Boardwalk Pipeline Partners (BWP) 10-K 16 Feb 10 2009 FY Annual report Financial data

Consolidated Balance Sheets

Consolidated Balance Sheets (USD $)
In Millions	Dec. 31, 2009	Dec. 31, 2008
Current Assets:
Cash and cash equivalents	45.8	137.7
Short-term investments	0	175
Receivables:
Trade, net	95.5	67.3
Other	13.5	18
Gas transportation receivables	7.9	13.5
Costs recoverable from customers	6	5.4
Gas stored underground	2.1	0.2
Prepayments	10.1	17.3
Other current assets	10	17.4
Total current assets	190.9	451.8
Property, Plant and Equipment:
Natural gas transmission plant	6406.7	3,871
Other natural gas plant	217.1	215.2
Construction work-in-progress	231.4	2196.4
Property, plant and equipment, gross	6855.2	6282.6
Less—accumulated depreciation and amortization	577.3	382.4
Property, plant and equipment, net	6277.9	5900.2
Other Assets:
Goodwill	163.5	163.5
Gas stored underground	133.7	124.8
Costs recoverable from customers	16.1	15.4
Other	113.7	65.9
Total other assets	427	369.6
Total Assets	6895.8	6721.6
Payables:
Trade	58.4	216.4
Affiliates	8.6	1.8
Other	17.8	7.4
Gas transportation payables	5	11.6
Accrued taxes, other	41.2	35.2
Accrued interest	41.8	40.1
Accrued payroll and employee benefits	16.4	16.3
Construction retainage	21	76.3
Deferred income	20.9	1.8
Other current liabilities	19.8	27.1
Total current liabilities	250.9	434
Long-term debt	3,000	2889.4
Long -term debt - affiliate	100	0
Total long-term debt	3,100	2889.4
Other Liabilities and Deferred Credits:
Pension liability	31.6	35.7
Asset retirement obligation	18	18
Provision for other asset retirement	47	45.6
Payable to affiliate	20.6	20.6
Other	63.5	33.3
Total other liabilities and deferred credits	180.7	153.2
Partners' Capital:
Common units – 169.7 and 154.9 million units issued and outstanding as of December 31, 2009 and 2008	2640.5	2504.8
Class B units – 22.9 million units issued and outstanding as of December 31, 2009 and 2008	683.6	692.8
General partner	65.5	62.9
Accumulated other comprehensive loss, net of tax	-25.4	-15.5
Total partners' capital	3364.2	3,245
Total Liabilities and Partners' Capital	6895.8	6721.6

Parenthetical Consolidated Bala

Parenthetical Consolidated Balance Sheets (USD $)
	Dec. 31, 2009	Dec. 31, 2008
Partners' Capital:
Common units	169,721,916	154,934,609
Class B units	22,866,667	22,866,667

Consolidated Statements of Inco

Consolidated Statements of Income (USD $)
In Millions, except Per Share data	12 Months Ended Dec. 31, 2009		12 Months Ended Dec. 31, 2008		12 Months Ended Dec. 31, 2007
Operating Revenues:
Gas transportation	794.9		698.2		529.7
Parking and lending	34.9		16.3		42.8
Gas storage	57.6		51.5		39.4
Other	21.8		18.8		31.3
Total operating revenues	909.2		784.8		643.2
Operating Costs and Expenses:
Fuel and gas transportation	61.9		102.4		46.4
Operation and maintenance	142.2		119.9		127.4
Administrative and general	122		106		97
Depreciation and amortization	203.1		124.8		81.8
Contract settlement gain	0		-11.2		0
Asset impairment	0		3		19.2
Net loss (gain) on disposal of operating assets and related contracts	8.2		-49.2		-23.8
Taxes other than income taxes	77.3		42.5		29.2
Total operating costs and expenses	614.7		438.2		377.2
Operating income	294.5		346.6		266
Other Deductions (Income):
Interest expense	125.3		57.7		61
Interest expense - affiliates, net	6.8		0		0
Interest income	-0.2		-2.9		-21.5
Miscellaneous other income, net	-0.4		-3.2		(2)
Total other deductions	131.5		51.6		37.5
Income before income taxes	163		295		228.5
Income taxes expense	0.3		1		0.8
Net Income	162.7		$294		227.7
Basic and diluted net income per limited partner unit:
Common units (1)	0.88	[1]	2.09	[1]	1.91	[1]
Class B units	0.08		0.6		$0
Subordinated units (1)	$0	[1]	1.68	[1]	1.86	[1]
Cash distribution to common and subordinated unitholders (1)	1.95	[1]	1.87	[1]	1.74	[1]
Cash distribution to class B units	1.2		0.3		$0
Weighted-average number of limited partners units outstanding:
Common units (1)	161.6	[1]	104.2	[1]	82.5	[1]
Class B units (2)	22.9	[2]	22.9	[2]	0	[2]
Subordinated units (1)	0	[1]	28.7	[1]	33.1	[1]
[1] All of the 33.1 million subordinated units converted to common units on a one-for-one basis in November 2008.
[2]Number of class B units shown is weighted from July 1, 2008, which is the date they became eligible to participate in earnings. The class B units do not participate in quarterly distributions above $0.30 per unit.

