UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

________________

Form 10-Q

(Mark One)

R	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended March 31, 2010
	For the quarterly period ended June 30, 2010
	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 1-4101

________________

Tennessee Gas Pipeline Company

(Exact Name of Registrant as Specified in Its Charter)

Delaware	74-1056569
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

El Paso Building
1001 Louisiana Street Houston, Texas	77002
(Address of Principal Executive Offices)	(Zip Code)

Telephone Number: (713) 420-2600

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 þ No o

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

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

	Large accelerated filer o	Accelerated filer o		Non-accelerated filer þ	Small reporting company o
			(Do not check if a 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 o No þ

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

Common stock, par value $5 per share. Shares outstanding on ~~May~~August 76, 2010: 208

TENNESSEE GAS PIPELINE COMPANY MEETS THE CONDITIONS OF GENERAL INSTRUCTION H(1)(a) AND (b) TO FORM 10-Q AND IS THEREFORE FILING THIS REPORT WITH A REDUCED DISCLOSURE FORMAT AS PERMITTED BY SUCH INSTRUCTION.

TENNESSEE GAS PIPELINE COMPANY

TABLE OF CONTENTS

	Caption	Page
	PART I — Financial Information
Item 1.	Financial Statements	1
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	9
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	*
Item 4.	Controls and Procedures	1314
	PART II — Other Information
Item 1.	Legal Proceedings	1415
Item 1A.	Risk Factors	1415
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	*
Item 3.	Defaults Upon Senior Securities	*
Item 4.	(Removed and Reserved)	1415
Item 5.	Other Information	1415
Item 6.	Exhibits	1516
	Signatures	1617

____________

* We have not included a response to this item in this document since no response is required pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.

Below is a list of terms that are common to our industry and used throughout this document:

	/d	=	per day	BBtu	=	billion British thermal units
	MMcf	=	million cubic feet

When we refer to cubic feet measurements, all measurements are at a pressure of 14.73 pounds per square inch.

When we refer to “us,” “we,” “our,” “ours,” or “~~ours~~the company,” we are describing Tennessee Gas Pipeline Company and/or our subsidiaries.

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PART I — FINANCIAL INFORMATION

Item 1. Financial Statements

TENNESSEE GAS PIPELINE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In millions)

(Unaudited)

	Quarter Ended March 31,
	Quarter Ended June 30,						Six Months Ended June 30,
	2010			2009			2010			2009
Operating revenues	$	~~224~~200		$	~~266~~217		$	424		$	483
Operating expenses
Operation and maintenance		7381			9087			154			177
Depreciation and amortization		4847			4647			95			93
Taxes, other than income taxes		1413			1613			27			29
		135			152
		141			147			276			299
Operating income		8959			~~114~~70			148			184
Earnings from unconsolidated affiliate		43			32			7			5
Other income, net		54			34			9			7
Interest and debt expense		(3837	)		(3839	)		(75	)		(77	)
Affiliated interest income, net		34			4			7			8
Income before income taxes		6333			8641			96			127
Income taxes		2413			3316			37			49
Net income	$	3920		$	5325		$	59		$	78

See accompanying notes.

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TENNESSEE GAS PIPELINE COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(In millions, except share amounts)

(Unaudited)

	March 31, 2010			December 31, 2009
	June 30, 2010			December 31, 2009
ASSETS
Current assets
Cash and cash equivalents	$	1—		$	—
Accounts and notes receivable
Customer		14—			12
Affiliates		~~103~~182			152
Other		5345			13
Materials and supplies		42			43
Deferred income taxes		47			44
Other		7			8
Total current assets		~~267~~323			272
Property, plant and equipment, at cost		4,~~731~~843			4,680
Less accumulated depreciation and amortization		~~962~~1,011			936
		3,769			3,744
		3,832			3,744
Additional acquisition cost assigned to utility plant, net		1,~~952~~943			1,963
Total property, plant and equipment, net		5,~~721~~775			5,707
Other assets
Notes receivable from affiliates		~~949~~878			939
Investment in unconsolidated affiliate		8079			79
Other		6771			70
		1,096			1,088
		1,028			1,088
Total assets	$	7,~~084~~126		$	7,067
LIABILITIES AND STOCKHOLDER’S EQUITY
Current liabilities
Accounts payable
Trade	$	3050		$	60
Affiliates		6159			72
Other		4041			47
Taxes payable		9094			94
Contractual deposits		3334			31
Asset retirement obligations		6160			66
Accrued interest		4733			33
Regulatory liabilities		4758			28
Other		1916			24
Total current liabilities		~~428~~445			455
Long-term debt		1,~~847~~848			1,846
Other liabilities
Deferred income taxes		1,~~365~~388			1,351
Regulatory liabilities		~~144~~128			153
Other		6360			64
		1,572			1,568
		1,576			1,568
Commitments and contingencies (Note 3)
Stockholder’s equity
Common stock, par value $5 per share; 300 shares authorized; 208 shares issued and outstanding		—			—
Additional paid-in capital		2,209			2,209
Retained earnings		1,~~362~~382			1,323
Note receivable from affiliate		(334	)		(334	)
Total stockholder’s equity		3,~~237~~257			3,198
Total liabilities and stockholder’s equity	$	7,~~084~~126		$	7,067

See accompanying notes.

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TENNESSEE GAS PIPELINE COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

(Unaudited)

	Quarter Ended March 31,
	Six Months Ended June 30,
	2010			2009
Cash flows from operating activities
Net income	$	3959		$	5378
Adjustments to reconcile net income to net cash from operating activities
Depreciation and amortization		4895			4693
Deferred income taxes		1134			69
Earnings from unconsolidated affiliate, adjusted for cash distributions		(1—	)		12
Other non-cash income items		(13	)		(1	)
Asset and liability changes		(3570	)		2644
Net cash provided by operating activities		61115			~~131~~225
Cash flows from investing activities
Additions to property, plant and equipment		(57	)		(67	)
Capital expenditures		(101	)		(127	)
Net change in notes receivable from affiliates		(619	)		(~~117~~195	)
Other		35			189
Net cash used in investing activities		(60115	)		(~~166~~313	)
Cash flows from financing activities
Net proceeds from the issuance of long-term debt		—			~~235~~234
Net cash provided by financing activities		—			~~235~~234
Net change in cash and cash equivalents		1—			~~200~~146
Cash and cash equivalents
Beginning of period		—			—
End of period	$	1—		$	~~200~~146

See accompanying notes.

