10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended March 31, 2012

or

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

For the transition period from                    to                     

Commission file number 1-33556

SPECTRA ENERGY PARTNERS, LP

(Exact Name of Registrant as Specified in its Charter)

Delaware	41-2232463
(State or other jurisdiction of incorporation)	(IRS Employer Identification No.)

5400 Westheimer Court

Houston, Texas 77056

(Address of principal executive offices, including zip code)

713-627-5400

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant 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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No  ¨

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

Large accelerated filer  x    Accelerated  filer  ¨    Non-accelerated filer  ¨    Smaller reporting company  ¨

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

At March 31, 2012, there were 96,355,150 Common Units and 1,966,432 General Partner Units outstanding.

SPECTRA ENERGY PARTNERS, LP

FORM 10-Q FOR THE QUARTER ENDED

March 31, 2012

INDEX

		Page
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)		4
	Condensed Consolidated Statements of Operations for the three months ended March 31, 2012 and 2011		4
	Condensed Consolidated Statements of Comprehensive Income for the three months ended March 31, 2012 and 2011		5
	Condensed Consolidated Balance Sheets as of March 31, 2012 and December 31, 2011		6
	Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2012 and 2011		8
	Condensed Consolidated Statements of Partners’ Capital for the three months ended March 31, 2012 and 2011		9
	Notes to Condensed Consolidated Financial Statements		10
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		17
Item 3.	Quantitative and Qualitative Disclosures about Market Risk		24
Item 4.	Controls and Procedures		24
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings		26
Item 1A.	Risk Factors		26
Item 6.	Exhibits		26
	Signatures		28

2

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based on management’s beliefs and assumptions. These forward-looking statements are identified by terms and phrases such as: anticipate, believe, intend, estimate, expect, continue, should, could, may, plan, project, predict, will, potential, forecast, and similar expressions. Forward-looking statements involve risks and uncertainties that may cause actual results to be materially different from the results predicted. Factors that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to:

• state and federal legislative and regulatory initiatives that affect cost and investment recovery, have an effect on rate structure, and affect the speed at and degree to which competition enters the natural gas industries;

• outcomes of litigation and regulatory investigations, proceedings or inquiries;

• weather and other natural phenomena, including the economic, operational and other effects of hurricanes and storms;

• the timing and extent of changes in interest rates;

• general economic conditions, including the risk of a prolonged economic slowdown or decline, or the risk of delay in a recovery, which can affect the long-term demand for natural gas and related services;

• potential effects arising from terrorist attacks and any consequential or other hostilities;

• changes in environmental, safety and other laws and regulations;

• the development of alternative energy resources;

• results of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general market and economic conditions;

• increases in the cost of goods and services required to complete capital projects;

• growth in opportunities, including the timing and success of efforts to develop domestic pipeline, storage, gathering and other related infrastructure projects and the effects of competition;

• the performance of natural gas transmission, storage and gathering facilities;

• the extent of success in connecting natural gas supplies to transmission and gathering systems and in connecting to expanding gas markets;

• the effects of accounting pronouncements issued periodically by accounting standard-setting bodies;

• conditions of the capital markets during the periods covered by these forward-looking statements; and

• the ability to successfully complete merger, acquisition or divestiture plans; regulatory or other limitations imposed as a result of a merger, acquisition or divestiture; and the success of the business following a merger, acquisition or divestiture.

In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than Spectra Energy Partners, LP has described. Spectra Energy Partners, LP undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

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PART I. FINANCIAL INFORMATION

Item 1. Financial Statements.

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In millions, except per-unit amounts)

	Three Months Ended March 31,
	2012		2011
Operating Revenues
Transportation of natural gas	$	56.2	$	44.0
Storage of natural gas and other		5.7		7.2
Total operating revenues		61.9		51.2
Operating Expenses
Operating, maintenance and other		15.8		15.0
Depreciation and amortization		9.3		7.8
Property and other taxes		3.7		3.3
Total operating expenses		28.8		26.1
Operating Income		33.1		25.1
Other Income and Expenses
Equity in earnings of unconsolidated affiliates		27.4		27.8
Other income and expenses, net		—		0.5
Total other income and expenses		27.4		28.3
Interest Income		—		0.1
Interest Expense		7.7		4.2
Earnings Before Income Taxes		52.8		49.3
Income Tax Expense		0.4		0.4
Net Income	$	52.4	$	48.9
Calculation of Limited Partners’ Interest in Net Income:
Net income	$	52.4	$	48.9
Less:
General partner’s interest in net income		6.5		4.3
Limited partners’ interest in net income	$	45.9	$	44.6
Weighted-average limited partner units outstanding—basic and diluted		96.3		89.2
Net income per limited partner unit—basic and diluted	$	0.48	$	0.50
Distributions paid per limited partner unit during the periods presented	$	0.475	$	0.45

See Notes to Condensed Consolidated Financial Statements.

4

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In millions)

	Three Months     Ended March 31,
	2012			2011
Net Income	$	52.4		$	48.9
Other comprehensive income Reclassification of cash flow hedges into earnings		(0.1	)		1.0
Comprehensive Income	$	52.3		$	49.9

See Notes to Condensed Consolidated Financial Statements.

5

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)

	March 31, 2012		December 31, 2011
ASSETS
Current Assets
Cash and cash equivalents	$	3.1	$	0.8
Receivables, net		26.9		30.3
Other		7.5		10.5
Total current assets		37.5		41.6
Investments and Other Assets
Investments in unconsolidated affiliates		734.2		727.2
Goodwill and other		461.8		461.8
Total investments and other assets		1,196.0		1,189.0
Property, Plant and Equipment
Cost		1,443.3		1,439.3
Less accumulated depreciation and amortization		243.1		234.1
Net property, plant and equipment		1,200.2		1,205.2
Regulatory Assets and Deferred Debits		20.6		21.1
Total Assets	$	2,454.3	$	2,456.9

See Notes to Condensed Consolidated Financial Statements.

6

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)

	March 31, 2012		December 31, 2011
LIABILITIES AND PARTNERS’ CAPITAL
Current Liabilities
Accounts payable	$	8.7	$	20.7
Taxes accrued		6.4		7.1
Note payable—affiliates		23.5		30.5
Current maturities of long-term debt		150.0		150.0
Commercial paper		40.0		27.0
Other		14.3		10.6
Total current liabilities		242.9		245.9
Long-term Debt		499.5		499.4
Deferred Credits and Other Liabilities
Deferred income taxes		8.3		8.0
Other		5.5		5.9
Total deferred credits and other liabilities		13.8		13.9
Commitments and Contingencies
Partners’ Capital
Common units (96.3 million units issued and outstanding at March 31, 2012 and December 31, 2011)		1,653.6		1,653.6
General partner units (2.0 million units issued and outstanding at March 31, 2012 and December 31, 2011)		40.1		39.6
Accumulated other comprehensive income		4.4		4.5
Total partners’ capital		1,698.1		1,697.7
Total Liabilities and Partners’ Capital	$	2,454.3	$	2,456.9

See Notes to Condensed Consolidated Financial Statements.

7

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In millions)

	Three Months Ended March 31,
	2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	52.4		$	48.9
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		9.7			7.8
Deferred income tax expense		0.4			0.3
Equity in earnings of unconsolidated affiliates		(27.4	)		(27.8	)
Distributions received from unconsolidated affiliates		24.3			24.7
Other		(1.9	)		3.7
Net cash provided by operating activities		57.5			57.6
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures		(5.3	)		(16.8	)
Investment expenditures		(9.1	)		(5.9	)
Distributions received from unconsolidated affiliates		5.0			—
Purchases of available-for-sale securities		—			(548.3	)
Proceeds from sales and maturities of available-for-sale securities		—			576.4
Other		—			9.5
Net cash provided by (used in) investing activities		(9.4	)		14.9
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt		—			(36.6	)
Net increase in revolving credit facility borrowings		—			13.0
Net increase in commercial paper		13.0			—
Proceeds from notes payable—affiliates		—			6.5
Payments on notes payable—affiliates		(7.0	)		(10.0	)
Distributions to partners		(51.8	)		(43.4	)
Net cash used in financing activities		(45.8	)		(70.5	)
Net increase in cash and cash equivalents		2.3			2.0
Cash and cash equivalents at beginning of period		0.8			27.4
Cash and cash equivalents at end of period	$	3.1		$	29.4
Supplemental Disclosures
Property, plant and equipment noncash accruals	$	1.7		$	1.1

See Notes to Condensed Consolidated Financial Statements.

8

SPECTRA ENERGY PARTNERS, LP

CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL

(Unaudited)

(In millions)

	Partners’ Capital						Accumulated Other Comprehensive Income (Loss)			Total
	Common			General Partner
December 31, 2011	$	1,653.6		$	39.6		$	4.5		$	1,697.7
Net income		45.9			6.5			—			52.4
Reclassification of cash flow hedges into earnings		—			—			(0.1	)		(0.1	)
Attributed deferred tax expense		(0.1	)		—			—			(0.1	)
Distributions to partners		(45.8	)		(6.0	)		—			(51.8	)
March 31, 2012	$	1,653.6		$	40.1		$	4.4		$	1,698.1
December 31, 2010	$	1,458.7		$	32.9		$	2.8		$	1,494.4
Net income		44.6			4.3			—			48.9
Reclassification of cash flow hedges into earnings		—			—			1.0			1.0
Distributions to partners		(40.1	)		(3.3	)		—			(43.4	)
March 31, 2011	$	1,463.2		$	33.9		$	3.8		$	1,500.9

See Notes to Condensed Consolidated Financial Statements.

9

SPECTRA ENERGY PARTNERS, LP

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. General

The terms “we,” “our,” “us” and “Spectra Energy Partners” as used in this report refer collectively to Spectra Energy Partners, LP and its subsidiaries unless the context suggests otherwise. These terms are used for convenience only and are not intended as a precise description of any separate legal entity within Spectra Energy Partners.