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (USD $)
In Millions	12 Months Ended Dec. 31, 2009	12 Months Ended Dec. 31, 2008	12 Months Ended Dec. 31, 2007
OPERATING ACTIVITIES:
Net income	162.7	$294	227.7
Adjustments to reconcile to cash provided by operations:
Depreciation and amortization	203.1	124.8	81.8
Amortization of deferred costs	9.4	9	8.3
Amortization of acquired executory contracts	0	-0.2	-1.1
Asset impairment	0	3	19.2
Net loss (gain) on disposal of operating assets and related contracts	8.2	-49.2	-23.8
Changes in operating assets and liabilities:
Trade and other receivables	-23.4	-16.6	-4.1
Gas receivables and storage assets	(5)	26.2	-1.4
Costs recoverable from customers	-1.6	0.9	3.6
Inventories	0	-8.8	-2.5
Other assets	(18)	-30.5	-13.3
Trade and other payables	25.9	9.5	-15.9
Other payables, affiliates	0.7	0	0
Gas payables	2.4	-15.1	-11.1
Accrued liabilities	4.3	7	12.9
Other liabilities	31.8	-3.7	1.4
Net cash provided by operating activities	400.5	350.3	281.7
INVESTING ACTIVITIES:
Capital expenditures	846.8	2652.5	1209.8
Proceeds from sale of operating assets, net	0	63.8	28.7
Proceeds from insurance reimbursements and other recoveries	0	4.7	1.7
Advances to affiliates, net	0	1.6	-0.9
Sales (purchases) of short-term investments	175	(175)	0
Net cash used in investing activities	-671.8	-2757.4	-1180.3
FINANCING ACTIVITIES:
Proceeds from long-term debt, net of issuance costs	346.7	247.2	495.3
Proceeds from borrowings on revolving credit agreement	411.5	1,484	0
Repayment of borrowings on revolving credit agreement	(650)	(692)	0
Payments on note payable	-1.3	0	0
Proceeds from long-term debt - affiliate	200	0	0
Repayment of long-term debt - affiliate	(100)	0	0
Distributions paid	-360.6	-260.5	(205)
Proceeds from sale of common units	326.3	733.6	515.9
Proceeds from sale of class B units	0	686	0
Capital contribution from general partner	6.8	29.2	10.7
Net cash provided by financing activities	179.4	2227.5	816.9
Decrease in cash and cash equivalents	-91.9	-179.6	-81.7
Cash and cash equivalents at beginning of period	137.7	317.3	399
Cash and cash equivalents at end of period	45.8	137.7	317.3

Consolidated Statements of Chan

Consolidated Statements of Changes in Partners Capital (USD $)
In Millions, except Share data	Common Units [Member]	Class B Units [Member]	Subordinated Units [Member]	General Partner [Member]	Accumulated Other Comprehensive Income [Member]	Total
Balance at Dec. 31, 2006	941.8	$0	285.6	22.1	$23	1272.5
Add (deduct):
Net income	157.2	0	63.5	7	0	227.7
Distributions paid	(141)	0	-57.4	-6.6	0	(205)
Sale of common units, net of related transaction costs	515.9	0	0	0	0	515.9
Capital contribution from general partner	0	0	0	10.7	0	10.7
Other comprehensive loss, net of tax	0	0	0	0	-18.8	-18.8
Balance at Dec. 31, 2007	1473.9	0	291.7	33.2	4.2	1,803
Add (deduct):
Net income	207.4	13.7	59.7	13.2	0	294
Distributions paid	(179)	-6.9	-61.9	-12.7	0	-260.5
Sale of common units, net of related transaction costs	713	0	0	0	0	713
Sale of class B units	0	686	0	0	0	686
Conversion of subordinated units to common units	289.5	0	-289.5	0	0	0
Capital contribution from general partner	0	0	0	29.2	0	29.2
Other comprehensive loss, net of tax	0	0	0	0	-19.7	-19.7
Balance at Dec. 31, 2008	2504.8	692.8	0	62.9	-15.5	3,245
Add (deduct):
Net income	128.2	18.2	0	16.3	0	162.7
Distributions paid	-312.7	-27.4	0	-20.5	0	-360.6
Sale of common units, net of related transaction costs	320.2	0	0	0	0	320.2
Capital contribution from general partner	0	0	0	6.8	0	6.8
Other comprehensive loss, net of tax	0	0	0	0	-9.9	-9.9
Balance at Dec. 31, 2009	2640.5	683.6	$0	65.5	-25.4	3364.2

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (USD $)
In Millions	12 Months Ended Dec. 31, 2009	12 Months Ended Dec. 31, 2008	12 Months Ended Dec. 31, 2007
Statement of Income and Comprehensive Income [Abstract]
Net income	162.7	$294	227.7
Other comprehensive (loss) income:
Gain (loss) on cash flow hedges	10.5	-16.7	-9.8
Reclassification adjustment transferred to Net income from cash flow hedges	-16.5	24.9	-7.3
Pension and other postretirement benefits costs	-3.9	-27.9	-1.7
Total comprehensive income	152.8	274.3	208.9

Note 1: Corporate Structure

Note 1: Corporate Structure
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Corporate Structure	Boardwalk Pipeline Partners, LP (the Partnership) is a Delaware limited partnership formed to own and operate the business conducted by its subsidiary, Boardwalk Pipelines, LP (Boardwalk Pipelines), and its subsidiaries, Gulf Crossing Pipeline Company LLC (Gulf Crossing), Gulf South Pipeline Company, LP (Gulf South) and Texas Gas Transmission, LLC (Texas Gas) (together, the operating subsidiaries). As of December 31, 2009, Boardwalk Pipelines Holding Corp. (BPHC), a wholly-owned subsidiary of Loews Corporation (Loews), owns 114.2 million of the Partnerships common units, all 22.9 million of the Partnerships class B units and, through Boardwalk GP, LP (Boardwalk GP), an indirect wholly-owned subsidiary of BPHC, holds the 2% general partner interest and all of the incentive distribution rights (IDRs). The common units, class B units and general partner interest owned by BPHC represent approximately 72% of the Partnerships equity interests, excluding the IDRs, further described in Note 11. The Partnership is traded under the symbol BWP on the New York Stock Exchange (NYSE). Basis of Presentation The accompanying consolidated financial statements of the Partnership were prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). Subsequent events have been evaluated through February 16, 2010, the issuance date of these financial statements.