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TENNESSEE GAS PIPELINE COMPANY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Basis of Presentation and Significant Accounting Policies

Basis of Presentation

We are an indirect wholly owned subsidiary of El Paso Corporation (El Paso). We prepared this Quarterly Report on Form 10-Q under the rules and regulations of the United States Securities and Exchange Commission. Because this is an interim period filing presented using a condensed format, it does not include all of the disclosures required by U.S. generally accepted accounting principles. You should read this report along with our 2009 Annual Report on Form 10-K, which contains a summary of our significant accounting policies and other disclosures. The financial statements as of ~~March~~June 3130, 2010, and for the quarters and six months ended ~~March~~June 3130, 2010 and 2009, are unaudited. We derived the condensed consolidated balance sheet as of December 31, 2009, from the audited balance sheet filed in our 2009 Annual Report on Form 10-K. In our opinion, we have made adjustments, all of which are of a normal, recurring nature to fairly present our interim period results. Due to the seasonal nature of our business, information for interim periods may not be indicative of our operating results for the entire year.

Significant Accounting Policies

The following is an update of our significant accounting policies and accounting pronouncements issued but not yet adopted as discussed in our 2009 Annual Report on Form 10-K.

Transfers of Financial Assets. On January 1, 2010, we adopted an accounting ~~standard~~standards ~~updates~~update for financial asset transfers. Among other items, ~~these~~this ~~updates~~update ~~require~~requires the sale of an entire financial asset or a proportionate interest in a financial asset in order to qualify for sale accounting. These changes were effective for sales of financial assets occurring on or after January 1, 2010. In January 2010, we terminated our prior accounts receivable sales program under which we previously sold a senior interest in certain accounts receivable to a third party financial institution (through a wholly-owned special purpose entity). As a result, the adoption of ~~these~~this accounting ~~standard~~standards ~~updates~~update did not have a material impact on our financial statements. Upon termination of the prior accounts receivable sales program, we entered into a new accounts receivable sales program under which we sell certain accounts receivable in their entirety to the third party financial institution (through a wholly-owned special purpose entity). The transfer of these receivables qualifies for sale accounting under the provisions of ~~these~~this accounting ~~standard~~standards ~~updates~~update. We present the cash flows related to the prior and new accounts receivable sales programs as operating cash flows in our statements of cash flows. For further information, see Note 4.

Variable Interest Entities. On January 1, 2010, we adopted an accounting ~~standard~~standards ~~updates~~update for variable interest entities that ~~revise~~revises how companies determine the primary beneficiary of these entities, among other changes. Companies are now required to use a qualitative approach based on their responsibilities and power over the entities’ operations, rather than a quantitative approach in determining the primary beneficiary as previously required. The adoption of ~~these~~this accounting ~~standard~~standards ~~updates~~update did not have a material impact on our financial statements.

2. Fair Value of Financial Instruments

At ~~March~~June 3130, 2010 and December 31, 2009, the carrying amounts of cash and cash equivalents and ~~trade~~accounts ~~receivables~~receivable and ~~payables~~payable are representative of their fair value because of the short-term nature of these instruments. At ~~March~~June 3130, 2010 and December 31, 2009, we had an interest bearing note receivable from El Paso of approximately $1.0 billion due upon demand, with a variable interest rate of 1.56% inand ~~each period~~1.5%. While we are exposed to changes in interest income based on changes to the variable interest rate, the fair value of this note receivable approximates its carrying value due to the note being due on demand and the market-based nature of the interest rate.

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In addition, the carrying amounts of our long-term debt and their estimated fair values, which are based on quoted market prices for the same or similar issues, are as follows:

March 31, 2010

December 31, 2009

June 30, 2010

December 31, 2009

Carrying Amount

~~Carrying Amount~~

Fair Value

~~Fair Value~~

Carrying Amount

~~Carrying Amount~~

Fair Value

~~Fair Value~~

(In millions)

~~(In millions)~~

Long-term debt

$1,848

~~1,847~~

2,075

~~2,066~~

1,846

~~1,846~~

2,086

~~2,086~~

3. Commitments and Contingencies

Legal Proceedings

~~Gas~~We ~~Measurement~~and ~~Class~~our ~~Action.~~affiliates Inare ~~1999,~~named adefendants ~~purported~~in ~~class~~numerous ~~action~~lawsuits ~~lawsuit~~and ~~entitled~~governmental ~~Will~~proceedings ~~Price,~~and etclaims ~~al.~~that v.arise ~~Gas~~in ~~Pipelines~~the ~~and~~ordinary ~~Their~~course ~~Predecessors,~~of etour albusiness. For each of these matters, ~~was~~we ~~filed~~evaluate inthe merits of the ~~District~~case ~~Court~~or ofclaim, ~~Stevens~~our ~~County~~exposure to the matter, ~~Kansas~~possible ~~against~~legal usor settlement strategies and athe ~~number~~likelihood of ~~our~~an ~~affiliates~~unfavorable outcome. ~~The~~ ~~complaint~~If ~~alleges~~we determine that ~~the~~an ~~defendants~~unfavorable ~~inaccurately~~outcome ~~measured~~is ~~the~~probable ~~volume~~ and ~~heating~~can ~~content~~be ofestimated, ~~gas~~we ~~that~~establish ~~resulted~~the innecessary accruals. While the ~~underpayment~~outcome of ~~royalties~~these tomatters ~~royalty~~cannot ~~owners~~be onpredicted ~~non-federal~~with certainty, and ~~non-Native~~there ~~American~~are ~~lands~~still inuncertainties ~~Kansas,~~related ~~Wyoming~~to ~~and~~the ~~Colorado.~~costs ~~The~~we ~~court~~may ~~has~~incur, ~~denied~~based ~~motions~~upon ~~for~~our ~~class~~evaluation ~~certification~~and experience to date, ~~and~~we ~~the~~had ~~deadline~~no accrual for anour ~~appeal~~outstanding oflegal ~~this~~matters ~~order~~at ~~has~~June ~~now~~30, ~~passed~~2010. ~~Our~~It ~~costs~~is ~~and~~possible, ~~legal~~however, that new information or future developments could require us to reassess our potential exposure related to ~~this~~these ~~lawsuit~~matters and ~~claim~~establish ~~are~~accruals ~~not currently determinable~~accordingly.