Nature of Operations. Spectra Energy Partners, through its subsidiaries and equity affiliates is engaged in the transportation and gathering of natural gas through interstate pipeline systems that are located in the southeastern quadrant of the United States, and the storage of natural gas in underground facilities that are located in southeast Texas, south central Louisiana and southwest Virginia.

Basis of Presentation. The Condensed Consolidated Financial Statements include our accounts and those of our majority-owned subsidiaries where we have control. These interim financial statements should be read in conjunction with the consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2011, and reflect all normal recurring adjustments that are, in our opinion, necessary to fairly present our results of operations and financial position. Amounts reported in the Condensed Consolidated Statements of Operations are not necessarily indicative of amounts expected for the respective annual periods.

During the third quarter of 2011, we identified errors in our previously issued Condensed Consolidated Statements of Cash Flows related to the accounting for rollovers of outstanding borrowings under our revolving bank credit facility. These rollovers, which are extensions of borrowings beyond their scheduled due dates that did not involve the exchange of cash, were previously accounted for as cash activities and resulted in the overstatement of both Proceeds from Issuance of Long-Term Debt and Payments for the Redemption of Long-Term Debt for the three months ended March 31, 2011. Cash and Cash Equivalents and Net Cash Used In Financing Activities as previously reported are not affected by the errors. We evaluated materiality from both a qualitative and a quantitative perspective and concluded that the errors are immaterial to our previously issued Condensed Consolidated Statements of Cash Flows.

In addition to making this correction, effective with the third quarter of 2011, we have elected to present cash borrowings and repayments under our revolving bank credit facility on a net basis for all periods presented as Net Increase in Revolving Credit Facility Borrowings. As these periodic borrowings and repayments are generally of significant amounts and have terms of 90 days or less, we believe our current presentation provides users with more meaningful and relevant information about our long-term debt financing activities.

The correction and change in presentation reflected on the Condensed Consolidated Statement of Cash Flows are as follows:

Three Months Ended March 31, 2011	Proceeds from the Issuance of Long-Term Debt			Payments for the Redemption of Long-Term Debt
	(in millions)
As previously reported	$	918.7		$	942.3
Less non-cash activity		(895.8	)		(895.8	)
As corrected		22.9			46.5
Less revolving credit facility activity		(22.9	)		(9.9	)
Long-term debt activity	$	—		$	36.6

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Use of Estimates. To conform with generally accepted accounting principles (GAAP) in the United States, we make estimates and assumptions that affect the amounts reported in the Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements. Although these estimates are based on our best available knowledge at the time, actual results could differ.

2. Acquisitions

Big Sandy. On July 1, 2011, we completed the acquisition of Big Sandy Pipeline, LLC (Big Sandy) from EQT Corporation (EQT) for approximately $390 million in cash. Big Sandy’s primary asset is a 68-mile Federal Energy Regulatory Commission (FERC) regulated natural gas pipeline system in eastern Kentucky with capacity of 0.2 billion cubic feet (Bcf) per day. The Big Sandy natural gas pipeline system connects Appalachian and Huron Shale natural gas supplies to markets in the mid-Atlantic and northeast portions of the United States. EQT is the main shipper on the pipeline, with over 80% of the pipeline’s capacity. With 100% fee-based revenues and a weighted average contract life of 14 years, the acquisition of Big Sandy strengthens our portfolio of fee-based natural gas assets and is consistent with our strategy of growth through third-party acquisitions.

The assets and liabilities of Big Sandy were recorded at their respective fair values as of the purchase date and the results of operations were included in the Condensed Consolidated Financial Statements beginning as of the effective date of the acquisition. Since Big Sandy records assets and liabilities resulting from the rate making process, the fair values of the individual assets and liabilities are considered to approximate their carrying values. Pro forma results of operations reflecting the acquisition of Big Sandy as if the acquisition had occurred as of January 1, 2011 does not materially differ from actual reported results.

3. Business Segments

Our Gas Transportation and Storage segment aligns our operations with the chief operating decision makers’ view of the business. This business segment is considered to be our sole reportable segment.

The Gas Transportation and Storage segment provides interstate transportation, storage and gathering services of natural gas, and the storage and redelivery of liquefied natural gas for customers in the southeastern quadrant of the United States. Substantially all of our operations are subject to the FERC and the Department of Transportation’s (DOT) rules and regulations. This segment includes East Tennessee Natural Gas, LLC (East Tennessee), Ozark Gas Transmission, L.L.C. (Ozark Gas Transmission) and Ozark Gas Gathering, L.L.C. (Ozark Gas Gathering) (collectively, hereafter referred to as “Ozark”), Saltville Gas Storage, L.L.C. (Saltville), and Big Sandy.

The remainder of our operations is presented as “Other.” While it is not considered a business segment, Other mainly includes our equity investments in Gulfstream Natural Gas System, L.L.C. (Gulfstream) and Market Hub Partners Holding (Market Hub) and unallocated corporate costs.

Gulfstream provides interstate natural gas pipeline transportation from Pascagoula, Mississippi and Mobile, Alabama across the Gulf of Mexico into Florida for customers in central and southern Florida. Gulfstream’s operations are subject to the rules and regulations of the FERC and DOT.

Market Hub owns and operates two natural gas storage facilities, Moss Bluff and Egan, which are located in southeast Texas and south central Louisiana, respectively. Market Hub’s operations are subject to the rules and regulations of DOT. Moss Bluff is also subject to the rules and regulations of the Texas Railroad Commission, while Egan is also subject to the rules and regulations of the FERC.

Management evaluates segment performance based on earnings before interest and taxes from continuing operations (EBIT). On a segment basis, EBIT represents all profits from continuing operations (both operating and non-operating) before deducting interest and income taxes.

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Business Segment Data

	Three Months Ended March 31,
	2012		2011
	(in millions)
Operating revenues
Gas Transportation and Storage	$	61.9	$	51.2
Other		—		—
Total operating revenues	$	61.9	$	51.2
Segment EBIT
Gas Transportation and Storage	$	35.1	$	27.8
Other		25.4		25.6
Total EBIT		60.5		53.4
Interest income		—		0.1
Interest expense		7.7		4.2
Earnings before income taxes	$	52.8	$	49.3

4. Net Income Per Limited Partner Unit and Cash Distributions

The following table presents our net income per limited partner unit calculations.

	Three Months Ended March 31,
	2012		2011
	(in millions, except per unit amounts)
Net income	$	52.4	$	48.9
Less:
General partner’s interest in net income—2%		1.1		1.0
General partner’s interest in net income attributable to incentive distribution rights		5.4		3.3
Limited partners’ interest in net income	$	45.9	$	44.6
Weighted average limited partner units outstanding—basic and diluted		96.3		89.2
Net income per limited partner unit—basic and diluted	$	0.48	$	0.50

The partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our Available Cash, as defined, to unitholders of record on the applicable record date.

Available Cash. Available Cash, for any quarter, consists of all cash on hand at the end of that quarter:

• less the amount of cash reserves established by the general partner to:

• provide for the proper conduct of business,

• comply with applicable law, any debt instrument or other agreement, or

• provide funds for distributions to the unitholders and to the general partner for any one or more of the next four quarters,

• plus, if the general partner so determines, all or a portion of cash on hand on the date of determination of Available Cash for the quarter.

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Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:

	Total Quarterly Distribution	Marginal Percentage Interest in Distributions
	Target Per-Unit Amount	Common and Subordinated Unitholders			General Partner
Minimum Quarterly Distribution	$0.30		98	%		2	%
First Target Distribution	up to $0.345		98	%		2	%
Second Target Distribution	above $0.345 up to $0.375		85	%		15	%
Third Target Distribution	above $0.375 up to $0.45		75	%		25	%
Thereafter	above $0.45		50	%		50	%

To the extent these incentive distributions are made to our general partner, there will be more Available Cash proportionately allocated to our general partner than to holders of common units. Our distribution of $0.48 per limited partner unit will be paid on May 15, 2012.

5. Investments in Unconsolidated Affiliates

As of March 31, 2012, our investments in unconsolidated affiliates consist of a 49% interest in Gulfstream and a 50% interest in Market Hub, both of which are accounted for using the equity method.

For the three months ended March 31, 2012, we received total distributions of $20.3 million from Gulfstream, of which $15.3 million were included in Cash Flows From Operating Activities—Distributions Received From Unconsolidated Affiliates and $5.0 million were included in Cash Flows From Investing Activities—Distributions Received From Unconsolidated Affiliates. For the three months ended March 31, 2011, we received total distributions of $13.2 million, all of which were included in Cash Flows From Operating Activities—Distributions Received From Unconsolidated Affiliates.

We received distributions from Market Hub of $9.0 million during the three months ended March 31, 2012 and $11.5 million during the same period in 2011, all of which were included in Cash Flows From Operating Activities—Distributions Received From Unconsolidated Affiliates.

Investments in Unconsolidated Affiliates

	March 31, 2012		December 31, 2011
	(in millions)
Gulfstream	$	354.8	$	360.0
Market Hub		379.4		367.2
Total	$	734.2	$	727.2

Equity in Earnings of Unconsolidated Affiliates

	Three Months Ended March 31,
	2012		2011
	(in millions)
Gulfstream	$	15.3	$	16.8
Market Hub		12.1		11.0
Total	$	27.4	$	27.8

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Summarized Financial Information of Unconsolidated Affiliates

(Presented at 100%)

	Three Months Ended March 31,
	2012		2011
	(in millions)
Gulfstream
Operating revenues	$	67.7	$	66.9
Operating expenses		19.0		15.8
Operating income		48.7		51.1
Net income		31.2		34.3
Market Hub
Operating revenues	$	31.2	$	30.1
Operating expenses		7.0		8.0
Operating income		24.2		22.1
Net income		24.2		22.1

6. Marketable Securities

We may actively invest a portion of our cash balances in various financial instruments, including taxable debt securities. In addition, we invest in short-term money market securities, some of which are restricted due to debt collateral requirements. We classify all short-term money market securities that are pledged as collateral as available-for-sale (AFS). We do not purchase marketable securities for speculative purposes, nor do we routinely sell marketable securities prior to their scheduled maturity dates. Therefore, we do not have any securities classified as trading securities. Initial investments in securities are classified as purchases of the respective type of securities (available-for-sale or held-to-maturity), and maturities of securities are classified within proceeds from sales and maturities of securities in the Condensed Consolidated Statements of Cash Flows. As of March 31, 2012, there were no marketable securities outstanding.