Note 2: Accounting Policies

Note 2: Accounting Policies
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Accounting Policies	Principles of Consolidation The consolidated financial statements include the Partnerships accounts and those of its wholly-owned subsidiaries, Boardwalk Pipelines, Gulf Crossing, Gulf South and Texas Gas, after elimination of intercompany transactions. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities and the fair values of certain items, including the Partnerships debt and pension and postretirement benefits trust assets. On an ongoing basis, the Partnership evaluates its estimates, including but not limited to those related to bad debts, goodwill, property and equipment and other long-lived assets, property taxes, pensions and other postretirement and postemployment benefits, share-based and other incentive compensation, contingent liabilities, revenues subject to refund and fair value. The Partnership bases its estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results could differ from such estimates. Segment Information The Partnership operates in one reportable segment the operation of interstate natural gas pipeline systems including integrated storage facilities. This segment consists of interstate natural gas pipeline systems which originate in the Gulf Coast region, Oklahoma and Arkansas, and extend north and east through the Midwestern states of Tennessee, Kentucky, Illinois, Indiana and Ohio. Regulatory Accounting The operating subsidiaries are regulated by the Federal Energy Regulatory Commission (FERC). When certain criteria are met, GAAP requires that certain rate-regulated entities account for and report assets and liabilities consistent with the economic effect of the manner in which independent third-party regulators establish rates (regulatory accounting). This basis of accounting is applicable to operations of the Partnerships Texas Gas subsidiary which record certain costs and benefits as regulatory assets and liabilities in order to provide for recovery from or refund to customers in future periods, but is not applicable to operations associated with the Fayetteville and Greenville Laterals project due to rates charged under negotiated rate agreements and Phase III of the Western Kentucky Storage Expansion project due to the regulatory treatment associated with the rates charged under that project. Regulatory accounting is not applicable to the Partnerships Gulf Crossing subsidiary due to discounts under negotiated rate agreements, or Gulf South because competition in its market area has resulted in discounts from the maximum allowable cost-based rates being granted to customers and certain services provided by Gulf South are priced using market-based rates. The Partnership monitors the regulatory and competitive environment in which it operates

Note 3: Commitments and Conting

Note 3: Commitments and Contingencies
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Commitments and Contingencies	Contractual Release In December 2008, the Partnership received notice of dissolution of the Alaskan Northwest Natural Gas Transportation Company which was formed in the 1970s and in which Texas Gas was an inactive investor. Along with the notice of dissolution, Texas Gas received a full release from any obligations associated with its equity method investment. As a result, the Partnership reversed the remainder of its liability for estimated obligations associated with the investment and recognized income of $3.3 million in Miscellaneous other income, net on the Consolidated Statements of Income. The book value of the investment was zero at December 31, 2008. Calpine Energy Services (Calpine) Settlement In the first quarter 2008, the Partnership received a cash payment of approximately $15.3 million as settlement of a claim against Calpine and recorded a net gain of $11.2 million related to the realization of the unrecognized portion of the claim which was reported as Contract settlement gain on the Consolidated Statements of Income. Legal Proceedings Napoleonville Salt Dome Matter Following the December 2003 accidental release of natural gas from storage in a salt dome cavern operated by Gulf South at the Dow Hydrocarbon and Resources, Inc. (Dow Hydrocarbon), Grand Bayou facility in Belle Rose, Louisiana, several suits were filed, including two that were initially filed as class actions. One of the cases initially filed as a class action was settled in 2008. A lawsuit entitled Crystal Aucoin, et al. v. Gulf South Pipeline Company, LP, et al., No. 28,157 was filed on February 12, 2004, in the 23rd Judicial District Court for the Parish of Assumption, State of Louisiana. The suit was initially filed as a class action. The defendants at the trial were Gulf South, Dow Chemical Company and Dow Hydrocarbon (jointly, Dow) and one of Gulf Souths insurers, Oil Insurance Limited (OIL). The plaintiffs voluntarily dismissed their class action allegations on February 2, 2006. Since that time the case has proceeded in the same court as a mass joinder of approximately 1,200 individual claims. The plaintiffs seek damages for alleged inconvenience and emotional distress arising from being forced to drive on a detour around a road closed due to the gas release. A trial was held in August 2008 on damages for a sample group of 23 plaintiffs. In January 2009, the court awarded damages to these plaintiffs of less than $0.1 million in the aggregate. Gulf South and the other defendants have appealed the ruling. Pursuant to an agreement among the defendants, Gulf South is responsible for one half of the judgment, subject to final determination of Gulf Souths claim for indemnification from Dow. On September 29, 2005, OIL filed suit against Dow, No. 29,217, in the 23rd Judicial District Court for the Parish of Assumption, State of Louisiana, Oil Insurance Limited v. Dow Chemical Company, et al. OIL seeks indemnification from Dow Hydrocarbon for amounts of insurance paid to Gulf South. Dow has filed a demand against OIL and a third-party claim against Gulf South. Dows allegations against Gulf South include contractual violations and liability

Note 4: Property, Plant and Equ

Note 4: Property, Plant and Equipment
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Property, Plant and Equipment	In 2009, the Partnership placed in service its Gulf Crossing Project and Fayetteville and Greenville Laterals and the remaining compression facilities associated with its Southeast Expansion project. Additionally, the Partnership placed into service the remaining portion of Phase III of the Western Kentucky Storage Expansion project. As a result, approximately $2.5 billion was transferred from work in progress to plant. The assets will generally be depreciated over a term of 35 years. The following table presents the Partnerships PPE as of December 31, 2009 and 2008 (in millions): Category 2009 Class Amount Weighted-Average Useful Lives (Years) 2008 Class Amount Weighted-Average Useful Lives (Years) Depreciable plant: Transmission $ 6,040.8 37 $ 3,537.2 39 Storage 275.1 45 248.9 47 Gathering 91.6 19 91.4 19 General 93.5 16 88.3 15 Rights of way and other 34.8 28 36.9 24 Total utility depreciable plant 6,535.8 37 4,002.7 39 Non-depreciable: Construction work in progress 231.4 2,196.4 Storage 55.4 61.6 Land 15.3 13.3 Other 17.3 8.6 Total other 319.4 2,279.9 Total PPE 6,855.2 6,282.6 Less:accumulated depreciation 577.3 382.4 Total PPE, net $ 6,277.9 $ 5,900.2 The non-transmission assets have weighted-average useful lives of 35 years as of December 31, 2009 and 2008 and depreciable asset values of $495.0 million and $465.5 million as of December 31, 2009 and 2008. The non-depreciable assets were not included in the calculation of the weighted-average useful lives. The Partnership holds undivided interests in certain assets, including the Bistineau storage facility of which the Partnership owns 92%, the Mobile Bay Pipeline of which the Partnership owns 64% and offshore and other assets, comprised of pipeline and gathering assets in which the Partnership holds various ownership interests. The proportionate share of investment associated with these interests has been recorded as PPE on the balance sheets. The Partnership records its portion of direct operating expenses associated with the assets in Operation and maintenance expense. The following table presents the gross PPE investment and related accumulated depreciation for the Partnerships undivided interests as of December 31, 2009 and 2008 (in millions): 2009 2008 Gross PPE Investment Accumulated Depreciation Gross PPE Investment Accumulated Depreciation Bistineau storage $ 58.0 $ 8.7 $ 57.1 $ 6.9 Mobile Bay Pipeline 11.3 1.7 11.2 1.4 Offshore and other assets 19.2 11.9 19.0 11.5 Total $ 88.5 $ 22.3 $ 87.3 $ 19.8 Asset Impairments Non-Contig