In addition to the above proceeding, we and our subsidiaries and affiliates are named defendants in numerous lawsuits and governmental proceedings and claims that arise in the ordinary course of our business. For each of these matters, we evaluate the merits of the case or claim, our exposure to the matter, possible legal or settlement strategies and the likelihood of an unfavorable outcome. If we determine that an unfavorable outcome is probable and can be estimated, we establish the necessary accruals. While the outcome of these matters, including those discussed above, cannot be predicted with certainty, and there are still uncertainties related to the costs we may incur, based upon our evaluation and experience to date, we had no accrual for our outstanding legal matters at March 31, 2010. It is possible, however, that new information or future developments could require us to reassess our potential exposure related to these matters and establish accruals accordingly.

Environmental Matters

We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws and regulations require us to remove or remedy the effect of the disposal or release of specified substances at current and former operating sites. At ~~March~~June 3130, 2010 and December 31, 2009, we had accrued approximately $5 million for expected remediation costs and associated onsite, offsite and groundwater technical studies and for related environmental legal costs; however, we estimate that our exposure could be as high as $7 million at ~~March~~June 3130, 2010.

Our environmental remediation projects are in various stages of completion. Our recorded liabilities reflect our current estimates of amounts we will expend to remediate these sites. However, depending on the stage of completion or assessment, the ultimate extent of contamination or remediation required may not be known. As additional assessments occur or remediation efforts continue, we may incur additional liabilities.

Polychlorinated Biphenyls (PCB) Cost Recoveries and Refund. Since 1994, we have been conducting remediation activities at certain of our compressor stations associated with PCBs and other hazardous materials. We have collected amounts, substantially in excess of remediation costs to date, through a surcharge to our customers under a settlement approved by the Federal Energy Regulatory Commission (FERC) in November of 1995. In November 2009, the FERC approved an amendment to the 1995 settlement that provides for interim refunds over a three year period of approximately $157 million of our collected amounts plus interest of 8%. Through ~~March~~June 3130, 2010, we have refunded approximately $3039 million to our customers. Our refund obligations are recorded as regulatory liabilities on our balance sheet and as of ~~March~~June 3130, 2010, we have classified approximately $4757 million as current liabilities based on the timing of when these amounts are expected to be refunded to our customers.

Superfund Matters. Included in our recorded environmental liabilities are projects where we have received notice that we have been designated or could be designated as a Potentially Responsible Party (PRP) under the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), commonly known as Superfund, or state equivalents for four active sites. Liability under the federal CERCLA statute may be joint and several, meaning that we could be required to pay in excess of our pro rata share of remediation costs. We consider the financial strength of other PRPs in estimating our liabilities. Accruals for these issues are included in the environmental reserve discussed above.

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Superfund Matters. Included in our recorded environmental liabilities are projects where we have received notice that we have been designated or could be designated as a Potentially Responsible Party (PRP) under the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA), commonly known as Superfund, or state equivalents for three active sites. Liability under the federal CERCLA statute may be joint and several, meaning that we could be required to pay in excess of our pro rata share of remediation costs. We consider the financial strength of other PRPs in estimating our liabilities. Accruals for these issues are included in the environmental reserve discussed above.

For the remainder of 2010, we estimate that our total remediation expenditures will be approximately $1 million, most of which will be expended under government directed clean-up plans. In addition, we expect to make capital expenditures for environmental matters of approximately $4 million in the aggregate for the remainder of 2010 through 2014.

It is possible that new information or future developments could require us to reassess our potential exposure related to environmental matters. We may incur significant costs and liabilities in order to comply with existing environmental laws and regulations. It is also possible that other developments, such as increasingly strict environmental laws, regulations and orders of regulatory agencies, as well as claims for damages to property and the environment or injuries to employees and other persons resulting from our current or past operations, could result in substantial costs and liabilities in the future. As this information becomes available, or other relevant developments occur, we will adjust our accrual amounts accordingly. While there are still uncertainties related to the ultimate costs we may incur, based upon our evaluation and experience to date, we believe our reserves are adequate.

Other Commitments

Capital Commitments. At ~~March~~June 3130, 2010, we had capital commitments of approximately $~~244~~259 million related to our 300 Line expansion project, of which $4950 million will be spent in the remainder of 2010, $~~190~~204 million will be spent in 2011 and $5 million will be spent in 2012.

Asset Retirement Obligations. At ~~March~~June 3130, 2010 and December 31, 2009, we had total asset retirement liabilities of $86 million and $91 million, and we have classified $6160 million and $66 million as current liabilities on our balance sheets.