In the fourth quarter of 2010, we invested in commercial paper with a portion of the proceeds from the equity issuance related to the Gulfstream acquisition. In June 2011, these investments were liquidated.

7. Debt and Credit Facility

	Expiration Date		Total Credit Facility Capacity		Outstanding at March 31, 2012
					Commercial Paper		Available Credit Facility Capacity
					(in millions)
Spectra Energy Partners, LP		2016	$	700.0	$	40.0	$	660.0

The issuances of commercial paper, letters of credit and revolving borrowings reduce the amount available under the credit facility. As of March 31, 2012, there were no letters of credit and revolving borrowings outstanding.

The credit agreement contains various financial and other covenants, including the maintenance of a consolidated leverage ratio, as defined in the agreement. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreement. As of March 31, 2012, we were in compliance with those covenants. In addition, the credit agreement allows for the acceleration of payments or termination of the agreement due to nonpayment, or in some cases, due to the acceleration of our other significant indebtedness or other significant indebtedness of some of our subsidiaries. The credit agreement does

14

not contain provisions that trigger an acceleration of indebtedness based solely on the occurrence of an adverse change in our financial condition or results of operations.

As noted above, the terms of the credit agreement requires us to maintain a consolidated leverage ratio of adjusted consolidated indebtedness to adjusted consolidated earnings before interest, taxes, depreciation and amortization (EBITDA), as defined in the agreement, of 5.0 or less. As of March 31, 2012, the consolidated leverage ratio was 2.7.

Adjusted EBITDA is a non-GAAP measure. Our definition of Adjusted EBITDA may not be comparable to similarly titled measures of other companies because our definition excludes some, but not all, items that affect net income and is defined in varying ways by companies in our industry. Adjusted EBITDA should not be considered an alternative to net income, operating income, cash from operations or any other measure of financial performance or liquidity presented in accordance with GAAP.

8. Fair Value Measurements

Financial Instruments. The fair values of financial instruments that are recorded and carried at book value are summarized in the following table. Judgment is required in interpreting market data to develop the estimates of fair value. These estimates are not necessarily indicative of the amounts we could have realized in current markets. The fair values of long-term debt, including current maturities are determined based on market-based prices which may include inputs such as quoted market prices of the exact or similar instruments, broker or dealer quotations, or alternative pricing sources that may include models or matrix pricing tools, with reasonable levels of price transparency.

	March 31, 2012				December 31, 2011
Condensed Consolidated Balance Sheet Caption	Book Value		Approximate Fair Value		Book Value		Approximate Fair Value
	(in millions)
Current maturities of long-term debt(a)	$	150.0	$	153.6	$	150.0	$	154.3
Long-term debt (b)	$	500.0	$	513.9	$	500.0	$	514.8

(a) East Tennessee debt due in 2012

(b) Excludes unamortized items

The fair value of cash and cash equivalents, accounts receivable, accounts payable, commercial paper and note payable—affiliates are not materially different from their carrying amounts because of the short-term nature of these instruments or because the stated rates approximate market rates.

During 2012 and 2011, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.

9. Commitments and Contingencies

Environmental. We are subject to various federal, state and local laws and regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These laws and regulations can change from time to time, imposing new obligations on us. We believe there are no matters outstanding that, upon resolution, will have a material effect on our consolidated results of operations, financial position or cash flows.

Litigation. We are involved in legal, tax and regulatory proceedings in various forums arising in the ordinary course of business, including matters regarding contracts and payment claims, some of which may involve substantial monetary amounts. We have insurance coverage for certain of these losses should they be incurred. We believe that the final disposition of these proceedings will not have a material effect on our consolidated results of operations, financial position or cash flows.

15

Legal costs related to the defense of loss contingencies are expensed as incurred. We had no material reserves recorded as of March 31, 2012 or December 31, 2011 related to litigation.

10. Risk Management and Hedging Activities

We are exposed to the impact of changes in interest rates as a result of our issuance of variable and fixed-rate debt and commercial paper. We manage our interest rate exposure by limiting our variable-rate exposures and by monitoring the effects of market changes in interest rates. As of March 31, 2012 and December 31, 2011, we did not have any derivatives outstanding.

11. New Accounting Pronouncement

There were no significant accounting pronouncements adopted during the three months ended March 31, 2012 that had a material impact on our consolidated results of operations, financial position or cash flows.

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

INTRODUCTION

Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Condensed Consolidated Financial Statements.

Executive Overview

For the three months ended March 31, 2012, we reported net income of $52.4 million compared to $48.9 million for the comparable period in 2011. For the three months ended March 31, 2012, cash available for distribution was $66.2 million, an increase of $7.4 million from the prior year quarter. The increase in both net income and cash available for distribution was the result of the addition of Big Sandy pipeline and East Tennessee’s Northeastern Tennessee (NET) assets to our portfolio in July and September 2011, respectively.

We estimate 2012 capital and investment expansion expenditures of approximately $30 million, of which $13.1 million was spent in the first quarter. The majority of these expenditures are to complete projects at East Tennessee and Market Hub, both of which went into commercial service in 2011.

A cash distribution of $0.48 per limited partner unit was declared on April 19, 2012 and is payable on May 15, 2012, representing a 1.1% increase over the previous distribution of $0.475 per limited partner unit paid in February 2012. The Spectra Energy Partners board evaluates each individual quarterly distribution decision within the confines of the Partnership agreement and based on an assessment of growth in cash available for distribution.

RESULTS OF OPERATIONS

	Three Months Ended March 31,
	2012		2011		Increase (Decrease)
	(in millions)
Operating revenues	$	61.9	$	51.2	$	10.7
Operating, maintenance and other expense		19.5		18.3		1.2
Depreciation and amortization		9.3		7.8		1.5
Operating income		33.1		25.1		8.0
Equity in earnings of unconsolidated affiliates		27.4		27.8		(0.4	)
Other income and expenses, net		—		0.5		(0.5	)
Interest income		—		0.1		(0.1	)
Interest expense		7.7		4.2		3.5
Earnings before income taxes		52.8		49.3		3.5
Income tax expense		0.4		0.4		—
Net income	$	52.4	$	48.9	$	3.5
Net cash provided by operating activities	$	57.5	$	57.6	$	(0.1	)
Adjusted EBITDA (a)		42.4		32.9		9.5
Cash Available for Distribution (a)		66.2		58.8		7.4

(a) See “Reconciliation of Non-GAAP Measures” for a reconciliation of this measure to its most directly comparable financial measures calculated and presented in accordance with GAAP.

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Three Months Ended March 31, 2012 compared to same period in 2011

Operating Revenues. Operating revenues increased $10.2 million and $5.7 million due to the acquisition of Big Sandy in July 2011 and the NET project being placed into commercial service on September 1, 2011, respectively. The increases were partially offset by decreases in contract revenue of $3.7 million and a reduction in throughput-driven revenues of $0.6 million both at Ozark.

Operating, Maintenance and Other Expense. The increase was driven mainly by the Big Sandy acquisition and planned higher software costs, partially offset by higher fuel recoveries at Ozark.

Depreciation and Amortization. The increase was driven primarily by the acquisition of the Big Sandy assets.

Equity in Earnings of Unconsolidated Affiliates. The following discussion explains the factors affecting the earnings of Gulfstream and Market Hub, each representing 100% of the earnings drivers of those entities.

	Three Months Ended March 31,
	2012		2011		Increase (Decrease)
	(in millions)
Gulfstream
Operating revenues	$	67.7	$	66.9	$	0.8
Operating, maintenance and other expense		10.1		7.0		3.1
Depreciation and amortization		8.9		8.8		0.1
Other income and expenses, net		—		0.4		(0.4	)
Interest expense		17.5		17.2		0.3
Net income	$	31.2	$	34.3	$	(3.1	)
Spectra Energy Partners’ share	$	15.3	$	16.8	$	(1.5	)

Gulfstream—Owned 49.0%

Gulfstream’s Phase V expansion project went into service on April 1, 2011 and increased operating revenues by $2.6 million. This increase in revenue from Phase V was partially offset by higher short-term transportation revenues from colder weather in 2011. Operating, maintenance and other expenses reflect $2.3 million of favorable tax adjustments in 2011 that did not reoccur in 2012.

	Three Months Ended March 31,
	2012			2011		Increase (Decrease)
	(in millions)
Market Hub
Operating revenues	$	31.2		$	30.1	$	1.1
Operating, maintenance and other expense		4.2			5.4		(1.2	)
Depreciation and amortization		2.8			2.6		0.2
Interest income		—			0.1		(0.1	)
Interest expense		(0.1	)		—		(0.1	)
Income tax expense		0.1			0.1		—
Net income	$	24.2		$	22.1	$	2.1
Spectra Energy Partners’ share	$	12.1		$	11.0	$	1.1

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Market Hub—Owned 50%

Market Hub’s revenues increased as result of the cavern expansion projects placed into commercial service during the second quarter of 2011. Operating, maintenance and other expenses reflect $1.5 million of favorable tax adjustments in 2012.

Other Income and Expenses net. The decrease is primarily due to a higher equity portion of allowance for funds used during construction (AFUDC) in 2011 related to the NET project.

Interest Expense. The increase is due to the issuance of $500.0 million of unsecured senior notes in June 2011.