Note 5: Asset Retirement Obliga

Note 5: Asset Retirement Obligations (ARO)
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Asset Retirement Obligations (ARO)	Pursuant to federal regulations, the Partnership has a legal obligation to cut and purge any pipeline that will remain in place after abandonment and to remove offshore platforms after the related gas flows have ceased. The Partnership has identified and recorded legal obligations associated with the abandonment of offshore pipeline assets and certain onshore facilities as well as abatement of asbestos consisting of removal, transportation and disposal when removed from certain compressor stations and meter station buildings. Legal obligations exist for the main pipeline and certain other Partnership assets; however, the fair value of the obligations cannot be determined because the lives of the assets are indefinite and therefore cash flows associated with retirement of the assets cannot be estimated with the degree of accuracy necessary to establish a liability for the obligations. The following table summarizes the aggregate carrying amount of the Partnerships ARO (in millions): 2009 2008 Balance at beginning of year $ 18.0 $ 16.1 Liabilities recorded 2.1 1.6 Liabilities settled (2.9 ) (0.5 ) Accretion expense 0.8 0.8 Balance at end of year $ 18.0 $ 18.0 The Partnership believes that an ARO exists for the Texas Gas corporate office building constructed in Owensboro, Kentucky, in 1962. Under the legal requirements enacted by the EPA during 1973, Texas Gas became legally obligated to dismantle and remove the asbestos from its office building at the end of its useful life, estimated to range from 2112 to 2162. The Partnership believes that the spray-applied asbestos can be maintained in place indefinitely, if undisturbed by following written maintenance procedures. The Partnership believes that the fair value of any liability relating to future remediation is not material to its financial position, results of operations and cash flows and that any costs incurred for this remediation would be recoverable in its rates. For the Partnerships operations where regulatory accounting is applicable, depreciation rates for PPE are comprised of two components. One component is based on economic service life (capital recovery) and the other is based on estimated costs of removal (as a component of negative salvage) which is collected in rates and does not represent an existing legal obligation. The Partnership has reflected $47.0 million and $45.6 million as of December 31, 2009 and 2008, in the accompanying Consolidated Balance Sheets as Provision for other asset retirement related to the estimated cost of removal collected in rates.

Note 6: Regulatory Assets and L

Note 6: Regulatory Assets and Liabilities
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Regulatory Assets and Liabilities	The amounts recorded as regulatory assets and liabilities in the Consolidated Balance Sheets as of December 31, 2009 and 2008, are summarized in the table below. The table also includes amounts related to unamortized debt expense and unamortized discount on long-term debt. While these amounts are not regulatory assets and liabilities, they are a critical component of the embedded cost of debt financing utilized in the Texas Gas rate proceedings. The tax effect of the equity component of AFUDC represents amounts recoverable from rate payers for the tax effects created prior to the 2005 change in the tax status of Boardwalk Pipelines and its election to be taxed as a partnership. Certain amounts in the table are reflected as a negative, or a reduction, to be consistent with the regulatory books of account. The period of recovery for the regulatory assets included in rates varies from one to nineteen years. The remaining period of recovery for regulatory assets not yet included in rates would be determined in future rate proceedings. None of the regulatory assets shown below were earning a return as of December 31, 2009 and 2008 (in millions): 2009 2008 Regulatory Assets: Pension $ 10.6 $ 9.5 Tax effect of AFUDC equity 5.5 5.9 Unamortized debt expense and premium on reacquired debt 8.9 10.0 Postretirement benefits other than pension 5.4 5.4 Fuel tracker 0.6 - Total regulatory assets $ 31.0 $ 30.8 Regulatory Liabilities: Cashout and fuel tracker $ 1.9 $ 2.3 Provision for other asset retirement 47.0 45.6 Unamortized discount on long-term debt (2.9 ) (3.5 ) Postretirement benefits other than pension 17.6 4.7 Other 0.5 - Total regulatory liabilities $ 64.1 $ 49.1

