 31, 2006 compared to $60.6 million in the same three-month period in 2005. 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 and Adjusted EBITDA provide additional information for evaluating our ability to make the minimum quarterly distribution and are presented solely as supplemental measures. 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.

Seasonality

The retail market for propane is seasonal because it is used primarily for heating in residential and commercial buildings. Approximately three-quarters of our retail propane volume is sold during the peak heating season from October through March. Consequently, sales and operating profits are generated mostly in the first and fourth calendar quarters of each year.

Liquidity and Sources of Capital

Capital Resource Activities

We have identified growth projects related to our Stagecoach and West Coast NGL midstream assets that are expected to require a capital investment of approximately $257 million to complete. Through December 31, 2006, we have invested approximately $35 million toward completion of these projects. These projects include expansion of our Stagecoach natural gas storage facility, which is expected to increase our working storage capacity of natural gas to approximately 26.35 bcf through the addition of approximately 13.1 bcf of storage to our existing 13.25 bcf working storage capacity. All necessary regulatory approvals have been received and construction of the expansion is underway. The expanded facilities are expected to be in service by the fall of 2007. Stagecoach is also expected to construct a pipeline interconnect with the proposed Millennium Pipeline which will enhance and further diversify our supply sources and provide interruptible wheeling services to the shipper community. In addition, we presently have an agreement with a customer of Stagecoach whereby that customer provides certain asset management services through utilization of its firm storage capacity and related firm transportation on Tennessee Gas Pipeline. The agreement expires in June 2007 at which time we will either renegotiate this agreement, execute a similar agreement with a different customer or internalize these asset management services within Stagecoach with an additional investment of approximately $26 million. However, we are presently in negotiations with another customer and expect to execute a new asset management services agreement prior to June 2007. The West Coast project consists of the construction of a butane isomerization unit and related ancillary facilities, as well as the expansion of butane storage capacity. The isomerization unit is projected to have a capacity of 10,000 barrels per day and provide isobutane supplies to refiners or wholesale distributors for gasoline blending. This project is subject to regulatory approval by state and county agencies and is expected to be in service by July 2008.

Cash Flows and Contractual Obligations

Net operating cash inflows (outflows) were $26.7 million and $(10.6) million for the three-month periods ending December 31, 2006 and 2005, respectively. The $37.3 million increase in operating cash flows was primarily attributable to higher operating income and net changes in working capital balances.

Net investing cash outflows were $64.4 million and $160.2 million for the three -month periods ending December 31, 2006 and 2005, respectively. Net cash outflows were primarily impacted by a $111.0 million decrease in cash outlays related to acquisitions, a $17.1 million increase in capital expenditures and a $2.0 million increase in proceeds received from the sale of property, plant and equipment.

Net financing cash inflows were $39.9 million and $187.7 million for the three-month periods ending December 31, 2006 and 2005, respectively. Net cash inflows were primarily impacted by a $120.2 million decrease in proceeds from the issuance of long-term debt, net of payments on long-term debt, a $24.9 million decrease in proceeds from the issuance of common units and a $6.1 million increase in distributions paid.

The following table summarizes our contractual obligations as of December 31, 2006 (in millions):


	Total		Less than 1 year		1-3 years		4-5 years		After 5 years
Aggregate amount of principal and interest to be paid on the outstanding long-term debt ^(a)	$	1,150.7	$	71.0	$	112.6	$	182.2	$	784.9
Amount of principal and interest to be paid on other long-term obligations		10.8		2.6		8.2		—		—
Future minimum lease payments under noncancelable operating leases		21.4		6.3		8.6		3.4		3.1
Fixed price purchase commitments		272.0		271.4		0.6		—		—
Standby letters of credit		40.7		37.3		3.2		0.2		—

^(a)

$216.9 million of our long-term debt, including interest rate swaps, is variable interest rate debt at prime rate or LIBOR plus an applicable spread. These rates plus their applicable spreads were between 7.10% and 8.50% at December 31, 2006. These rates have been applied for each period presented in the table.

In addition to our fixed price purchase commitments, we also have forward purchase energy contracts. As of December 31, 2006, total energy contracts had an outstanding net fair value of $11.4 million, as compared to a net fair value of $25.8 million as of December 31, 2005. This $14.4 million decrease includes a net decrease in fair value of $8.1 million from energy contracts settled and a net increase of $10.1 million from other changes in fair value related to net unrealized losses on energy contracts still outstanding. Of the outstanding fair value as of December 31, 2006, all energy contracts mature within fifteen months.

We believe that anticipated cash from operations and borrowing capacity under our Credit Agreement described below 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.

Description of Credit Facility

We maintain borrowing capacity under a credit facility (“Credit Agreement”), which consists of a $75 million revolving working capital facility (“Working Capital Facility”) and a $350 million revolving acquisition facility (“Acquisition Facility”). The Credit Agreement accrues interest at either prime rate or LIBOR plus applicable spreads, resulting in interest rates between 7.10% and 8.50% at December 31, 2006. At December 31, 2006, borrowings outstanding under the Credit Agreement were $91.9 million, including $70.0 million under the Acquisition Facility and $21.9 million under the Working Capital Facility. On October 1, 2006, Inergy amended the Credit Agreement with existing lenders primarily to increase the effective amount of working capital borrowings available through the utilization of the Acquisition Facility from $75 million to $125 million. Other terms, conditions, and covenants remained materially unchanged. The Credit Agreement is guaranteed by each of Inergy’s domestic subsidiaries.