Adjusted EBITDA and Cash Available for Distribution

Adjusted EBITDA

We define our Adjusted Earnings Before Interest, Taxes, Depreciation and Amortization (EBITDA) as Net Income plus Interest Expense, Income Taxes and Depreciation and Amortization less our Equity in Earnings of Gulfstream and Market Hub, Interest Income, and Other Income and Expenses, Net, which primarily consists of non-cash AFUDC. Since Adjusted EBITDA excludes some, but not all, items that affect net income and is defined differently by companies in our industry, our definition of Adjusted EBITDA may not be comparable to similarly titled measures of other companies. Adjusted EBITDA is a non-GAAP measure and should not be considered an alternative to Net Income, Operating Income, cash from operations or any other measure of financial performance or liquidity in accordance with GAAP.

Adjusted EBITDA is used as a supplemental financial measure by our management and by external users of our financial statements to assess:

• the financial performance of assets without regard to financing methods, capital structure or historical cost basis;

• the ability to generate cash sufficient to pay interest on indebtedness and to make distributions to partners; and

• operating performance and return on invested capital as compared to those of other publicly traded limited partnerships that own energy infrastructure assets, without regard to financing methods and capital structure.

Significant drivers of variances in Adjusted EBITDA between the periods presented are substantially the same as those previously discussed under Results of Operations.

Cash Available for Distribution

We define Cash Available for Distribution (CAD) as our Adjusted EBITDA plus Cash Available for Distribution from Gulfstream and Market Hub and net preliminary project costs, less interest expense, cash paid for income tax expense, maintenance capital expenditures, excluding the impact of reimbursable projects, and other non-cash items affecting net income. Cash Available for Distribution does not reflect changes in working capital balances. Cash Available for Distribution for Gulfstream and Market Hub is defined on a basis consistent with us. Cash Available for Distribution should not be viewed as indicative of the actual amount of cash we plan to distribute for a given period.

Cash Available for Distribution is a non-GAAP measure and should not be considered an alternative to Net Income, Operating Income, cash from operations or any other measure of financial performance or liquidity

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presented in accordance with GAAP. Cash Available for Distribution excludes some, but not all, items that affect Net Income and Operating Income and these measures may vary among other companies. Therefore, Cash Available for Distribution as presented may not be comparable to similarly titled measures of other companies.

Significant drivers of variances in Cash Available for Distribution between the periods presented are substantially the same as those previously discussed under Results of Operations. Other drivers include the timing of certain cash outflows, such as capital expenditures for maintenance.

Spectra Energy Partners

Reconciliation of Net Income to Non-GAAP “Adjusted EBITDA” and “Cash Available for Distribution”

	Three Months Ended March 31,
	2012			2011(a)
	(in millions)
Net income	$	52.4		$	48.9
Add:
Interest expense		7.7			4.2
Income tax expense		0.4			0.4
Depreciation and amortization		9.3			7.8
Less:
Equity in earnings of Gulfstream		15.3			16.8
Equity in earnings of Market Hub		12.1			11.0
Interest income		—			0.1
Other income and expenses, net		—			0.5
Adjusted EBITDA		42.4			32.9
Add:
Cash Available for Distribution from Gulfstream		19.6			20.5
Cash Available for Distribution from Market Hub		13.5			12.2
Preliminary project costs, net		—			—
Less:
Interest expense		7.7			4.2
Cash paid for income tax expense		—			—
Maintenance capital expenditures		1.7			2.6
Other		(0.1	)		—
Cash Available for Distribution	$	66.2		$	58.8

(a) Cash Available for Distribution for the three months ended March 31, 2011 has been revised to reflect the refinement to our definition that was effective January 1, 2012.

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Spectra Energy Partners

Reconciliation of Net Cash Provided by Operating Activities to Non-GAAP “Adjusted EBITDA” and “Cash Available for Distribution”

	Three Months Ended March 31,
	2012			2011(a)
	(in millions)
Net cash provided by operating activities	$	57.5		$	57.6
Interest income		—			(0.1	)
Interest expense		7.7			4.2
Income tax expense—current		—			0.1
Distributions received from Gulfstream		(15.3	)		(13.2	)
Distributions received from Market Hub		(9.0	)		(11.5	)
Changes in operating working capital and other		1.5			(4.2	)
Adjusted EBITDA		42.4			32.9
Add:
Cash Available for Distribution from Gulfstream		19.6			20.5
Cash Available for Distribution from Market Hub		13.5			12.2
Preliminary project costs, net		—			—
Less:
Interest expense		7.7			4.2
Cash paid for income tax expense		—			—
Maintenance capital expenditures		1.7			2.6
Other		(0.1	)		—
Cash Available for Distribution	$	66.2		$	58.8

(a) Cash Available for Distribution for the three months ended March 31, 2011 has been revised to reflect the refinement to our definition that was effective January 1, 2012.

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Gulfstream

Reconciliation of Non-GAAP “Adjusted EBITDA” and “Cash Available for Distribution”

	Three Months Ended March 31,
	2012		2011(a)
	(in millions)
Net income	$	31.2	$	34.3
Add:
Interest expense		17.5		17.2
Depreciation and amortization		8.9		8.8
Less:
Other income and expenses, net		—		0.4
Adjusted EBITDA—100%		57.6		59.9
Add:
Preliminary project costs, net		0.3		0.2
Less:
Interest expense		17.5		17.2
Maintenance capital expenditures		0.3		0.7
Other		—		0.3
Cash Available for Distribution—100%	$	40.1	$	41.9
Adjusted EBITDA—49%	$	28.2	$	29.3
Cash Available for Distribution—49%		19.6		20.5

(a) Cash Available for Distribution for the three months ended March 31, 2011 has been revised to reflect the refinement to our definition that was effective January 1, 2012.

Market Hub

Reconciliation of Non-GAAP “Adjusted EBITDA” and “Cash Available for Distribution”

	Three Months Ended March 31,
	2012			2011
	(in millions)
Net income	$	24.2		$	22.1
Add:
Interest expense		(0.1	)		—
Income tax expense		0.1			0.1
Depreciation and amortization		2.8			2.6
Less:
Interest income		—			0.1
Other income and expenses, net		—			—
Adjusted EBITDA—100%		27.0			24.7
Less:
Interest expense		(0.1	)		—
Cash paid for income tax expense		—			—
Maintenance capital expenditures		0.1			0.4
Cash Available for Distribution—100%	$	27.0		$	24.3
Adjusted EBITDA—50%	$	13.5		$	12.4
Cash Available for Distribution—50%		13.5			12.2

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LIQUIDITY AND CAPITAL RESOURCES

We will rely upon cash flows from operations, including cash distributions received from Gulfstream and Market Hub, and various financing transactions, which may include issuances of short-term and long-term debt, to fund our liquidity and capital requirements for the next 12 months. As of March 31, 2012, we had negative net working capital of $205.4 million compared to a negative $204.3 million of working capital as of December 31, 2011, both of which included the East Tennessee notes payable of $150.0 million.

We have access to a credit facility, with available capacity of $660.0 million at March 31, 2012, which is used to manage working capital requirements. Given that we expect to continue to pursue expansion opportunities over the next several years, capital resources may continue to include commercial paper, short-term borrowings under our current credit facility and possibly securing additional sources of capital including debt and/or equity.

Operating Cash Flows

Net cash provided by operating activities totaled $57.5 million and was relatively consistent with the same period in 2011. An increase in payments for normal operating expenses was offset by accrued interest on the $500 million unsecured senior notes and higher earnings due to the Big Sandy acquisition.

Investing Cash Flows

Net cash flows used in investing activities was $9.4 million in the first three months of 2012 compared to $14.9 million of cash provided by in the same period in 2011. The change was driven mainly by:

• $28.1 million of net proceeds in 2011 from the liquidation of available-for-sale securities, and

• $9.5 million due to release of collateral investments in 2011, partially offset by

• $11.5 million decrease in capital expenditures due to the NET project at East Tennessee going into commercial service in September 2011, and

• $5.0 million of return of capital distributions received from Gulfstream in 2012.

Capital and Investment Expenditures

	Three Months Ended March 31,
	2012		2011
	(in millions)
Capital Expenditures
Gas Transportation and Storage	$	5.3	$	16.8
Investment Expenditures
Gulfstream		—		3.8
Market Hub		9.1		2.1
Total capital and investment expenditures	$	14.4	$	22.7

Capital and investment expenditures for the three months ended March 31, 2012 totaled $14.4 million and included $13.1 million for expansion projects and $1.3 million for maintenance and other projects. We estimate 2012 capital and investment expenditures of approximately $49 million, $30 million is expected to be used to complete expansion projects placed into service during 2011 and $19 million is to be used for maintenance and other projects.

23

We continue to evaluate customers’ needs for incremental expansion opportunities at East Tennessee, Big Sandy, Gulfstream and Market Hub. In addition, we are assessing the needs of our Ozark customers for additional transportation services. We expect that significant natural gas infrastructure, including both natural gas transportation and storage with links to growing gas supplies and markets, will be needed over time to serve growth in gas-fired power generation, oil-to-gas conversions, industrial development and attachments to new gas supply.

Financing Cash Flows and Liquidity

Net cash used in financing activities was $45.8 million in the first three months of 2012 compared to $70.5 million during the same period in 2011. This change was driven mainly by:

• $13.0 million of net commercial paper issuances in 2012 compared to $23.6 million of net debt payment in 2011, including net revolver borrowings, partially offset by

• an $8.4 million increase in distributions to partners in 2012 compared to the same period in 2011, as a result of increased distribution rates, limited partner units outstanding and higher incentive distribution rights, and

• $7.0 million of payments on note payable to affiliates in 2012, compared to $3.5 million of net payments in the same period in 2011.

Available Credit Facility and Restrictive Debt Covenants. See Note 7 of Notes to Condensed Consolidated Financial Statements for a discussion of the available credit facility and related financial and other covenants.

Credit Ratings. As of March 31, 2012 our credit ratings are BBB/Stable from Standard & Poor’s and Fitch Ratings and Baa3/Stable from Moody’s Investors Service. Our credit ratings are dependent upon, among other factors, our ability to generate sufficient cash to fund capital and investment expenditures, our results of operations, market conditions, the leverage of Spectra Energy Corp (Spectra Energy) and other factors. Our credit ratings could impact our ability to raise capital in the future, impact the cost of capital and, as a result, have an impact on our liquidity.