Note 7: Financing

Note 7: Financing
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Financing	Long-Term Debt The following table presents all long-term debt issues outstanding as of December 31, 2009 and 2008 (in millions): 2009 2008 Notes and Debentures: Boardwalk Pipelines 5.88% Notes due 2016 $ 250.0 $ 250.0 5.20% Notes due 2018 185.0 185.0 5.50% Notes due 2017 300.0 300.0 5.75% Notes due 2019 350.0 - Gulf South 6.30% Notes due 2017 275.0 275.0 5.75% Notes due 2012 225.0 225.0 5.05% Notes due 2015 275.0 275.0 Texas Gas 7.25% Debentures due 2027 100.0 100.0 4.60% Notes due 2015 250.0 250.0 5.50% Notes due 2013 250.0 250.0 Total notes and debentures 2,460.0 2,110.0 Revolving Credit Facility: Boardwalk Pipelines 135.0 285.0 Gulf South 228.5 317.0 Texas Gas 190.0 190.0 Total revolving credit facility 553.5 792.0 Subordinated Loan Agreement with BPHC 100.0 - 3,113.5 2,902.0 Less: unamortized debt discount (13.5 ) (12.6 ) Total Long-Term Debt $ 3,100.0 $ 2,889.4 Maturities of the Partnerships long-term debt for the next five years and in total thereafter are as follows (in millions): 2010 - 2011 - 2012 $ 878.5 2013 250.0 2014 - Thereafter 1,985.0 Total long-term debt $ 3,113.5 Notes and Debentures For the years ended December 31, 2009, 2008 and 2007, the Partnership completed the following debt issuances, the proceeds of which were used to directly and indirectly fund the Partnerships expansion projects through the reduction of borrowings under its Subordinated Loan Agreement and revolving credit facility, both described below (in millions, except interest rate percentage): Date of Issuance Issuing Subsidiary Amount of Issuance Purchaser Discounts and Expenses Net Proceeds Interest Rate Maturity Date Interest Payable August 2009 Boardwalk Pipelines $ 350.0 $ 3.3 $ 346.7 5.75 % September 15, 2019 March 15 and September 15 March 2008 Texas Gas 250.0 2.8 247.2 5.50 % April 1, 2013 April 1 and October 1 August 2007 Gulf South 225.0 2.0 223.0 5.75 % August 15, 2012 February 15 and August 15 August 2007 Gulf South 275.0 2.7 272.3 6.30 % August 15, 2017 February 15 and August 15 The Partnerships notesand debentures are redeemable, in whole or in part, at the Partnerships option at any time, at redemption prices equal to the greater of 100% of the principal amount of the notes to be redeemed or a make whole redemption price based on the remaining scheduled payments of principal and interest discounted to the date of redemption at a rate equal to the Treasury rate plus 20 to 50 basis points depending upon the particular issue of notes, plus accrued and unpaid interest, if any.Other cus

Note 8: Derivatives

Note 8: Derivatives
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Derivative	Subsidiaries of the Partnership use futures, swaps, and option contracts (collectively, derivatives) to hedge exposure to natural gas commodity price risk related to the future operational sales of natural gas and cash for fuel reimbursement where customers pay cash for the cost of fuel used in providing transportation services as opposed to having fuel retained in kind. This price risk exposure includes approximately $2.3 million and $0.2 million of gas stored underground at December 31, 2009 and 2008, which the Partnership owns and carries on its Consolidated Balance Sheets as current Gas stored underground, and 3.3 billion cubic feet (Bcf) of gas with a book value of $7.5 million that has become available for sale as a result of Phase III of the Western Kentucky Storage Expansion. At December 31, 2009, approximately 5.6 Bcf of anticipated future sales of natural gas and cash for fuel reimbursement were hedged with derivatives having settlement dates in 2010. The derivatives qualify for cash flow hedge accounting and are designated as such. The Partnership has also periodically used derivatives as cash flow hedges of interest rate risk in anticipation of debt offerings. All of the Partnerships currently outstanding derivatives are reported at fair value based on New York Mercantile Exchange (NYMEX) quotes for natural gas futures and options. The NYMEX quotes are deemed to be observable inputs in an active market for similar assets and liabilities and are considered Level 2 inputs for purposes of fair value disclosures. The Partnership has not changed its valuation techniques or inputs during the reporting period. The fair values of derivatives existing as of December 31, 2009 and 2008, were included in the following captions in the Consolidated Balance Sheets (in millions): Asset Derivatives Liability Derivatives December 31, December 31, 2009 2008 2009 2008 Balance sheet location Fair Value Balance sheet location Fair Value Balance sheet location Fair Value Balance sheet location Fair Value Derivatives designated as hedging instruments Commodity contracts Other current assets $ 6.2 Other current assets $ 10.5 Other current liabilities $ - Other current liabilities $ 0.1 Other assets - Other assets 3.7 Other liabilities - Other liabilities - $ 6.2 $ 14.2 $ - $ 0.1 The changes in fair values of the derivatives designated as cash flow hedges are expected to, and do, have a high correlation to changes in value of the anticipated transactions. Each reporting period the Partnership measures the effectiveness of the cash flow hedge contracts. To the extent the changes in the fair values of the hedge contracts do not effectively offset the changes in the estimated cash flows of the anticipated transactions, the ineffective portion of the hedge contracts is currently recognized in earnings. If it becomes probable that the anticipated transactions will not occur, hedge accounting would be terminated and changes in the

Note 9: Employee Benefits

Note 9: Employee Benefits
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Employee Benefits	Defined Benefit Retirement Plans Texas Gas employees hired before November 1, 2006, are covered under a non-contributory, defined benefit pension plan (Pension Plan). The Texas Gas Supplemental Retirement Plan (SRP) provides pension benefits for the portion of an eligible employees pension benefit under the Pension Plan that becomes subject to compensation limitations under the Internal Revenue Code. Effective November 1, 2006, the Pension Plan was closed to new participants and new employees are provided benefits under a defined contribution money purchase plan. Collectively, the Partnership refers to the Pension Plan and the SRP as Retirement Plans. The Partnership uses a measurement date of December 31 for its Retirement Plans. As a result of the Texas Gas rate case settlement in 2006, the Partnership is required to fund the amount of annual net periodic pension cost associated with its Pension Plan, including a minimum of $3.0 million which is the amount included in rates. In 2009 and 2008, the Partnership funded $6.0 million and $4.6 million to the Pension Plan and expects to fund approximately $6.0 million to the plan in 2010. The Partnership does not anticipate that any Pension Plan assets will be returned to the Partnership during 2010. Through December 31, 2009, no funding has been provided for the SRP other than the payment of benefits under the plan, and the Partnership does not expect to fund this plan in the future until such time as benefits are paid. The Partnership recognizes in expense each year the actuarially determined amount of net periodic pension cost associated with its Retirement Plans, including a minimum amount of $3.0 million related to its Pension Plan, in accordance with its most recent rate case settlement. Texas Gas is permitted to seek future rate recovery for amounts of annual Pension Plan costs in excess of $6.0 million and is precluded from seeking future recovery of annual Pension Plan costs between $3.0 and $6.0 million. As a result, the Partnership would recognize a regulatory asset for amounts of annual Pension Plan costs in excess of $6.0 million and would reduce its regulatory asset to the extent that any amounts of annual Pension Plancosts are less than $3.0 million. Annual Pension Plan costs between $3.0 million and $6.0 million will be charged to expense. Postretirement Benefits Other Than Pension (PBOP) Texas Gas provides postretirement medical benefits and life insurance to retired employees who were employed full time, hired prior to January 1, 1996, and have met certain other requirements. The Partnership did not make contributions to the PBOP plan in 2009. The Partnership contributed $0.8 million to the plan in 2008. Due to plan changes regarding benefits available to current and future retirees described below, the PBOP plan is currently in an overfunded status, therefore the Partnership does not expect to make any contributions to the plan in 2010. The Partnership does not anticipate that any plan assets will be returned to the Partnership during 2010. The Partnership uses a measurement date of December 31 for its PBOP plan. Projected Benefit Obligation, Fair Value of As