4. Accounts Receivable Sales Program

During 2009, we had an agreement to sell a senior interest in certain accounts receivable (which are short-term assets that generally settle within 60 days) to a third party financial institution (through a wholly-owned special purpose entity), and we retained a subordinated interest in those receivables. The sale of the senior interest qualified for sale accounting and was conducted to accelerate cash from these receivables, the proceeds from which were used to increase liquidity and lower our overall cost of capital. During the quarter and six months ended ~~March~~June 3130, 2009, we received $~~124~~115 million and $239 million of cash related to the sale of the senior interest, collected $~~163~~112 million and $275 million from the subordinated interest we retained in the receivables, and recognized a loss of less than $1 million on these transactions. At December 31, 2009, the third party financial institution held $40 million of senior interest and we held $43 million of subordinated interest. Our subordinated interest is reflected in accounts receivable inon our balance sheet. In January 2010, we terminated this accounts receivable sales program and paid $40 million to acquire the senior interest. We reflected the cash flows related to the accounts receivable sold under this program, changes in our retained subordinated interest, and cash paid to terminate the program, as operating cash flows inon our statement of cash flows.

In the first quarter of 2010, we entered into a new accounts receivable sales program to continue to sell accounts receivable to the third party financial institution that qualify for sale accounting under the updated accounting standards related to financial asset transfers. Under this program, we sell receivables in their entirety to the third party financial institution (through a wholly-owned special purpose entity). As of ~~March~~June 3130, 2010, the third party financial institution held $8174 million of the accounts receivable we sold under the program. In connection with our accounts receivable sales, we receive a portion of the sales proceeds up front and receive an additional amount upon the collection of the underlying receivables. Our ability to recover this additional amount is based solely on the collection of the underlying receivables. During the ~~first~~ quarter ofand six months end June 30, 2010, we received $~~160~~113 million and $273 million of cash up front from the sale of the receivables and received an additional $8593 million and $178 million of cash upon the collection of the underlying receivables. As of ~~March~~June 3130, 2010, we had not collected approximately $4137 million related to our accounts receivable sales, which is reflected as other accounts receivable inon our balance sheet. We recognized a loss of less than $1 million on our accounts receivable sales during the ~~first~~ quarter ofand six months ended June 30, 2010. Because the cash received up front and the cash received as the underlying receivables are collected both are related to the sale or ultimate collection of the underlying receivables, and not subject to significant other risks given their short term nature, we reflect all cash flows under the new accounts receivable sales program as operating cash flows inon our statement of cash flows.

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Under both the prior and current accounts receivable sales programs, we serviced the underlying receivables for a fee. The fair value of these servicing agreements as well as the fees earned were not material to our financial statements for the ~~quarters~~periods ended ~~March~~June 3130, 2010 and 2009.

The third party financial institution involved in both of these accounts receivable sales programs acquires interests in various financial assets and issues commercial paper to fund those acquisitions. We do not consolidate the third party financial institution because we do not have the power to direct its overall activities (and do not absorb a majority of its expected losses) since our receivables do not comprise a significant portion of its operations.

5. Investment in Unconsolidated Affiliate and Transactions with Affiliates

Investment in Unconsolidated Affiliate

We have a 50 percent ownership interest in Bear Creek Storage Company, L.L.C. (Bear Creek), a joint venture with Southern Natural Gas Company, our affiliate. For the ~~quarters~~six months ended ~~March~~June 3130, 2010 and 2009, we received $37 million ~~and~~in cash dividends from Bear Creek. In July 2010, we received an additional $4 million in cash dividends. Also, ~~from~~in July 2010, Bear Creek utilized its note receivable balance under the cash management program with El Paso to pay a cash distribution to its partners, including $23 million to us.

Summarized financial information of our proportionate share of our unconsolidated affiliate for the ~~quarters~~periods ended ~~March 31~~June 30 is presented as follows:

	2010		2009
	Quarter Ended June 30,				Six Months Ended June 30,
	(In millions)
	2010		2009		2010		2009
Operating results data:
	(In millions)
Operating revenues	$	5	$	5
Operating results data:
Operating expenses		1		2
Operating revenues	$	5	$	4	$	10	$	9
Income from continuing operations and net income		4		3
Operating expenses		2		2		3		4
Income from continuing operations and net income		3		2		7		5

Transactions with Affiliates

Cash Management Program and Other Notes Receivable. We participate in El Paso’s cash management program which matches short-term cash surpluses and needs of participating affiliates, thus minimizing total borrowings from outside sources. El Paso uses the cash management program to settle intercompany transactions between participating affiliates. We have historically advanced cash to El Paso in exchange for an affiliated note receivable that is due upon demand. At ~~March~~June 3130, 2010 and December 31, 2009, we had a note receivable from El Paso of approximately $1.0 billion. We classified approximately $88173 million of this receivable as current on our balance sheet at ~~March~~June 3130, 2010, based on the net amount we anticipate using in the next twelve months considering available cash sources and needs. The interest rate on this variable rate note was 1.6% and 1.5% at ~~March~~June 3130, 2010 and at December 31, 2009.

At ~~March~~June 3130, 2010 and December 31, 2009, we had a non-interest bearing note receivable of $334 million from an El Paso affiliate. ~~This note is~~ reflected as a reduction of our stockholder’s equity. On ~~based~~July on30, ~~uncertainties~~2010, ~~regarding~~we ~~the~~collected ~~timing~~this note receivable and ~~method~~then ~~through~~immediately ~~which~~distributed Elthe ~~Paso~~cash ~~will~~received ~~settle~~to ~~these~~our ~~balances~~parent.

Income Taxes. El Paso files consolidated U.S. federal and certain state tax returns which include our taxable income. In certain states, we file and pay taxes directly to the state taxing authorities. At ~~March~~June 3130, 2010 and December 31, 2009, we had net federal and state income taxes payable of $66 million and $75 million. The majority of these balances, as well as deferred income taxes and amounts associated with the resolution of unrecognized tax benefits, will become payable to El Paso.

Other Affiliate Balances. At June 30, 2010 and December 31, 2009, we had contractual deposits from our affiliates of $9 million.