Cash Distributions. As previously discussed, a cash distribution of $0.48 per limited partner unit was declared in April 2012, payable on May 15, 2012, representing a 1.1% increase over the previous distribution of $0.475 per limited partner unit and the eighteenth consecutive quarterly increase.

Other Financing Matters. We have an effective shelf registration statement on file with the Securities and Exchange Commission (SEC) to register the issuance of unspecified amounts of limited partner common units and various debt securities.

OTHER ISSUES

New Accounting Pronouncement. See Note 11 of Notes to Condensed Consolidated Financial Statements for discussion.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

Our exposure to market risk is described in Item 7A of our Annual Report on Form 10-K for the year ended December 31, 2011. We believe the exposure to market risk has not changed materially.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by us in the reports we file or submit under the Securities Exchange Act of

24

1934 (Exchange Act) is recorded, processed, summarized, and reported, within the time periods specified by the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by us in the reports we file or submit under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of the management of Spectra Energy Partners (DE) GP, LP (our General Partner), including the Chief Executive Officer and Chief Financial Officer, we have evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of March 31, 2012, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

During the quarter ended March 31, 2012, we implemented several modules of a new enterprise resource planning system, Systems Applications and Products (SAP), the most significant of which was the general ledger module in our U.S. operations. The internal controls over financial reporting affected by this implementation were evaluated for design and found to be effective. Prior to implementation of the modules, user acceptance testing was performed to ensure the system was functioning as designed. Post-implementation reviews have been and will continue to be conducted by management to ensure that the internal controls surrounding the system implementation processes, key applications and the financial close process are properly designed and are operating effectively. We expect to implement additional SAP modules during the remainder of 2012, and will apply the same methodology to their implementation.

Under the supervision and with the participation of the management of our General Partner, including the Chief Executive Officer and Chief Financial Officer, we have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended March 31, 2012 and found no change, other than described above, that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

25

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

We have no material pending legal proceedings that are required to be disclosed hereunder. For information regarding other legal proceedings and environmental matters, see Note 9 of Notes to Condensed Consolidated Financial Statements, which information is incorporated by reference into this Part II.

Item 1A. Risk Factors.

In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2011, which could materially affect our financial condition or future results. There have been no material changes to those risk factors.

Item 6. Exhibits.

Any agreements included as exhibits to this Form 10-Q may contain representations and warranties by each of the parties to the applicable agreement. These representations and warranties have been made solely for the benefit of the other parties to the applicable agreement and:

• were not intended to 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;

• may apply contract standards of “materiality” that are different from “materiality” under the applicable securities laws; 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.

We acknowledge that, notwithstanding the inclusion of the foregoing cautionary statements, we are responsible for considering whether additional specific disclosures of material information regarding material contractual provisions are required to make the statements in this Form 10-Q not misleading.

26

(a) Exhibits

Exhibit Number
*31.1	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*31.2	Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
*32.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*32.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
*101.INS	XBRL Instance Document.
*101.SCH	XBRL Taxonomy Extension Schema.
*101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
*101.DEF	XBRL Taxonomy Extension Definition Linkbase.
*101.LAB	XBRL Taxonomy Extension Label Linkbase.
*101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

* Filed herewith

27

SIGNATURES

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

	SPECTRA ENERGY PARTNERS, LP
	By:	Spectra Energy Partners (DE) GP, LP, its general partner
	By:	Spectra Energy Partners GP, LLC, its general partner
Date: May 9, 2012		/S/    JULIE A. DILL
		Julie A. Dill President and Chief Executive Officer
Date: May 9, 2012		/S/    LAURA BUSS SAYAVEDRA
		Laura Buss Sayavedra Vice President and Chief Financial Officer

28

EX-31.1

EXHIBIT 31.1

CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Julie A. Dill, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Spectra Energy Partners, LP;

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

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

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

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

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

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

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

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

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

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

Date: May 9, 2012	/S/    JULIE A. DILL
	Julie A. Dill President and Chief Executive Officer Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

EX-31.2

EXHIBIT 31.2

CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Laura Buss Sayavedra, certify that:

1) I have reviewed this quarterly report on Form 10-Q of Spectra Energy Partners, LP;

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

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

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

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

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

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

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

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

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

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

Date: May 9, 2012	/S/    LAURA BUSS SAYAVEDRA
	Laura Buss Sayavedra Vice President and Chief Financial Officer Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Spectra Energy Partners, LP on Form 10-Q for the period ending March 31, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Julie A. Dill, President and Chief Executive Officer of Spectra Energy Partners GP, LLC, general partner of Spectra Energy Partners (DE) GP, LP, general partner of Spectra Energy Partners, LP, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date: May 9, 2012	/S/    JULIE A. DILL
	Julie A. Dill President and Chief Executive Officer Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

EX-32.2

EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Spectra Energy Partners, LP on Form 10-Q for the period ending March 31, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Laura Buss Sayavedra, Vice President and Chief Financial Officer of Spectra Energy Partners GP, LLC, general partner of Spectra Energy Partners (DE) GP, LP, general partner of Spectra Energy Partners, LP, certify, pursuant to 18 U.S.C. section 1350, as adopted pursuant to section 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date: May 9, 2012	/S/    LAURA BUSS SAYAVEDRA
	Laura Buss Sayavedra Vice President and Chief Financial Officer Spectra Energy Partners GP, LLC General Partner of Spectra Energy Partners (DE) GP, LP General Partner of Spectra Energy Partners, LP

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Fair Values of Financial Instruments That are Recorded and Carried at Book Value (Detail) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012		Dec. 31, 2011
Book Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current maturities of long-term debt	$ 150.0	[1]	$ 150.0	[1]
Long-term debt	500.0	[2]	500.0	[2]
Approximate Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Current maturities of long-term debt	153.6	[1]	154.3	[1]
Long-term debt	$ 513.9	[2]	$ 514.8	[2]

[1] East Tennessee debt due in 2012

[2] Excludes unamortized items

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Investments in Unconsolidated Affiliates - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Schedule of Equity Method Investments [Line Items]
Operating Activities-distributions received from unconsolidated Affiliates	$ 24.3	$ 24.7
Investing activities-distributions received from unconsolidated affiliates	5.0
Gulfstream
Schedule of Equity Method Investments [Line Items]
Percentage of investments in unconsolidated affiliates which are accounted for using the equity method	49.00%
Distributions received from unconsolidated affiliates	20.3
Operating Activities-distributions received from unconsolidated Affiliates	15.3	13.2
Investing activities-distributions received from unconsolidated affiliates	5.0
Market Hub
Schedule of Equity Method Investments [Line Items]
Percentage of investments in unconsolidated affiliates which are accounted for using the equity method	50.00%
Operating Activities-distributions received from unconsolidated Affiliates	$ 9.0	$ 11.5

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General - Additional Information (Detail) (Maximum)	3 Months Ended
	Mar. 31, 2012
Maximum
Business Acquisition [Line Items]
Revolving credit facility, terms	90 days

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Credit Facility Summary (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Debt Instrument [Line Items]
Expiration Date	2016
Total Credit Facility Capacity	$ 700.0
Commercial Paper	40.0	27.0
Available Credit Facility Capacity	$ 660.0

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Acquisitions

3 Months Ended

Mar. 31, 2012

Acquisitions

2. Acquisitions

Big Sandy. On July 1, 2011, we completed the acquisition of Big Sandy Pipeline, LLC (Big Sandy) from EQT Corporation (EQT) for approximately $390 million in cash. Big Sandy’s primary asset is a 68-mile Federal Energy Regulatory Commission (FERC) regulated natural gas pipeline system in eastern Kentucky with capacity of 0.2 billion cubic feet (Bcf) per day. The Big Sandy natural gas pipeline system connects Appalachian and Huron Shale natural gas supplies to markets in the mid-Atlantic and northeast portions of the United States. EQT is the main shipper on the pipeline, with over 80% of the pipeline’s capacity. With 100% fee-based revenues and a weighted average contract life of 14 years, the acquisition of Big Sandy strengthens our portfolio of fee-based natural gas assets and is consistent with our strategy of growth through third-party acquisitions.

The assets and liabilities of Big Sandy were recorded at their respective fair values as of the purchase date and the results of operations were included in the Condensed Consolidated Financial Statements beginning as of the effective date of the acquisition. Since Big Sandy records assets and liabilities resulting from the rate making process, the fair values of the individual assets and liabilities are considered to approximate their carrying values. Pro forma results of operations reflecting the acquisition of Big Sandy as if the acquisition had occurred as of January 1, 2011 does not materially differ from actual reported results.

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Net Income Per Limited Partner Unit Calculations (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012 PartnershipUnit	Mar. 31, 2011 PartnershipUnit
Net income	$ 52.4	$ 48.9
Less: General partner's interest in net income	6.5	4.3
Limited partners' interest in net income	45.9	44.6
Weighted average limited partner units outstanding-basic and diluted	96,300,000	89,200,000
Net income per limited partner unit-basic and diluted	0.48	0.50
Partnership Interest
Less: General partner's interest in net income	1.1	1.0
Incentive Distribution Rights
Less: General partner's interest in net income	$ 5.4	$ 3.3

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Business Segment Data (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Segment Reporting Information [Line Items]
Operating revenues	$ 61.9	$ 51.2
Earnings before interest and income tax	60.5	53.4
Interest Income		0.1
Interest Expense	7.7	4.2
Earnings Before Income Taxes	52.8	49.3
Gas Transportation and Storage
Segment Reporting Information [Line Items]
Operating revenues	61.9	51.2
Earnings before interest and income tax	35.1	27.8
All Other Segments
Segment Reporting Information [Line Items]
Earnings before interest and income tax	$ 25.4	$ 25.6

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Net Income Per Limited Partner Unit Calculations (Parenthetical) (Detail)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
General partner's interest in net income, ownership interest percentage	2.00%	2.00%

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Net Income Per Limited Partner Unit and Cash Distributions - Additional Information (Detail) (USD $)	3 Months Ended	1 Months Ended
	Mar. 31, 2012	May 15, 2012 Dividend Declared
Earnings Per Share Disclosure [Line Items]
Period after the end of each quarter for the distribution of Available Cash to unit holders on the applicable record date	45 days
Distributions to be paid to unit holders		$ 0.48

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General

3 Months Ended

Mar. 31, 2012

General

1. General

The terms “we,” “our,” “us” and “Spectra Energy Partners” as used in this report refer collectively to Spectra Energy Partners, LP and its subsidiaries unless the context suggests otherwise. These terms are used for convenience only and are not intended as a precise description of any separate legal entity within Spectra Energy Partners.

