10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended June 30, 2015

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	Exact name of registrants as specified in their charters, address of principal executive offices and registrants’ telephone  number	I.R.S. Employer Identification Number
001-36684	Dominion Midstream Partners, LP 120 Tredegar Street Richmond, Virginia 23219 (804) 819-2000	46-5135781

State or other jurisdiction of incorporation or organization of the registrant: Delaware

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

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

The registrant had 37,092,305 common units and 31,972,789 subordinated units outstanding as of June 30, 2015.

INDEX

		Page Number
	Glossary of Terms		3
	PART I. Financial Information
Item 1.	Financial Statements		5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		23
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		33
Item 4.	Controls and Procedures		33
	PART II. Other Information
Item 1.	Legal Proceedings		34
Item 1A.	Risk Factors		34
Item 6.	Exhibits		35

Unless the context otherwise requires, references in this Quarterly Report on Form 10-Q to “Cove Point,” “the Predecessor,” “our predecessor,” and “we,” “our,” “us,” “our partnership” or like terms when used in a historical context (periods prior to October 20, 2014), refer to Dominion Cove Point LNG, LP as our predecessor for accounting purposes. When used in the present tense or prospectively (periods beginning October 20, 2014), “Dominion Midstream,” “we,” “our,” “us” or like terms refer to Dominion Midstream Partners, LP; one of its wholly-owned subsidiaries, Cove Point GP Holding Company, LLC or Dominion Carolina Gas Transmission, LLC (beginning April 1, 2015); or all of them taken as a whole.

2

GLOSSARY OF TERMS

The following abbreviations or acronyms used in this Form 10-Q are defined below:

Abbreviation or Acronym	Definition
2005 Agreement	An agreement effective March 1, 2005, in which Cove Point entered into a new agreement with the Sierra Club and the Maryland Conservation Council, Inc.
Additional Return Distributions	The additional cash distribution equal to 3.0% of Cove Point’s Modified Net Operating Income in excess of $600 million distributed each year
Adjusted EBITDA	EBITDA after adjustment for EBITDA attributable to the DCGT Predecessor and a noncontrolling interest in Cove Point held by Dominion subsequent to the Offering
AFUDC	Allowance for funds used during construction
ARO	Asset retirement obligation
CAA	Clean Air Act
CEO	Chief Executive Officer
CFO	Chief Financial Officer
Columbia to Eastover Project	Project to provide 15,800 Dths/day of firm transportation service from an existing interconnect with Southern Natural Gas Company, LLC in Aiken County, South Carolina and provide for a receipt point change of 2,200 Dths/day under an existing contract from an existing interconnect with Transco in Cherokee County, South Carolina for a total 18,000 Dths/day, to a new delivery point for the International Paper Company at its pulp and paper mill known as the Eastover Plant in Richland County, South Carolina
Cove Point	Dominion Cove Point LNG, LP
Cove Point Holdings	Cove Point GP Holding Company, LLC
Cove Point LNG Facility	An LNG import/regasification and storage facility located on the Chesapeake Bay in Lusby, Maryland owned by Cove Point
Cove Point Pipeline	An approximately 136-mile natural gas pipeline owned by Cove Point that connects the Cove Point LNG Facility to interstate natural gas pipelines
CPCN	Certificate of Public Convenience and Necessity
D.C.	District of Columbia
DCGT	Dominion Carolina Gas Transmission, LLC (successor by statutory conversion to and formerly known as Carolina Gas Transmission Corporation)
DCGT Acquisition	The acquisition of DCGT by Dominion Midstream from Dominion on April 1, 2015
DCGT Predecessor	Dominion as the predecessor for accounting purposes for the period from Dominion’s acquisition of DCGT from SCANA on January 31, 2015 until the DCGT Acquisition
DCPI	Dominion Cove Point, Inc.
Dominion	The legal entity, Dominion Resources, Inc., one or more of its consolidated subsidiaries (other than Dominion Midstream GP, LLC and its subsidiaries) or operating segments or the entirety of Dominion Resources, Inc. and its consolidated subsidiaries
Dominion Midstream	The legal entity, Dominion Midstream Partners, LP, one or more of its consolidated subsidiaries, Cove Point Holdings and DCGT (beginning April 1, 2015), or the entirety of Dominion Midstream Partners, LP and its consolidated subsidiaries
Dominion Payroll	Dominion Payroll Company, Inc.
DRS	Dominion Resources Services, Inc.
Dth	Dekatherm
EBITDA	Earnings before interest and associated charges, income tax expense, depreciation and amortization
Edgemoor Project	Project to provide 45,000 Dths/day of firm transportation service from an existing interconnect with Transco in Cherokee County, South Carolina to customers in Calhoun and Lexington Counties, South Carolina
EPA	Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
GAAP	U.S. generally accepted accounting principles
GHG	Greenhouse gas
IDR	Incentive distribution right
Import Shippers	The three LNG import shippers consisting of BP Energy Company, Shell NA LNG, Inc. and Statoil Natural Gas, LLC
Keys Energy Project	Project to provide 107,000 Dths/day of firm transportation service from Cove Point’s interconnect with Transco in Fairfax County, Virginia to Keys Energy Center, LLC’s power generating facility in Prince George’s County, Maryland