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~~Other~~ Affiliate ~~Balances~~Revenues and Expenses. AtWe ~~March~~enter ~~31,~~into ~~2010~~transactions ~~and~~with ~~December~~our 31affiliates within the ordinary course of business. For a further discussion of our affiliated transactions, see our 2009, weAnnual ~~had~~Report ~~contractual~~on ~~deposits~~Form 10-K. The following table shows revenues and charges from our affiliates offor $9the ~~million.~~periods ended June 30:

Affiliate Revenues and Expenses. We enter into transactions with our affiliates within the ordinary course of business. For a further discussion of our affiliated transactions, see our 2009 Annual Report on Form 10-K. The following table shows revenues and charges from our affiliates for the quarters ended March 31:

	Quarter Ended June 30,				Six Months Ended June 30,
	2010		2009		2010		2009
	(In millions)
Revenues from affiliates	$	5	$	4	$	10	$	8
Operation and maintenance expenses from affiliates		20		17		41		34
Reimbursement of operating expenses charged to affiliates		15		11		30		23

	2010		2009
	(In millions)
Revenues from affiliates	$	5	$	4
Operation and maintenance expenses from affiliates		21		17
Reimbursements of operating expenses charged to affiliates		15		12

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

The information required by this Item is presented in a reduced disclosure format pursuant to General Instruction H to Form 10-Q. In addition, this Item updates, and should be read in conjunction with the information disclosed in our 2009 Annual Report on Form 10-K, and the financial statements and notes presented in Item 1 of this Quarterly Report on Form 10-Q.

Results of Operations

Our management uses earnings before interest expense and income taxes (EBIT) as a measure to assess the operating results and effectiveness of our business, which consists of consolidated operations as well as an investment in an unconsolidated affiliate. We believe EBIT is useful to investors to provide them with the same measure used by El Paso to evaluate our performance. We define EBIT as net income adjusted for items such as (i) interest and debt expense, (ii) affiliated interest income, and (iii) income taxes. We exclude interest and debt expense from this measure so that investors may evaluate our operating results without regard to our financing methods. EBIT may not be comparable to measures used by other companies. Additionally, EBIT should be considered in conjunction with net income, income before income taxes and other performance measures such as operating income or operating cash flows. Below is a reconciliation of our EBIT to net income, our throughput volumes and an analysis and discussion of our results for the ~~quarter~~six months ended ~~March~~June 3130, 2010 compared with the same period in 2009.

Operating Results:

	2010			2009
	(In millions, except for volumes)
Operating revenues	$	~~224~~424		$	~~266~~483
Operating expenses		(~~135~~276	)		(~~152~~299	)
Operating income		89148			~~114~~184
Earnings from unconsolidated affiliate		47			35
Other income, net		59			37
EBIT		98164			~~120~~196
Interest and debt expense		(3875	)		(3877	)
Affiliated interest income, net		37			48
Income taxes		(2437	)		(3349	)
Net income	$	3959		$	5378
Throughput volumes (BBtu/d)		5,~~491~~023			54,~~497~~912

EBIT Analysis:

	Revenue			Expense			Other		EBIT Impact
	Operating Revenue			Operating Expense			Other		Total
	Favorable/(Unfavorable)
	(In millions)
Gas not used in operations and other natural gas sales	$	(3853	)	$	812		$	—	$	(3041	)
Expansions		35			—(1	)		24		58
Reservation and other services revenues		(711	)		—			—		(711	)
Operating and general and administrative expenses		—			56			—		56
Hurricanes		—			3			—		3
Hurricane repairs		—			5			—		5
Other(1)		—			1			1—		21
Total impact on EBIT	$	(4259	)	$	1723		$	34	$	(2232	)

_______________

(1)	Consists of individually insignificant items.

Gas Not Used in Operations and Other Natural Gas Sales. ~~Gas not used in operations results in revenues to us, which we recognize when volumes are retained.~~ During the ~~quarter~~six months ended ~~March~~June 3130, 2010, our EBIT decreased $3853 million primarily due to lower average realized prices ~~and sales volume~~ on operational sales as compared to the same period in 2009. Our EBIT was favorably impacted by $812 million due to lower electric compression expenses from decreased utilization. Gas not used in operations results in revenues to us, which we recognize when volumes are retained. As discussed below, the shifts in receipts on our system have reduced the volumes of gas not used in operations resulting in fewer volumes collected. For a further discussion of gas not used in operations and other natural gas sales, see our 2009 Annual Report on Form 10-K.

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Expansions. In 2009, we placed several expansion projects in service including the Carthage expansion in May, the Concord Lateral expansion in October, and the Blue Water expansion in November. As a result, for the six ~~quarter~~months ended ~~March~~June 3130, 2010, our revenues increased as compared to the same period in 2009.

Listed below are significant updates to our expansion projects discussed in our 2009 Annual Report on Form 10-K.

· 300 Line Expansion. InDuring ~~July 2009~~2010, ~~we filed an application with~~ the FERC ~~for~~issued ~~certificate~~a ~~authorization~~favorable toenvironmental ~~construct~~assessment ~~our 300 Line expansion project~~ and we ~~anticipate~~received ~~receiving~~certificate ~~their~~authorization ~~approval~~from in the ~~second~~FERC ~~quarter~~to ofconstruct ~~2010~~the expansion. AIn ~~favorable~~June ~~environmental~~2010, ~~assessment~~we ~~was~~commenced ~~issued~~construction byon ~~the~~our ~~FERC~~compression infacilities ~~the~~related ~~first~~to ~~quarter~~this ~~of 2010~~project.