Note 10: Disposition of Assets

Note 10: Disposition of Assets
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Disposition of Assets	In 2008, as a result of Phase III of the Western Kentucky Storage Expansion approximately 5.1 Bcf of gas stored underground with a book value of $11.8 million was sold, resulting in a gain of $34.4 million. In 2008, the Partnership also completed the sale of its investment in land and coal reserves along the Ohio River in northern Kentucky and southern Indiana for $16.5 million. These assets had no book value at the time of the sale. As a result, the Partnership recorded a gain of $16.5 million related to the sale. The gains were included in Net gain on disposal of operating assets and related contracts in the Consolidated Statements of Income.

Note 11: Net Income per Limited

Note 11: Net Income per Limited Partner Unit and Cash Distributions
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Net Income per Limited Partner Unit and Cash Distributions	Cash Distributions The Partnerships cash distribution policy requires that the Partnership distribute to its various ownership interests on a quarterly basis all of its available cash, as defined in its partnership agreement. IDRs, which represent a limited partner ownership interest and are currently held by the Partnerships general partner, represent the contractual right to receive an increasing percentage of quarterly distributions of available cash as follows: Total Quarterly Distribution MarginalPercentage Interestin Distributions Target Amount Limited Partner Unitholders (1) General Partner First Target Distribution upto$0.4025 98% 2% Second Target Distribution above$0.4025upto$0.4375 85% 15% Third Target Distribution above $0.4375 up to $0.5250 75% 25% Thereafter above $0.5250 50% 50% (1) The class B unitholders participate in distributions on a pari passu basis with the Partnerships common units up to $0.30 per unit per quarter. The class B units do not participate in quarterly distributions above $0.30 per unit. The class B units began sharing in income allocations and distributions with respect to the third quarter 2008. The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common, subordinated and class B units and the 2% general partner interest and IDRs held by its general partner as follows (in millions, except distribution per unit): Payment Date Distribution per Unit Amount Paid to Common and Subordinated Unitholders (1) Amount Paid to Class B Unitholder Amount Paid to General Partner (Including IDRs) (2) November 9, 2009 $ 0.495 $ 84.0 $ 6.8 $ 5.9 August 10, 2009 0.490 79.2 6.9 5.2 May 11, 2009 0.485 75.1 6.8 4.9 February 23, 2009 0.480 74.4 6.9 4.5 November 10, 2008 0.475 63.6 6.9 3.7 August 11, 2008 0.470 62.8 - 3.4 May 12, 2008 0.465 57.6 - 2.9 February 25, 2008 0.460 56.9 - 2.7 November 12, 2007 0.450 52.3 - 2.2 August 13, 2007 0.440 51.1 - 1.7 May 14, 2007 0.430 50.1 - 1.5 February 27, 2007 0.415 44.9 - 1.2 (1) All of the 33.1 million subordinated units converted to common units on a one-for-one basis two days following the November 10, 2008 distribution. (2) In 2009, 2008 and 2007, the Partnership paid $13.3 million, $7.5 million and $2.5 million in distributions on behalf of IDRs. In February 2010, the Partnership declared a quarterly cash distribution to unitholders of record of $0.50 per unit. Net Income per Unit For purposes of calculating net income per unit, net income for the current period is reduced by the amount of available cash that will be distributed with respect to that period. Any residual amount representing undistributed net income (or loss) is

Note 12: Income Tax

Note 12: Income Tax
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Income Tax	The Partnership is not a taxable entity for federal income tax purposes. As such, it does not directly pay federal income tax. The Partnerships taxable income or loss, which may vary substantially from the net income or loss reported in the Condensed Consolidated Statements of Income, is includable in the federal income tax returns of each partner. The aggregate difference in the basis of the Partnerships net assets for financial and income tax purposes cannot be readily determined as the Partnership does not have access to the information about each partners tax attributes. The subsidiaries of the Partnership directly incur some income-based state taxeswhich are presented in Income tax expense on the Consolidated Statements of Income. Following is a summary of the provision for income taxes for the periods ended December 31, 2009, 2008 and 2007 (in millions): For the Year Ended December 31, 2009 2008 2007 Current expense: State $ 0.2 $ 0.7 $ 0.8 Total 0.2 0.7 0.8 Deferred provision: State 0.1 0.3 - Total 0.1 0.3 - Income taxes $ 0.3 $ 1.0 $ 0.8 The Partnerships tax years 2006 through 2008 remain subject to examination by the Internal Revenue Service and the states in which it operates. There were no differences between the provision at the statutory rate to the income tax provision at December 31, 2009, 2008 and 2007. As of December 31, 2009 and 2008, there were no significant deferred income tax assets or liabilities.