Nature of Operations. Spectra Energy Partners, through its subsidiaries and equity affiliates is engaged in the transportation and gathering of natural gas through interstate pipeline systems that are located in the southeastern quadrant of the United States, and the storage of natural gas in underground facilities that are located in southeast Texas, south central Louisiana and southwest Virginia.

Basis of Presentation. The Condensed Consolidated Financial Statements include our accounts and those of our majority-owned subsidiaries where we have control. These interim financial statements should be read in conjunction with the consolidated financial statements included in our Annual Report on Form 10-K for the year ended December 31, 2011, and reflect all normal recurring adjustments that are, in our opinion, necessary to fairly present our results of operations and financial position. Amounts reported in the Condensed Consolidated Statements of Operations are not necessarily indicative of amounts expected for the respective annual periods.

During the third quarter of 2011, we identified errors in our previously issued Condensed Consolidated Statements of Cash Flows related to the accounting for rollovers of outstanding borrowings under our revolving bank credit facility. These rollovers, which are extensions of borrowings beyond their scheduled due dates that did not involve the exchange of cash, were previously accounted for as cash activities and resulted in the overstatement of both Proceeds from Issuance of Long-Term Debt and Payments for the Redemption of Long-Term Debt for the three months ended March 31, 2011. Cash and Cash Equivalents and Net Cash Used In Financing Activities as previously reported are not affected by the errors. We evaluated materiality from both a qualitative and a quantitative perspective and concluded that the errors are immaterial to our previously issued Condensed Consolidated Statements of Cash Flows.

In addition to making this correction, effective with the third quarter of 2011, we have elected to present cash borrowings and repayments under our revolving bank credit facility on a net basis for all periods presented as Net Increase in Revolving Credit Facility Borrowings. As these periodic borrowings and repayments are generally of significant amounts and have terms of 90 days or less, we believe our current presentation provides users with more meaningful and relevant information about our long-term debt financing activities.

The correction and change in presentation reflected on the Condensed Consolidated Statement of Cash Flows are as follows:

Three Months Ended March 31, 2011	Proceeds from the Issuance of Long-Term Debt			Payments for the Redemption of Long-Term Debt
	(in millions)
As previously reported	$	918.7		$	942.3
Less non-cash activity		(895.8	)		(895.8	)
As corrected		22.9			46.5
Less revolving credit facility activity		(22.9	)		(9.9	)
Long-term debt activity	$	—		$	36.6

Use of Estimates. To conform with generally accepted accounting principles (GAAP) in the United States, we make estimates and assumptions that affect the amounts reported in the Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements. Although these estimates are based on our best available knowledge at the time, actual results could differ.

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Incentive Distribution Rights in Accordance with Partnership Agreement (Detail) (USD $)	3 Months Ended
	Mar. 31, 2012
Minimum Quarterly Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.300
Marginal Percentage Interest in Distributions Common and Subordinated Unit holders	98.00%
Marginal Percentage Interest in Distributions General Partner	2.00%
First Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common and Subordinated Unit holders	98.00%
Marginal Percentage Interest in Distributions General Partner	2.00%
First Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.345
Second Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common and Subordinated Unit holders	85.00%
Marginal Percentage Interest in Distributions General Partner	15.00%
Second Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.345
Second Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.375
Third Target Distribution
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common and Subordinated Unit holders	75.00%
Marginal Percentage Interest in Distributions General Partner	25.00%
Third Target Distribution | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.375
Third Target Distribution | Maximum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.450
Target Distribution Thereafter
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Marginal Percentage Interest in Distributions Common and Subordinated Unit holders	50.00%
Marginal Percentage Interest in Distributions General Partner	50.00%
Target Distribution Thereafter | Minimum
Incentive Distribution Made to Managing Member or General Partner [Line Items]
Total Quarterly Distribution Target Per-Unit Amount	$ 0.450

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012 PartnershipUnit	Mar. 31, 2011 PartnershipUnit
Operating Revenues
Transportation of natural gas	$ 56.2	$ 44.0
Storage of natural gas and other	5.7	7.2
Total operating revenues	61.9	51.2
Operating Expenses
Operating, maintenance and other	15.8	15.0
Depreciation and amortization	9.3	7.8
Property and other taxes	3.7	3.3
Total operating expenses	28.8	26.1
Operating Income	33.1	25.1
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	27.4	27.8
Other income and expenses, net		0.5
Total other income and expenses	27.4	28.3
Interest Income		0.1
Interest Expense	7.7	4.2
Earnings Before Income Taxes	52.8	49.3
Income Tax Expense	0.4	0.4
Net Income	52.4	48.9
Calculation of Limited Partners' Interest in Net Income:
Net income	52.4	48.9
Less: General partner's interest in net income	6.5	4.3
Limited partners' interest in net income	$ 45.9	$ 44.6
Weighted-average limited partner units outstanding-basic and diluted	96,300,000	89,200,000
Net income per limited partner unit-basic and diluted	0.48	0.50
Distributions paid per limited partner unit during the periods presented	$ 0.475	$ 0.450

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 52.4	$ 48.9
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	9.7	7.8
Deferred income tax expense	0.4	0.3
Equity in earnings of unconsolidated affiliates	(27.4)	(27.8)
Distributions received from unconsolidated affiliates	24.3	24.7
Other	(1.9)	3.7
Net cash provided by operating activities	57.5	57.6
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(5.3)	(16.8)
Investment expenditures	(9.1)	(5.9)
Distributions received from unconsolidated affiliates	5.0
Purchases of available-for-sale securities		(548.3)
Proceeds from sales and maturities of available-for-sale securities		576.4
Other		9.5
Net cash provided by (used in) investing activities	(9.4)	14.9
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt		(36.6)
Net increase in revolving credit facility borrowings		13.0
Net increase in commercial paper	13.0
Proceeds from notes payable-affiliates		6.5
Payments on notes payable-affiliates	(7.0)	(10.0)
Distributions to partners	(51.8)	(43.4)
Net cash used in financing activities	(45.8)	(70.5)
Net increase in cash and cash equivalents	2.3	2.0
Cash and cash equivalents at beginning of period	0.8	27.4
Cash and cash equivalents at end of period	3.1	29.4
Supplemental Disclosures
Property, plant and equipment noncash accruals	$ 1.7	$ 1.1

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Equity in Earnings of Unconsolidated Affiliates (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	$ 27.4	$ 27.8
Gulfstream
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	15.3	16.8
Market Hub
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates	$ 12.1	$ 11.0

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Investments in Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2012

Investments in Unconsolidated Affiliates

Investments in Unconsolidated Affiliates

	March 31, 2012		December 31, 2011
	(in millions)
Gulfstream	$	354.8	$	360.0
Market Hub		379.4		367.2
Total	$	734.2	$	727.2

Equity in Earnings of Unconsolidated Affiliates

Equity in Earnings of Unconsolidated Affiliates

	Three Months Ended March 31,
	2012		2011
	(in millions)
Gulfstream	$	15.3	$	16.8
Market Hub		12.1		11.0
Total	$	27.4	$	27.8

Summarized Financial Information of Unconsolidated Affiliates Presented at 100 Percent

Summarized Financial Information of Unconsolidated Affiliates

(Presented at 100%)

	Three Months Ended March 31,
	2012		2011
	(in millions)
Gulfstream
Operating revenues	$	67.7	$	66.9
Operating expenses		19.0		15.8
Operating income		48.7		51.1
Net income		31.2		34.3
Market Hub
Operating revenues	$	31.2	$	30.1
Operating expenses		7.0		8.0
Operating income		24.2		22.1
Net income		24.2		22.1

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Summarized Financial Information of Unconsolidated Affiliates Presented at 100 Percent (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 61.9	$ 51.2
Operating expenses	28.8	26.1
Operating income	33.1	25.1
Net income	52.4	48.9
Gulfstream
Schedule of Equity Method Investments [Line Items]
Operating revenues	67.7	66.9
Operating expenses	19.0	15.8
Operating income	48.7	51.1
Net income	31.2	34.3
Market Hub
Schedule of Equity Method Investments [Line Items]
Operating revenues	31.2	30.1
Operating expenses	7.0	8.0
Operating income	24.2	22.1
Net income	$ 24.2	$ 22.1

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2012

Fair Values of Financial Instruments That are Recorded and Carried at Book Value

The fair values of financial instruments that are recorded and carried at book value are summarized in the following table. Judgment is required in interpreting market data to develop the estimates of fair value. These estimates are not necessarily indicative of the amounts we could have realized in current markets. The fair values of long-term debt, including current maturities are determined based on market-based prices which may include inputs such as quoted market prices of the exact or similar instruments, broker or dealer quotations, or alternative pricing sources that may include models or matrix pricing tools, with reasonable levels of price transparency.