3

Abbreviation or Acronym	Definition
Liquefaction Project	A natural gas liquefaction/export facility currently under construction by Cove Point
LNG	Liquefied natural gas
MD&A	Management’s Discussion and Analysis of Financial Condition and Results of Operations
MLP	Master limited partnership, equivalent to publicly traded partnership
Modified Net Operating Income	Cove Point’s Net Operating Income plus any interest expense included in the computation of Net Operating Income
Net Operating Income	Cove Point’s gross revenues from operations minus its interest expense and operating expenses, but excluding depreciation and amortization, as determined for U.S. federal income tax purposes
NGA	Natural Gas Act of 1938, as amended
Offering	The initial public offering of common units of Dominion Midstream
Preferred Equity Interest	A perpetual, non-convertible preferred equity interest in Cove Point entitled to the Preferred Return Distributions and the Additional Return Distributions
Preferred Return Distributions	The first $50.0 million of annual cash distributions made by Cove Point
SCANA	SCANA Corporation
SEC	Securities and Exchange Commission
St. Charles Transportation Project	Project to provide 132,000 Dths/day of firm transportation service from Cove Point’s interconnect with Transco in Fairfax County, Virginia to Competitive Power Venture Maryland, LLC’s power generating facility in Charles County, Maryland
Storage Customers	The four local distribution companies that receive firm peaking services from Cove Point, consisting of: Atlanta Gas Light Company, Public Service Company of North Carolina, Incorporated, Virginia Natural Gas, Inc. and Washington Gas Light Company
Transco	Transcontinental Gas Pipe Line Company, LLC
U.S.	United States of America

4

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,					Six Months Ended June 30,
	2015			2014		2015			2014
				(Predecessor)					(Predecessor)
(millions, except per unit data)
Operating Revenue(1)	$	105.4		$	111.2	$	183.8		$	180.1
Operating Expenses
Purchased gas(1)		25.5			47.8		29.4			53.1
Other operations and maintenance:
Affiliated suppliers		6.4			1.9		11.2			3.9
Other		9.6			8.9		18.1			17.3
Depreciation and amortization		9.9			7.9		20.5			15.7
Other taxes		6.8			5.5		12.7			11.1
Total operating expenses		58.2			72.0		91.9			101.1
Income from operations		47.2			39.2		91.9			79.0
Other income		0.2			—		0.4			—
Interest and related charges(1)		0.2			—		0.2			—
Income from operations including noncontrolling interest before income taxes		47.2			39.2		92.1			79.0
Income tax expense		—			15.0		2.1			30.2
Net income including noncontrolling interest and DCGT Predecessor	$	47.2		$	24.2	$	90.0		$	48.8
Less: Net income attributable to DCGT Predecessor		—					2.3
Net income including noncontrolling interest		47.2					87.7
Less: Net income attributable to noncontrolling interest		29.6					58.3
Net income attributable to partners	$	17.6				$	29.4
Net income attributable to partners’ ownership interest
General partner’s interest in net income	$	(0.7	)			$	(0.7	)
Common unitholders’ interest in net income		10.3					16.2
Subordinated unitholder’s interest in net income		8.0					13.9
Net income per limited partner unit (basic and diluted)
Common units	$	0.26				$	0.47
Subordinated units	$	0.26				$	0.44

(1) See Note 15 for amounts attributable to related parties.

The accompanying notes are an integral part of Dominion Midstream’s Consolidated Financial Statements.