Note 13: Financial Instruments

Note 13: Financial Instruments
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Financial Instruments	The following methods and assumptions were used in estimating the Partnerships fair value disclosures for financial instruments: Cash and Cash Equivalents: For cash and short-term financial assets and liabilities, the carrying amount is a reasonable estimate of fair value due to the short maturity of those instruments. Short-term investments: In December 2008, the Partnershipinvested a portion of its undistributed cash in U.S. Government securities, primarily Treasury notes, under repurchase agreements. Generally, the Partnership has engaged in overnight repurchase transactions where purchased securities are sold back to the counterparty the following business day. Pursuant to the master repurchase agreements, the Partnership takes actual possession of the purchased securities. In the event of default by the counterparty under the agreement, the repurchase would be deemed immediately to occur and the Partnership would be entitled to sell the securities in the open market, or give the counterparty credit based on the market price on such date, and apply the proceeds (or deemed proceeds) to the aggregate unpaid repurchase amounts and any other amounts owed by the counterparty. At December 31, 2008, the portfolio consisted of $175.0 million of Treasury securities with original maturities in August 2009, held pursuant to overnight repurchase agreements. The amount invested under repurchase agreements was stated at fair value based on quoted market prices for the securities.The Partnership had no short-term investments at December 31, 2009. Long-Term Debt:All of the Partnerships long-term debt is publicly tradedexcept for debt issued by Gulf South, the debt issued by Texas Gas in March 2008, the revolving credit facility and the Subordinated Loans categorized as Long-term debt - affiliate. The estimated fair value of the Partnerships publicly traded debt is based on quoted market prices at December 31, 2009 and 2008. The fair market value of the debt that is not publicly traded is based on market prices of similar debt at December 31, 2009 and 2008. Long-Term Debt - Affiliate:Borrowings under the Subordinated Loans were completed in 2009. The estimated fair value is based on market prices of similar debt, adjusted for the affiliated nature of the transaction. Note 7 contains more information regarding the Subordinated Loans. The carrying amount and estimated fair values of the Partnerships financial instruments as of December 31, 2009 and 2008 were as follows (in millions): 2009 2008 Financial Assets Carrying Amount Fair Value Carrying Amount Fair Value Cash and cash equivalents $ 45.8 $ 45.8 $ 137.7 $ 137.7 Short-term investments - - 175.0 175.0 Financial Liabilities Long-term debt $ 3,000.0 $ 3,060.6 $ 2,889.4 $ 2,655.3 Long-term debt affiliate 100.0 108.0 - -

Note 14: Accumulated Other Comp

Note 14: Accumulated Other Comprehensive Income (Loss)
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Accumulated Other Comprehensive Income (Loss)	The following table shows the components of Accumulated other comprehensive loss, net of tax which is included in Partners Capital on the Consolidated Balance Sheets (in millions): For the Year Ended December 31, 2009 2008 Loss on cash flow hedges, net of tax $ (6.7 ) $ (0.7 ) Deferred components of net periodic benefit cost, net of tax (18.7 ) (14.8 ) Total Accumulated other comprehensive loss, net of tax $ (25.4 ) $ (15.5 ) In 2010, the Partnership expects to recognizein earnings approximately $10.7 million of the amounts included in the table.This amountis comprised ofincreases toearningsof $5.3 million related to cash flow hedges and $5.4 million related tonet periodic benefit cost.

Note 15: Credit Risk

Note 15: Credit Risk
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Credit Risk	Major Customers Operating revenues received from the Partnerships major customer (in millions) and the percentage of total operating revenues earned from that customer were: For the Year Ended December 31, 2009 2008 2007 Customer Revenue % Revenue % Revenue % Devon Energy Production Company, LP $ 102.6 11 % $ 47.2 6 % $ 16.8 3 % Atmos Energy 53.7 6 % 73.0 9 % 63.9 10 % Gas Loaned to Customers Natural gas price volatility can cause changes in credit risk related to gas loaned to customers. As of December 31, 2009, the amount of gas owed to the operating subsidiaries due to gas imbalances and gas loaned under PAL agreements was approximately 14.9 TBtu. Assuming an average market price during December 2009 of $5.36 per MMBtu, the market value of that gas was approximately $79.9 million. As of December 31, 2008, the amount of gas owed to the operating subsidiaries due to gas imbalances and gas loaned under PAL agreements was approximately 34.4 TBtu. Assuming an average market price during December 2008 of $5.85 per MMBtu, the market value of this gas at December 31, 2008, would have been approximately $201.2 million. If any significant customer should have credit or financial problems resulting in a delay or failure to repay the gas owed to the operating subsidiaries, it could have a material adverse effect on the Partnerships financial condition, results of operations and cash flows.

Note 16: Related Party Transact

Note 16: Related Party Transactions
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Related Party Transactions	Loews provides a variety of corporate services to the Partnership and its subsidiaries under services agreements which have been operative since 2005. Services provided by Loews include, among others, information technology, tax, risk management, internal audit and corporate development services. Loews charged $17.1 million, $14.5 million and $12.1 million for the years ended December 31, 2009, 2008 and 2007 to the Partnership for performing these services, plus related expenses and allocated overhead. Distributions paid related to limited partner units held by BPHC and the 2% general partner interest and IDRs held by Boardwalk GP were $264.2 million, $181.1 million and $156.4 million for the years ended December 31, 2009, 2008 and 2007. In 2009, Boardwalk Pipelines entered into a $200.0 million Subordinated Loan Agreement with BPHC and the Partnership issued and sold 6.7 million common units to BPHC. Note 7 contains more information regarding these transactions.

Note 17: Supplemental Disclosur

Note 17: Supplemental Disclosure of Cash Flow Information
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Supplemental Disclosure of Cash Flow Information	(in millions): For the Year Ended December 31, 2009 2008 2007 Cash paid during the period for: Interest (net of amount capitalized) $ 124.4 $ 42.8 $ 46.1 Income taxes, net 0.2 0.8 0.3 Non-cash adjustments: Accounts payable and PPE $ 173.2 $ 86.8 $ 175.8 Accrued registration rights costs 6.1 20.6 -