· Northeast Upgrade Project. In February 2010, we entered into precedent agreements with two shippers to provide 620 MMcf/d of additional firm transportation service from receipt points in the Marcellus shale basin to an interconnect in New Jersey. ~~Total estimated cost for this project is approximately $416 million and is anticipated to be placed in service in late 2013.~~

~~Reservation~~· ~~and~~Northeast ~~Other~~Supply ~~Services~~Diversification ~~Revenues~~Project. During ~~the~~2010, ~~quarter~~we ~~ended~~entered ~~March~~into ~~31,~~precedent ~~2010,~~agreements ~~our~~with ~~EBIT~~three ~~was~~shippers ~~unfavorably~~to ~~impacted~~provide by approximately $7250 ~~million~~MMcf/d ~~primarily~~of ~~due~~additional tofirm atransportation ~~shift~~service ~~in receipts~~ from ~~the~~receipt ~~Gulf~~points ~~Coast~~in ~~region to~~ the Marcellus shale basin ~~resulting~~to delivery points in ~~decreased~~the ~~long-haul~~New ~~deliveries~~York and New England markets. In ~~addition,~~Total weestimated ~~experienced~~cost aof ~~decrease~~this inproject ~~our~~is ~~other~~less ~~services~~than ~~revenue~~$100 ~~due~~million. Subject to ~~milder~~FERC ~~weather~~and inother approvals, the ~~northeast~~project ~~market~~is ~~area. Partially~~expected ~~offsetting~~to ~~these~~commence ~~decreases~~construction ~~was~~in anthe ~~increase~~first inhalf ~~new~~of ~~backhaul~~2012 ~~contracts~~and ~~from~~is ~~the~~anticipated ~~Marcellus~~to ~~shale~~be ~~basin~~placed in service on November 1, 2012.

~~Operating~~Reservation and ~~General~~Other ~~and~~Services ~~Administrative Expenses~~Revenues. During the ~~quarter~~six months ended ~~March~~June 3130, 2010, ~~our~~throughput ~~operating~~volumes ~~and~~on ~~general~~our ~~and~~system ~~administrative~~increased ~~expenses~~by ~~were~~2% ~~lower~~compared ~~than~~to the same period in 2009; ~~primarily~~however, ~~due~~as a result of a shift in receipts from the Gulf Coast Region to ~~lower~~the ~~bonus~~Rockies Express Pipeline interconnect and ~~benefit~~the ~~costs~~Marcellus shale basin, our long-haul transport decreased while our backhaul service from the Marcellus shale basin increased, for a net unfavorable impact to EBIT of approximately $9 million. We believe our recently announced Northeast Supply Diversification project will expand our presence from Marcellus to the New York and New England markets. In addition, usage revenues decreased by $6 million due to reduced interruptible services resulting from unfavorable price spreads, partially offset by an increase of $3 million in liquids separation dehydration sales due to increased contractual rates.

~~Hurricanes~~Operating and General and Administrative Expenses. ~~For~~ During the ~~quarter~~six months ended ~~March~~June 3130, ~~2009~~2010, our ~~EBIT~~operating ~~was~~and ~~unfavorably~~general ~~impacted~~and byadministrative ~~repair~~expenses ~~costs~~were ~~that~~lower ~~will~~than ~~not~~the besame ~~recoverable~~period ~~from~~in ~~insurance~~2009 primarily due to ~~losses~~lower ~~not~~payroll ~~exceeding~~costs, ~~self-retention~~net ~~levels~~of capitalization and reimbursement from affiliates.

Hurricane Repairs. For the six months ended June 30, 2009, our EBIT was unfavorably impacted by repair costs that will not be recoverable from insurance due to losses which did not exceed our self-retention levels.

Affiliated Interest Income, Net

The following table shows the average advances due from El Paso and the average short-term interest rates for the ~~quarters~~six months ended ~~March~~June 3130:

	2010			2009
	(In millions, except for rates)
Average advance due from El Paso	$	~~901~~953		$	~~818~~855
Average short-term interest rate		1.5	%		2.20	%

Income Taxes

Our effective tax ~~rates~~rate of 3839 percent for the ~~quarters~~six months ended ~~March~~June 3130, 2010 and 2009 ~~were~~was higher than the statutory rate of 35 percent primarily due to the effect of state income taxes.

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Liquidity and Capital Resources

Our primary sources of liquidity are cash flows from operating activities and amounts available to us under El Paso’s cash management program. At ~~March~~June 3130, 2010, we had a note receivable from El Paso of approximately $1.0 billion of which approximately $88173 million was classified as current based on the net amount we anticipate using in the next twelve months considering available cash sources and needs. At ~~March~~June 3130, 2010, we had a non-interest bearing note receivable of $334 million from an El Paso affiliate. ~~This note is~~ reflected as a reduction of our stockholder’s equity. On ~~based~~July on30, ~~uncertainties~~2010, ~~regarding~~we ~~the~~collected ~~timing~~this note receivable and ~~method~~then ~~through~~immediately ~~which~~distributed Elthe ~~Paso~~cash ~~will~~received ~~settle~~to ~~these~~our ~~balances~~parent. See Item 1, Financial Statements, Note 5 for a further discussion of El Paso’s cash management program and our other affiliate note receivable. Our primary uses of cash are for working capital and capital expenditures. Our cash capital expenditures for the ~~quarter~~six months ended ~~March~~June 3130, 2010, and our estimated capital expenditures for the remainder of this year to expand and maintain our system are listed below.

	Quarter Ended March 31, 2010		2010 Remaining		Total
	Six Months Ended June 30, 2010		2010 Remaining		Total
	(In millions)
Maintenance	$	12	$	156	$	168
Maintenance(1)	$	18	$	121	$	139
Expansion		2649		~~156~~130		~~182~~179
Other (1)		19		78		97
Other(2)		34		62		96
	$	57101	$	~~390~~313	$	~~447~~414

_______________

(1) ~~Relates~~Amount tois ~~building~~net ~~renovations~~of atinsurance ~~our~~proceeds ~~corporate facilities~~received.

(2)	Relates to building renovations at our corporate facilities.

Although financial market conditions have improved since late 2008 and early 2009, volatility in the remainder of 2010 and beyond in the financial markets could impact our longer-term access to capital for future growth projects as well as the cost of such capital. Additionally, although the impacts are difficult to quantify at this point, a prolonged recovery of the global economy could have adverse impacts on natural gas consumption and demand. However, we believe our exposure to changes in natural gas consumption and demand is partially mitigated by a revenue base that includes long-term contracts that are based on firm demand charges.