During each fiscal year beginning October 1, the outstanding balance of the Working Capital Facility must be reduced to $10.0 million or less for a minimum of 30 consecutive days during the period commencing March 1 and ending September 30 of each calendar year.

At our option, loans under the Credit Agreement bear interest at either the prime rate or LIBOR (preadjusted for reserves), plus, in each case, an applicable margin. The applicable margin varies quarterly based on its leverage ratio. We also pay a fee based on the average daily unused commitments under the Credit Agreement.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

We have long-term debt and a revolving line of credit subject to the risk of loss associated with movements in interest rates. At December 31, 2006, we had floating rate obligations totaling approximately $216.9 million including amounts borrowed under our Credit Agreement and interest rate swaps, which convert fixed rate debt associated with the same amount of principal of our senior unsecured notes due 2014 to floating rate debt, with aggregate notional amounts of $125 million. The floating rate obligations expose us 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 2006 levels, our interest expense would change by a total of approximately $2.2 million per year.

Commodity Price, Market and Credit Risk

Inherent in our contractual portfolio 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, 2006 and 2005 were propane retailers, resellers, energy marketers and dealers.

The propane industry is a “margin-based” business in which gross profits depend on the excess of sales prices over supply costs. As a result, our profitability will be sensitive to changes in wholesale prices of propane caused by changes in supply or other market conditions. When there are sudden and sharp increases in the wholesale cost of propane, we may not be able to pass on these increases to our customers through retail or wholesale prices. Propane is a commodity and the price we pay for it can fluctuate significantly in response to supply or other market conditions. We have no control over supply or market conditions. In addition, the timing of cost pass-throughs can significantly affect margins. Sudden and extended wholesale price increases could reduce our gross profits and could, if continued over an extended period of time, reduce demand by encouraging our retail customers to conserve or convert to alternative energy sources. 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 wholesale 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.

Notional Amounts and Terms

The notional amounts and terms of our derivative financial instruments include the following at December 31, 2006 and September 30, 2006 (in millions):


	December 31, 2006		September 30, 2006
	Fixed Price Payor	Fixed Price Receiver	Fixed Price Payor	Fixed Price Receiver
Propane and heating oil (barrels)	5.6	5.5	8.0	7.5
Natural gas (MMBTU’s)	5.6	5.6	5.5	5.4

Notional amounts reflect the volume of transactions, but do not accurately measure our exposure to market or credit risks.

Fair Value

The fair value of the derivatives and inventory exchange contracts related to price risk management activities as of December 31, 2006 and September 30, 2006 was assets of $54.7 million and $46.2 million, respectively, and liabilities of $43.3 million and $49.0 million, respectively. All intercompany transactions have been appropriately eliminated.

The following table summarizes the change in the unrealized fair value of energy derivative contracts related to risk management activities for the three months ended December 31, 2006 and 2005 where settlement has not yet occurred (in millions):


	Three Months Ended December 31,
	2006			2005
Net fair value gain (loss) of contracts outstanding at beginning of period	$	(2.8	)	$	8.8
Net change in physical exchange contracts		12.2			23.0
Change in fair value of contracts attributable to market movement during the period		10.1			(4.0	)
Realized gains		(8.1	)		(2.0	)

Net fair value of contracts outstanding at end of period	$	11.4		$	25.8

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 which 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.

Of the outstanding fair value as of December 31, 2006, all contracts had a maturity of fifteen months or less.

Sensitivity Analysis

A theoretical change of 10% in the underlying commodity value would result in a change of approximately $0.1 million in the market value of the contracts as there were approximately 0.7 million gallons of net unbalanced positions at December 31, 2006.

Item 4.

Controls and Procedures

We maintain controls and procedures designed to ensure 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 adequate and effective as of December 31, 2006. There have been no changes in our internal controls over financial reporting (as defined in Rule 13(e)-15 or Rule 15d-15(f) of the Exchange Act) or in other factors during the fiscal year covered by this report that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

PART II – OTHER INFORMATION

Item 1.

Legal Proceedings

Part I, Item 1. Financial Statements, Note 7 to the Consolidated Financial Statements, of this Form 10Q is hereby incorporated herein by reference.

Item 1A.

Risk Factors

There have been no material changes to the risk factors as previously disclosed in Item 1A. of the Company’s Annual Report on Form 10-K for the year ended September 30, 2006.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3.

Defaults Upon Senior Securities

None.

Item 4.

Submission of Matters to a Vote of Security Holders

None.

Item 5.

Other Information

None.

Item 6.

Exhibits


		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.

SIGNATURE

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


	INERGY, L.P.

	By:	INERGY GP, LLC
		(its managing general partner)

Date: February 7, 2007	By:	/s/ R. Brooks Sherman, Jr.
		R. Brooks Sherman, Jr.
		Senior Vice President and Chief Financial Officer
		(Principal Financial Officer and Principal Accounting Officer)

Section 302 CEO Certification

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:

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;

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;

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

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):

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

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 7, 2007

/s/ John J. Sherman

John J. Sherman

President and Chief Executive Officer

Section 302 CFO Certification

Exhibit 31.2

CERTIFICATIONS

I, R. Brooks Sherman, Jr., certify that:

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

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 7, 2007

/s/ R. Brooks Sherman, Jr.

R. Brooks Sherman, Jr.

Senior Vice President and Chief Financial Officer

Section 906 CEO Certification

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, 2006 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 7, 2007

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.

Section 906 CFO Certification

Exhibit 32.2

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, 2006 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, R. Brooks Sherman, Jr., 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/ R. Brooks Sherman, Jr.

R. Brooks Sherman, Jr.

Chief Financial Officer

February 7, 2007

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