Note 18: Selected Quarterly Fin

Note 18: Selected Quarterly Financial Data (Unaudited)
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Selected Quarterly Financial Data (Unaudited)	The following tables summarize selected quarterly financial data for 2009 and 2008 for the Partnership (in millions, except for earnings per unit): 2009 For the Quarter Ended: December 31 September 30 June 30 March 31 Operating revenues $ 279.0 $ 205.4 $ 201.4 $ 223.4 Operating expenses 170.7 151.0 148.2 144.8 Operating income 108.3 54.4 53.2 78.6 Interest expense, net 36.8 35.7 32.9 26.5 Other (income) expense (0.2 ) - - (0.2 ) Income before income taxes 71.7 18.7 20.3 52.3 Income taxes (benefit) 0.1 (0.1 ) - 0.3 Net income $ 71.6 $ 18.8 $ 20.3 $ 52.0 Net income per unit: Common units $ 0.37 $ 0.10 $ 0.12 $ 0.29 Class B units $ 0.17 $ (0.10 ) $ (0.09 ) $ 0.11 Total Comprehensive Income $ 73.6 $ 11.7 $ 12.3 $ 55.2 2008 For the Quarter Ended: December 31 September 30 June 30 March 31 Operating revenues $ 205.6 $ 191.6 $ 190.3 $ 197.3 Operating expenses 130.3 102.8 109.3 95.8 Operating income 75.3 88.8 81.0 101.5 Interest expense, net 10.9 8.6 17.3 18.0 Other (income) expense (3.4 ) 6.3 (1.2 ) (4.9 ) Income before income taxes 67.8 73.9 64.9 88.4 Income taxes 0.2 0.3 0.2 0.3 Net income $ 67.6 $ 73.6 $ 64.7 $ 88.1 Net income per unit: Common units $ 0.46 (1) $ 0.47 $ 0.50 $ 0.68 Class B units $ 0.20 (1) $ 0.30 $ - $ - Subordinated units $ (0.10 ) (1) $ 0.47 $ 0.46 $ 0.68 Total Comprehensive Income $ 55.4 $ 100.3 $ 56.5 $ 62.1 (1) As discussed in Note 11, in the first quarter 2009, the Partnership changed the method used in computing its net income per unit due to a change in GAAP.As a result, the net income per unit for the quarter ended December 31, 2008, has been retrospectively adjusted from $0.40 per common and subordinated unit to $0.46 per common unit and $(0.10) per subordinated unit. Additionally, net income per unit for the quarter ended December 31, 2008, was retrospectively adjusted from $0.30 per class B unit to $0.20 per class B unit.

Note 19: Guarantee of Securitie

Note 19: Guarantee of Securities of Subsidiaries
	12 Months Ended Dec. 31, 2009 USD / shares
Notes to Financial Statements [Abstract]
Guarantee of Securities of Subsidiaries	The Partnerships Boardwalk Pipelines subsidiary (subsidiary issuer) has issued securities which have been fully and unconditionally guaranteed by the Partnership (parent guarantor). The Partnership's subsidiaries have no significant restrictions on their ability to pay distributions or make loans to the Partnership except as noted in the debt covenants and have no restricted assets at December 31, 2009 and 2008. Note 7 contains additional information regarding the Partnership's debt and related covenants. The Partnership has provided the followingcondensed consolidating financial information, which was not previously presented, in accordance with Regulation S-X Rule 3-10, Financial Statements of Guarantors and Issuers of Guaranteed Securities Registered or Being Registered. Condensed Consolidating Balance Sheets as of December 31, 2009 (in millions) Assets Parent Guarantor Subsidiary Issuer Non-guarantor Subsidiaries Eliminations Consolidated Boardwalk Pipeline Partners, LP Cash $ - $ 45.6 $ 0.2 $ - $ 45.8 Receivables - - 137.9 (28.9 ) 109.0 Gas stored underground - - 2.1 - 2.1 Prepayments - - 10.1 - 10.1 Advances to affiliates - 128.0 - (128.0 ) - Other current assets 0.3 - 25.2 (1.6 ) 23.9 Total current assets 0.3 173.6 175.5 (158.5 ) 190.9 Investment in consolidated subsidiaries 754.9 4,592.2 - (5,347.1 ) - Property, plant and equipment, gross 0.6 - 6,854.6 - 6,855.2 Lessaccumulated depreciation and amortization (0.4 ) - (576.9 ) - (577.3 ) Property, plant and equipment, net 0.2 - 6,277.7 - 6,277.9 Other noncurrent assets 0.4 2.1 424.5 - 427.0 Advances to affiliates - noncurrent 2,638.2 121.6 165.8 (2,925.6 ) - Total other assets 2,638.6 123.7 590.3 (2,925.6 ) 427.0 Total Assets $ 3,394.0 $ 4,889.5 $ 7,043.5 $ (8,431.2 ) $ 6,895.8 Liabilities Partners' Capital/MembersEquity Parent Guarantor Subsidiary Issuer Non-guarantor Subsidiaries Eliminations Consolidated Boardwalk Pipeline Partners, LP Payables $ 8.9 $ 0.3 $ 104.5 $ (28.9 ) $ 84.8 Advances from affiliates - - 128.0 (128.0 ) - Other current liabilities 0.3 16.9 150.5 (1.6 ) 166.1 Total current liabilities

Valuation and Qualifying Accoun

Valuation and Qualifying Accounts
	12 Months Ended Dec. 31, 2009 USD / shares
Schedule to Financial Statements [Abstract]
Valuation and Qualifying Accounts	The following table presents those accounts that have a reserve as of December 31, 2009, 2008 and 2007 and are not included in specific schedules herein. These amounts have been deducted from the respective assets on the Consolidated Balance Sheets (in millions): Additions: Description Balance at Beginning of Period Charged to Costs and Expenses Other Additions Deductions Balance at End of Period Allowance for doubtful accounts: 2009 $ 0.3 $ 0.3 $ - $ (0.3 ) $ 0.3 2008 0.4 - (0.1 ) - 0.3 2007 2.6 2.7 (4.7 ) (0.2 ) 0.4 Inventory obsolescence: 2009 $ - $ - $ - $ - $ - 2008 0.1 - - (0.1 ) - 2007 - - 0.1 - 0.1

Document Information

Document Information
	12 Months Ended Dec. 31, 2009 USD / shares
Document Information [Text Block]
Document Type	10-K
Amendment Flag	false
Document Period End Date	2009-12-31

Entity Information

Entity Information (USD $)
	12 Months Ended Dec. 31, 2009	Feb. 10, 2010	Jun. 30, 2009
Entity [Text Block]
Entity Registrant Name	Boardwalk Pipeline Partners, LP
Entity Central Index Key	0001336047
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	Yes
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$1,070,292,000
Entity Common Stock, Shares Outstanding		169,721,916