We believe we have adequate liquidity available to us to meet our capital requirements and our existing operating needs through cash flows from operating activities and amounts available to us under El Paso’s cash management program. In addition to the cash management program above, we are eligible to borrow amounts available under El Paso’s $1.5 billion credit agreement and are only liable for amounts we directly borrow. As of ~~March~~June 3130, 2010, El Paso had approximately $01.91 billion of capacity remaining and available to us and our affiliates under this credit agreement, and none of the amount outstanding under the facility was issued or borrowed by us. For a further discussion of this credit agreement, see our 2009 Annual Report on Form 10-K. While we do not anticipate a need to directly access the financial markets in the remainder of 2010 for any of our operating activities or expansion capital needs based on liquidity available to us, market conditions may impact our ability to act opportunistically.

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Commitments and Contingencies

Below is a summary of certain climate change and energy policies recently enacted or proposed that, if enacted, will likely impact our business. For a further discussion of our commitments and contingencies, see Item 1, Financial Statements, Note 3, which is incorporated herein by reference.

Climate Change Legislation and Regulation. Legislative and regulatory efforts to address climate change and greenhouse gas (GHG) emissions are in various phases of discussions or implementation at international, federal, regional and state levels. We believe that legislation that either limits or sets a price on carbon emissions will increase demand for natural gas depending on the legislative provisions ultimately adopted. However, we also believe it is reasonably likely that the federal legislation being contemplated, as well as recently adopted and proposed federal regulations, would increase our cost of environmental compliance by requiring us to purchase emission allowances or offset credits, install additional equipment or change work practices, and could materially increase the cost of goods and services we purchase from suppliers due to their increased compliance costs. Although we believe that many of these costs should be recoverable in our rates, recovery through these mechanisms is still uncertain at this time.

The Environmental Protection Agency (EPA) has adopted regulations that require us to monitor and report certain GHG emissions from our operations on an annual basis. The EPA has proposed to further expand the monitoring and reporting requirements to additional natural gas transmission sources which could materially increase the costs of our operations. ~~The~~Our ~~EPA~~preliminary ~~has~~estimate ~~also~~of ~~proposed regulations pursuant to which GHG emissions would be regulated under~~ the ~~Clean~~first-year ~~Air Act in 2011. These proposed rules, if adopted, would likely have a material impact on our~~ cost ~~of operations, could require us~~ to ~~install new equipment to control emissions from~~ our ~~facilities,~~company asis ~~well~~over $1 ~~as could result in delays and negative impacts on our ability to obtain permits and other regulatory approvals with regard to existing and new facilities~~million.

ItThe isEPA ~~uncertain~~has ~~what~~also ~~federal~~adopted orregulations ~~state~~that ~~legislation~~will orrequire ~~regulations~~permits ~~will~~to ~~ultimately~~ be ~~adopted~~obtained ~~and~~under ~~whether~~the ~~they~~Clean ~~will~~Air ~~withstand~~Act ~~likely~~for ~~legal~~GHG ~~challenges~~emissions above certain thresholds. ~~Therefore,~~Depending on the ~~potential~~thresholds ultimately established by the EPA, these permit requirements could have a material impact onupon the cost of our operations, could require us to install new equipment to control emissions from our facilities and ~~construction~~could ~~projects~~result ~~remains~~in ~~uncertain~~delays and negative impacts on our ability to obtain permits and other regulatory approvals with regard to new and existing facilities. The EPA’s regulations are being challenged in the federal courts; however, pending such judicial reviews, the thresholds that have been established by the EPA through at least 2016 are not expected to have a material impact on our operations or financial results.

~~Energy~~It ~~Legislation.~~is Inuncertain ~~conjunction~~what ~~with these climate change proposals, there have been various~~ federal ~~and~~or state ~~legislative~~legislation ~~and~~or ~~regulatory~~regulations ~~proposals that would create additional incentives to move to a less carbon intensive “footprint.” Although it is reasonably likely that many of these proposals~~ will ultimately be ~~enacted~~adopted ~~over~~and ~~the~~whether ~~next~~adopted ~~few years, we cannot predict the form of any laws and~~ regulations ~~that~~will ~~might~~withstand belikely ~~enacted,~~legal ~~the timing of their implementation~~challenges. Therefore, or the ~~precise~~potential impact on our operations orand ~~demand~~construction ~~for~~projects ~~natural~~remains ~~gas~~uncertain. ~~However, such proposals if enacted could negatively impact natural gas demand over the longer term.~~

~~Air~~Energy ~~Quality Regulations~~Legislation. In ~~March~~conjunction ~~2009,~~with ~~the~~these ~~EPA~~climate ~~proposed~~change ~~a rule~~proposals, ~~that~~there ishave ~~expected~~been tovarious befederal ~~finalized~~and ~~later~~state inlegislative ~~2010~~and ~~impacting~~regulatory ~~emissions~~proposals ofthat ~~hazardous~~would ~~air~~create ~~pollutants~~additional ~~from~~incentives ~~reciprocating~~to ~~internal~~move ~~combustion engines and requiring us~~ to ~~install~~a ~~emission~~less ~~controls~~carbon onintensive ~~our pipeline system~~“footprint.” AsAlthough ~~proposed,~~it ~~engines~~is ~~subject~~reasonably tolikely ~~the~~that ~~regulations~~many ~~would~~of ~~have~~these toproposals will be inenacted ~~compliance~~over bythe ~~August~~next ~~2013.~~few ~~Based~~years, ~~upon~~we ~~that~~cannot ~~timeframe,~~predict wethe ~~expect~~form ~~that~~of weany ~~would~~laws ~~begin~~and ~~incurring~~regulations ~~expenditures~~that inmight ~~late~~be ~~2010~~enacted, ~~incur~~ the ~~majority~~timing of ~~the~~their ~~expenditures in 2011 and 2012~~implementation, ~~and~~or ~~expend~~the ~~any~~precise ~~remaining~~impact ~~amounts in early 2013. Based~~ on our ~~expectation~~operations ~~that~~or ~~the~~demand ~~final~~for ~~rule~~natural ~~will~~gas. beHowever, ~~similar~~such toproposals aif ~~recently~~enacted ~~adopted~~could ~~rule applicable to diesel engines, our current estimated~~ impact isnatural ~~approximately~~gas $9demand ~~million in capital expenditures~~ over the ~~period~~longer ~~from 2010 to 2013~~term.