	March 31, 2012				December 31, 2011
Condensed Consolidated Balance Sheet Caption	Book Value		Approximate Fair Value		Book Value		Approximate Fair Value
	(in millions)
Current maturities of long-term debt(a)	$	150.0	$	153.6	$	150.0	$	154.3
Long-term debt (b)	$	500.0	$	513.9	$	500.0	$	514.8

(a) East Tennessee debt due in 2012

(b) Excludes unamortized items

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CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL (USD $) In Millions	Total	Limited Partners Common	General Partner	Accumulated Other Comprehensive Income (Loss)
Beginning Balance at Dec. 31, 2010	$ 1,494.4	$ 1,458.7	$ 32.9	$ 2.8
Net income	48.9	44.6	4.3
Reclassification of cash flow hedges into earnings	1.0			1.0
Distributions to partners	(43.4)	(40.1)	(3.3)
Ending Balance at Mar. 31, 2011	1,500.9	1,463.2	33.9	3.8
Beginning Balance at Dec. 31, 2011	1,697.7	1,653.6	39.6	4.5
Net income	52.4	45.9	6.5
Reclassification of cash flow hedges into earnings	(0.1)			(0.1)
Attributed deferred tax expense	(0.1)	(0.1)
Distributions to partners	(51.8)	(45.8)	(6.0)
Ending Balance at Mar. 31, 2012	$ 1,698.1	$ 1,653.6	$ 40.1	$ 4.4

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net income	$ 52.4	$ 48.9
Other comprehensive income
Reclassification of cash flow hedges into earnings	(0.1)	1.0
Comprehensive Income	$ 52.3	$ 49.9

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Risk Management and Hedging Activities

3 Months Ended

Mar. 31, 2012

Risk Management and Hedging Activities

10. Risk Management and Hedging Activities

We are exposed to the impact of changes in interest rates as a result of our issuance of variable and fixed-rate debt and commercial paper. We manage our interest rate exposure by limiting our variable-rate exposures and by monitoring the effects of market changes in interest rates. As of March 31, 2012 and December 31, 2011, we did not have any derivatives outstanding.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2012
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Trading Symbol	SEP
Entity Registrant Name	SPECTRA ENERGY PARTNERS, LP
Entity Central Index Key	0001394074
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	96,355,150
Entity General Partner, Units Outstanding	1,966,432

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New Accounting Pronouncement

3 Months Ended

Mar. 31, 2012

New Accounting Pronouncement

11. New Accounting Pronouncement

There were no significant accounting pronouncements adopted during the three months ended March 31, 2012 that had a material impact on our consolidated results of operations, financial position or cash flows.

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CONDENSED CONSOLIDATED BALANCE SHEETS (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Current Assets
Cash and cash equivalents	$ 3.1	$ 0.8
Receivables, net	26.9	30.3
Other	7.5	10.5
Total current assets	37.5	41.6
Investments and Other Assets
Investments in unconsolidated affiliates	734.2	727.2
Goodwill and other	461.8	461.8
Total investments and other assets	1,196.0	1,189.0
Property, Plant and Equipment
Cost	1,443.3	1,439.3
Less accumulated depreciation and amortization	243.1	234.1
Net property, plant and equipment	1,200.2	1,205.2
Regulatory Assets and Deferred Debits	20.6	21.1
Total Assets	2,454.3	2,456.9
Current Liabilities
Accounts payable	8.7	20.7
Taxes accrued	6.4	7.1
Note payable-affiliates	23.5	30.5
Current maturities of long-term debt	150.0	150.0
Commercial Paper	40.0	27.0
Other	14.3	10.6
Total current liabilities	242.9	245.9
Long-term Debt	499.5	499.4
Deferred Credits and Other Liabilities
Deferred income taxes	8.3	8.0
Other	5.5	5.9
Total deferred credits and other liabilities	13.8	13.9
Commitments and Contingencies
Partners' Capital
Common units (96.3 million units issued and outstanding at March 31, 2012 and December 31, 2011)	1,653.6	1,653.6
General partner units (2.0 million units issued and outstanding at March 31, 2012 and December 31, 2011)	40.1	39.6
Accumulated other comprehensive income	4.4	4.5
Total partners' capital	1,698.1	1,697.7
Total Liabilities and Partners' Capital	$ 2,454.3	$ 2,456.9

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Investments in Unconsolidated Affiliates

3 Months Ended

Mar. 31, 2012

Investments in Unconsolidated Affiliates

5. Investments in Unconsolidated Affiliates

As of March 31, 2012, our investments in unconsolidated affiliates consist of a 49% interest in Gulfstream and a 50% interest in Market Hub, both of which are accounted for using the equity method.

For the three months ended March 31, 2012, we received total distributions of $20.3 million from Gulfstream, of which $15.3 million were included in Cash Flows From Operating Activities—Distributions Received From Unconsolidated Affiliates and $5.0 million were included in Cash Flows From Investing Activities—Distributions Received From Unconsolidated Affiliates. For the three months ended March 31, 2011, we received total distributions of $13.2 million, all of which were included in Cash Flows From Operating Activities—Distributions Received From Unconsolidated Affiliates.

We received distributions from Market Hub of $9.0 million during the three months ended March 31, 2012 and $11.5 million during the same period in 2011, all of which were included in Cash Flows From Operating Activities—Distributions Received From Unconsolidated Affiliates.

Investments in Unconsolidated Affiliates

	March 31, 2012		December 31, 2011
	(in millions)
Gulfstream	$	354.8	$	360.0
Market Hub		379.4		367.2
Total	$	734.2	$	727.2

Equity in Earnings of Unconsolidated Affiliates

	Three Months Ended March 31,
	2012		2011
	(in millions)
Gulfstream	$	15.3	$	16.8
Market Hub		12.1		11.0
Total	$	27.4	$	27.8

Summarized Financial Information of Unconsolidated Affiliates

(Presented at 100%)

	Three Months Ended March 31,
	2012		2011
	(in millions)
Gulfstream
Operating revenues	$	67.7	$	66.9
Operating expenses		19.0		15.8
Operating income		48.7		51.1
Net income		31.2		34.3
Market Hub
Operating revenues	$	31.2	$	30.1
Operating expenses		7.0		8.0
Operating income		24.2		22.1
Net income		24.2		22.1

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Net Income Per Limited Partner Unit and Cash Distributions

3 Months Ended

Mar. 31, 2012

Net Income Per Limited Partner Unit and Cash Distributions

4. Net Income Per Limited Partner Unit and Cash Distributions

The following table presents our net income per limited partner unit calculations.

	Three Months Ended March 31,
	2012		2011
	(in millions, except per unit amounts)
Net income	$	52.4	$	48.9
Less:
General partner’s interest in net income—2%		1.1		1.0
General partner’s interest in net income attributable to incentive distribution rights		5.4		3.3
Limited partners’ interest in net income	$	45.9	$	44.6
Weighted average limited partner units outstanding—basic and diluted		96.3		89.2
Net income per limited partner unit—basic and diluted	$	0.48	$	0.50

The partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our Available Cash, as defined, to unitholders of record on the applicable record date.

Available Cash. Available Cash, for any quarter, consists of all cash on hand at the end of that quarter:

• less the amount of cash reserves established by the general partner to:

• provide for the proper conduct of business,

• comply with applicable law, any debt instrument or other agreement, or

• provide funds for distributions to the unitholders and to the general partner for any one or more of the next four quarters,

• plus, if the general partner so determines, all or a portion of cash on hand on the date of determination of Available Cash for the quarter.

Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:

	Total Quarterly Distribution	Marginal Percentage Interest in Distributions
	Target Per-Unit Amount	Common and Subordinated Unitholders			General Partner
Minimum Quarterly Distribution	$0.30		98	%		2	%
First Target Distribution	up to $0.345		98	%		2	%
Second Target Distribution	above $0.345 up to $0.375		85	%		15	%
Third Target Distribution	above $0.375 up to $0.45		75	%		25	%
Thereafter	above $0.45		50	%		50	%

To the extent these incentive distributions are made to our general partner, there will be more Available Cash proportionately allocated to our general partner than to holders of common units. Our distribution of $0.48 per limited partner unit will be paid on May 15, 2012.

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Debt and Credit Facility (Tables)

3 Months Ended

Mar. 31, 2012

Credit Facility Summary

Debt and Credit Facility

	Expiration Date		Total Credit Facility Capacity		Outstanding at March 31, 2012
					Commercial Paper		Available Credit Facility Capacity
					(in millions)
Spectra Energy Partners, LP		2016	$	700.0	$	40.0	$	660.0

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General (Tables)

3 Months Ended

Mar. 31, 2012

Correction and Changes in Presentation Reflected on Condensed Consolidated Statement of Cash Flows

The correction and change in presentation reflected on the Condensed Consolidated Statement of Cash Flows are as follows:

Three Months Ended March 31, 2011	Proceeds from the Issuance of Long-Term Debt			Payments for the Redemption of Long-Term Debt
	(in millions)
As previously reported	$	918.7		$	942.3
Less non-cash activity		(895.8	)		(895.8	)
As corrected		22.9			46.5
Less revolving credit facility activity		(22.9	)		(9.9	)
Long-term debt activity	$	—		$	36.6

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Fair Value Measurements

3 Months Ended

Mar. 31, 2012

Fair Value Measurements

8. Fair Value Measurements

Financial Instruments. The fair values of financial instruments that are recorded and carried at book value are summarized in the following table. Judgment is required in interpreting market data to develop the estimates of fair value. These estimates are not necessarily indicative of the amounts we could have realized in current markets. The fair values of long-term debt, including current maturities are determined based on market-based prices which may include inputs such as quoted market prices of the exact or similar instruments, broker or dealer quotations, or alternative pricing sources that may include models or matrix pricing tools, with reasonable levels of price transparency.

	March 31, 2012				December 31, 2011
Condensed Consolidated Balance Sheet Caption	Book Value		Approximate Fair Value		Book Value		Approximate Fair Value
	(in millions)
Current maturities of long-term debt(a)	$	150.0	$	153.6	$	150.0	$	154.3
Long-term debt (b)	$	500.0	$	513.9	$	500.0	$	514.8

(a) East Tennessee debt due in 2012

(b) Excludes unamortized items

The fair value of cash and cash equivalents, accounts receivable, accounts payable, commercial paper and note payable—affiliates are not materially different from their carrying amounts because of the short-term nature of these instruments or because the stated rates approximate market rates.