Air Quality Regulations. In March 2009, the EPA proposed a rule that is expected to be finalized later in 2010 impacting emissions of hazardous air pollutants from reciprocating internal combustion engines and requiring us to install emission controls on our pipeline system. As proposed, engines subject to the regulations would have to be in compliance by August 2013. Based upon that timeframe, we expect that we would begin incurring expenditures in late 2010, incur the majority of the expenditures in 2011 and 2012, and expend any remaining amounts in early 2013. Based on our expectation that the final rule will be similar to a recently adopted rule applicable to diesel engines, our current estimated impact is approximately $7 million in capital expenditures over the period from 2010 to 2013.

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In February 2010, the EPA promulgated a new one-hour National Ambient Air Quality Standard (NAAQS) for oxides of nitrogen (NO2). The new standard is in addition to the existing annual NAAQS which was not changed. While it is uncertain how the EPA and the states will apply the new one-hour NAAQS, the new NAAQS may impact our ability to obtain permits and other regulatory approvals with regard to existing and new facilities and may cause us to incur costs to install additional controls on existing and new facilities. The EPA’s new rule is being challenged in the federal courts. While the new NAAQS, if upheld, could have a material impact on our cost of operations and our cost to install new facilities, we are unable, at this point, to estimate its financial impact.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

As of ~~March~~June 3130, 2010, we carried out an evaluation under the supervision and with the participation of our management, including our President and Chief Financial Officer (CFO), as to the effectiveness, design and operation of our disclosure controls and procedures. This evaluation considered the various processes carried out under the direction of our disclosure committee in an effort to ensure that information required to be disclosed in the U.S. Securities and Exchange Commission reports we file or submit under the Securities Exchange Act of 1934, as amended (Exchange Act) is accurate, complete and timely. Our management, including our President and CFO, does not expect that our disclosure controls and procedures or our internal controls will prevent and/or detect all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within a our company have been detected. Our disclosure controls and procedures are designed to provide reasonable assurance of achieving their objectives and our President and CFO concluded that our disclosure controls and procedures (as defined in ~~the~~ Exchange Act Rules 13a-15(e) and 15d-15(e)) were effective as of ~~March~~June 3130, 2010.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting during the ~~first~~second quarter of 2010 that have materially affected or are reasonably likely to materially affect our internal control over financial reporting.

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PART II — OTHER INFORMATION

Item 1. Legal Proceedings

See Part I, Item 1, Financial Statements, Note 3, which is incorporated herein by reference.

Item 1A. Risk Factors

CAUTIONARY STATEMENTS FOR PURPOSES OF THE “SAFE HARBOR” PROVISIONS OF

THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995

This report contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements are based on assumptions or beliefs that we believe to be reasonable; however, assumed facts almost always vary from actual results, and differences between assumed facts and actual results can be material, depending upon the circumstances. Where, based on assumptions, we or our management express an expectation or belief as to future results, that expectation or belief is expressed in good faith and is believed to have a reasonable basis. We cannot assure you, however, that the stated expectation or belief will occur, be achieved or accomplished. The words “believe,” “expect,” “estimate,” “anticipate,” and similar expressions will generally identify forward-looking statements. All of our forward-looking statements, whether written or oral, are expressly qualified by these cautionary statements and any other cautionary statements that may accompany such forward-looking statements. In addition, we disclaim any obligation to update any forward-looking statements to reflect events or circumstances after the date of this report.

Important factors that could cause actual results to differ materially from estimates or projections contained in forward-looking statements are described in our 2009 Annual Report on Form 10-K under Part I, Item 1A, Risk Factors. There have been no material changes in these risk factors since that report.

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

Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.

Item 3. Defaults Upon Senior Securities

Omitted from this report pursuant to the reduced disclosure format permitted by General Instruction H to Form 10-Q.

Item 4. (Removed and Reserved)

Item 5. Other Information

None.

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Item 6. Exhibits

The Exhibit Index is incorporated herein by reference.

The agreements included as exhibits to this report are intended to provide information regarding their terms and not to provide any other factual or disclosure information about us or the other parties to the agreements. The agreements may contain representations and warranties by the parties to the agreements, including us, solely for the benefit of the other parties to the applicable agreement and:

·	should not in all instances be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate;

·	may have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement, which disclosures are not necessarily reflected in the agreement;

·	may apply standards of materiality in a way that is different from what may be viewed as material to certain investors; and

·	were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement and are subject to more recent developments.

Accordingly, these representations and warranties may not describe the actual state of affairs as of the date they were made or at any other time.

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SIGNATURES

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

	TENNESSEE GAS PIPELINE COMPANY
Date: May 7, 2010	By:	/s/ James C. Yardley
Date: August 6, 2010	/s/ Norman G. Holmes
		James C. Yardley
	Norman G. Holmes President (Principal Executive Officer)
		President
Date: August 6, 2010	/s/ John R. Sult
		(Principal Executive Officer)
	John R. Sult Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Date: May 7, 2010	By:	/s/ John R. Sult
		John R. Sult
		Executive Vice President and Chief Financial Officer
		(Principal Financial Officer)

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TENNESSEE GAS PIPELINE COMPANY

EXHIBIT INDEX

Each exhibit identified below is filed as a part of this report

Exhibit Number	Description

31.A	Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.B	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.A	Certification of Principal Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.B	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

17 18

Filing Compare · TENNESSEE GAS PIPELINE COMPANY, L.L.C.