During 2012 and 2011, there were no material adjustments to assets and liabilities measured at fair value on a nonrecurring basis.

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Marketable Securities

3 Months Ended

Mar. 31, 2012

Marketable Securities

6. Marketable Securities

We may actively invest a portion of our cash balances in various financial instruments, including taxable debt securities. In addition, we invest in short-term money market securities, some of which are restricted due to debt collateral requirements. We classify all short-term money market securities that are pledged as collateral as available-for-sale (AFS). We do not purchase marketable securities for speculative purposes, nor do we routinely sell marketable securities prior to their scheduled maturity dates. Therefore, we do not have any securities classified as trading securities. Initial investments in securities are classified as purchases of the respective type of securities (available-for-sale or held-to-maturity), and maturities of securities are classified within proceeds from sales and maturities of securities in the Condensed Consolidated Statements of Cash Flows. As of March 31, 2012, there were no marketable securities outstanding.

In the fourth quarter of 2010, we invested in commercial paper with a portion of the proceeds from the equity issuance related to the Gulfstream acquisition. In June 2011, these investments were liquidated.

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Debt and Credit Facility

3 Months Ended

Mar. 31, 2012

Debt and Credit Facility

7. Debt and Credit Facility

	Expiration Date		Total Credit Facility Capacity		Outstanding at March 31, 2012
					Commercial Paper		Available Credit Facility Capacity
					(in millions)
Spectra Energy Partners, LP		2016	$	700.0	$	40.0	$	660.0

The issuances of commercial paper, letters of credit and revolving borrowings reduce the amount available under the credit facility. As of March 31, 2012, there were no letters of credit and revolving borrowings outstanding.

The credit agreement contains various financial and other covenants, including the maintenance of a consolidated leverage ratio, as defined in the agreement. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreement. As of March 31, 2012, we were in compliance with those covenants. In addition, the credit agreement allows for the acceleration of payments or termination of the agreement due to nonpayment, or in some cases, due to the acceleration of our other significant indebtedness or other significant indebtedness of some of our subsidiaries. The credit agreement does not contain provisions that trigger an acceleration of indebtedness based solely on the occurrence of an adverse change in our financial condition or results of operations.

As noted above, the terms of the credit agreement requires us to maintain a consolidated leverage ratio of adjusted consolidated indebtedness to adjusted consolidated earnings before interest, taxes, depreciation and amortization (EBITDA), as defined in the agreement, of 5.0 or less. As of March 31, 2012, the consolidated leverage ratio was 2.7.

Adjusted EBITDA is a non-GAAP measure. Our definition of Adjusted EBITDA may not be comparable to similarly titled measures of other companies because our definition excludes some, but not all, items that affect net income and is defined in varying ways by companies in our industry. Adjusted EBITDA should not be considered an alternative to net income, operating income, cash from operations or any other measure of financial performance or liquidity presented in accordance with GAAP.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2012

Commitments and Contingencies

9. Commitments and Contingencies

Environmental. We are subject to various federal, state and local laws and regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These laws and regulations can change from time to time, imposing new obligations on us. We believe there are no matters outstanding that, upon resolution, will have a material effect on our consolidated results of operations, financial position or cash flows.

Litigation. We are involved in legal, tax and regulatory proceedings in various forums arising in the ordinary course of business, including matters regarding contracts and payment claims, some of which may involve substantial monetary amounts. We have insurance coverage for certain of these losses should they be incurred. We believe that the final disposition of these proceedings will not have a material effect on our consolidated results of operations, financial position or cash flows.

Legal costs related to the defense of loss contingencies are expensed as incurred. We had no material reserves recorded as of March 31, 2012 or December 31, 2011 related to litigation.

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Investments in Unconsolidated Affiliates (Detail) (USD $) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 734.2	$ 727.2
Gulfstream
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	354.8	360.0
Market Hub
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 379.4	$ 367.2

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Net Income Per Limited Partner Unit and Cash Distributions (Tables)

3 Months Ended

Mar. 31, 2012

Net Income per Limited Partner Unit Calculations

The following table presents our net income per limited partner unit calculations.

	Three Months Ended March 31,
	2012		2011
	(in millions, except per unit amounts)
Net income	$	52.4	$	48.9
Less:
General partner’s interest in net income—2%		1.1		1.0
General partner’s interest in net income attributable to incentive distribution rights		5.4		3.3
Limited partners’ interest in net income	$	45.9	$	44.6
Weighted average limited partner units outstanding—basic and diluted		96.3		89.2
Net income per limited partner unit—basic and diluted	$	0.48	$	0.50

Incentive Distribution Rights in Accordance with Partnership Agreement

Incentive Distribution Rights. The general partner holds incentive distribution rights beyond the first target distribution in accordance with the partnership agreement as follows:

	Total Quarterly Distribution	Marginal Percentage Interest in Distributions
	Target Per-Unit Amount	Common and Subordinated Unitholders			General Partner
Minimum Quarterly Distribution	$0.30		98	%		2	%
First Target Distribution	up to $0.345		98	%		2	%
Second Target Distribution	above $0.345 up to $0.375		85	%		15	%
Third Target Distribution	above $0.375 up to $0.45		75	%		25	%
Thereafter	above $0.45		50	%		50	%

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Correction and Changes in Presentation Reflected on Condensed Consolidated Statement of Cash Flows (Detail) (USD $) In Millions, unless otherwise specified	3 Months Ended
	Mar. 31, 2011
Payments for the Redemption of Long-Term Debt	$ 36.6
As previously reported
Proceeds from the Issuance of Long-Term Debt	918.7
Payments for the Redemption of Long-Term Debt	942.3
Non Cash Activity
Proceeds from the Issuance of Long-Term Debt	(895.8)
Payments for the Redemption of Long-Term Debt	(895.8)
As corrected
Proceeds from the Issuance of Long-Term Debt	22.9
Payments for the Redemption of Long-Term Debt	46.5
Revolving credit facility activity
Proceeds from the Issuance of Long-Term Debt	(22.9)
Payments for the Redemption of Long-Term Debt	$ (9.9)

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) In Millions, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Common units, units issued	96.3	96.3
Common units, units outstanding	96.3	96.3
General partner units, units issued	2.0	2.0
General partner units, units outstanding	2.0	2.0

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Business Segments

3 Months Ended

Mar. 31, 2012

Business Segments

3. Business Segments

Our Gas Transportation and Storage segment aligns our operations with the chief operating decision makers’ view of the business. This business segment is considered to be our sole reportable segment.

The Gas Transportation and Storage segment provides interstate transportation, storage and gathering services of natural gas, and the storage and redelivery of liquefied natural gas for customers in the southeastern quadrant of the United States. Substantially all of our operations are subject to the FERC and the Department of Transportation’s (DOT) rules and regulations. This segment includes East Tennessee Natural Gas, LLC (East Tennessee), Ozark Gas Transmission, L.L.C. (Ozark Gas Transmission) and Ozark Gas Gathering, L.L.C. (Ozark Gas Gathering) (collectively, hereafter referred to as “Ozark”), Saltville Gas Storage, L.L.C. (Saltville), and Big Sandy.

The remainder of our operations is presented as “Other.” While it is not considered a business segment, Other mainly includes our equity investments in Gulfstream Natural Gas System, L.L.C. (Gulfstream) and Market Hub Partners Holding (Market Hub) and unallocated corporate costs.

Gulfstream provides interstate natural gas pipeline transportation from Pascagoula, Mississippi and Mobile, Alabama across the Gulf of Mexico into Florida for customers in central and southern Florida. Gulfstream’s operations are subject to the rules and regulations of the FERC and DOT.

Market Hub owns and operates two natural gas storage facilities, Moss Bluff and Egan, which are located in southeast Texas and south central Louisiana, respectively. Market Hub’s operations are subject to the rules and regulations of DOT. Moss Bluff is also subject to the rules and regulations of the Texas Railroad Commission, while Egan is also subject to the rules and regulations of the FERC.

Management evaluates segment performance based on earnings before interest and taxes from continuing operations (EBIT). On a segment basis, EBIT represents all profits from continuing operations (both operating and non-operating) before deducting interest and income taxes.

Business Segment Data

	Three Months Ended March 31,
	2012		2011
	(in millions)
Operating revenues
Gas Transportation and Storage	$	61.9	$	51.2
Other		—		—
Total operating revenues	$	61.9	$	51.2
Segment EBIT
Gas Transportation and Storage	$	35.1	$	27.8
Other		25.4		25.6
Total EBIT		60.5		53.4
Interest income		—		0.1
Interest expense		7.7		4.2
Earnings before income taxes	$	52.8	$	49.3

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Acquisitions - Additional Information (Detail) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Jul. 31, 2011 mi Bcf
Big Sandy
Business Acquisition [Line Items]
Purchase price	$ 390
Length of pipeline	68
Capacity per day	0.2
EQT
Business Acquisition [Line Items]
Percentage of pipeline capacity to be shipped by EQT	80.00%
Percentage of fee based revenues	100.00%
Transportation agreement with EQT (in years)	14

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Debt and Credit Facility - Additional Information (Detail)	Mar. 31, 2012
Debt Instrument [Line Items]
Debt-to-Adjusted EBITDA ratio maximum	5.0
Debt-to-Adjusted EBITDA ratio	2.7

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Business Segments (Tables)

3 Months Ended

Mar. 31, 2012

Business Segment Data

Business Segment Data

	Three Months Ended March 31,
	2012		2011
	(in millions)
Operating revenues
Gas Transportation and Storage	$	61.9	$	51.2
Other		—		—
Total operating revenues	$	61.9	$	51.2
Segment EBIT
Gas Transportation and Storage	$	35.1	$	27.8
Other		25.4		25.6
Total EBIT		60.5		53.4
Interest income		—		0.1
Interest expense		7.7		4.2
Earnings before income taxes	$	52.8	$	49.3