5

DOMINION MIDSTREAM PARTNERS, LP

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2015			December 31, 2014
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	77.3		$	175.4
Customer and other receivables		28.7			19.9
Affiliated receivables		6.1			6.1
Prepayments		1.0			9.5
Materials and supplies		11.3			8.7
Regulatory assets		2.6			1.7
Other		5.2			4.7
Total current assets		132.2			226.0
Property, Plant and Equipment
Property, plant and equipment		3,152.8			2,203.1
Accumulated depreciation and amortization		(335.1	)		(231.2	)
Total property, plant and equipment, net		2,817.7			1,971.9
Deferred Charges and Other Assets
Goodwill		295.5			45.9
Intangible assets, net		16.3			12.1
Regulatory assets		2.6			2.5
Other		0.1			—
Total deferred charges and other assets		314.5			60.5
Total assets	$	3,264.4		$	2,258.4

The accompanying notes are an integral part of Dominion Midstream’s Consolidated Financial Statements.

6

DOMINION MIDSTREAM PARTNERS, LP

CONSOLIDATED BALANCE SHEETS (CONTINUED)

(Unaudited)

	June 30, 2015			December 31, 2014
(millions)
LIABILITIES AND EQUITY AND PARTNERS’ CAPITAL
Current Liabilities
Accounts payable	$	109.7		$	3.3
Payables to affiliates		5.3			2.5
Accrued payroll and taxes		3.6			1.5
Regulatory liabilities		7.2			3.6
Dominion credit facility borrowings		5.9			—
Deferred revenue		0.3			3.9
Natural gas imbalances(1)		3.5			2.7
CPCN obligation		7.9			7.9
Other		22.7			6.4
Total current liabilities		166.1			31.8
Affiliated Long-Term Debt		300.8			—
Deferred Credits and Other Liabilities
Pension and other postretirement benefit liabilities(1)		4.7			4.4
Regulatory liabilities		71.0			33.5
CPCN obligation		28.9			36.2
Asset retirement obligation		12.7			0.3
Other		2.7			1.4
Total deferred credits and other liabilities		120.0			75.8
Total liabilities		586.9			107.6
Commitments and Contingencies (see Note 13)
Equity and Partners’ Capital
Common unitholders - public (20,132,377 units issued and outstanding at June 30, 2015; 20,127,322 units issued and outstanding at December 31, 2014)		398.0			395.4
Common unitholder - Dominion (16,959,928 units issued and outstanding at June 30, 2015; 11,847,789 units issued and outstanding at December 31, 2014)		416.5			213.7
Subordinated unitholder - Dominion (31,972,789 units issued and outstanding at June 30, 2015 and December 31, 2014)		470.0			466.2
General Partner interest - Dominion (non-economic interest)		(12.6	)		—
Total Dominion Midstream Partners, LP partners’ capital		1,271.9			1,075.3
Noncontrolling interest		1,405.6			1,075.5
Total equity and partners’ capital		2,677.5			2,150.8
Total liabilities and equity and partners’ capital	$	3,264.4		$	2,258.4

(1) See Note 15 for amounts attributable to related parties.

The accompanying notes are an integral part of Dominion Midstream’s Consolidated Financial Statements.

7

DOMINION MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENT OF EQUITY AND PARTNERS’ CAPITAL

(Unaudited)

	Partnership
	DCGT Predecessor Equity			Common Unitholders Public			Common Unitholder Dominion			Subordinated Unitholder Dominion			General Partner Dominion (non- economic interest)			Total Dominion Midstream Partners, LP Partners’ Equity and Capital			Noncontrolling interest		Total Equity and Partners’ Capital
(millions)
December 31, 2014	$	—		$	395.4		$	213.7		$	466.2		$	—		$	1,075.3		$	1,075.5	$	2,150.8
Net income including noncontrolling interest		—			8.8			7.4			13.9			(0.7	)		29.4			58.3		87.7
DCGT Acquisition:
Record Dominion’s net investment in DCGT		497.0			—			—			—			—			497.0			—		497.0
Net income attributable to DCGT Predecessor		2.3			—			—			—			—			2.3			—		2.3
Contribution from Dominion to DCGT prior to DCGT Acquisition		2.3			—			—			—			—			2.3			—		2.3
Allocation of DCGT Predecessor investment		(501.6	)		—			—			—			501.6			—			—		—
Settlement of net current and deferred income tax assets		—			—			—			—			(13.4	)		(13.4	)		—		(13.4	)
Consideration provided to Dominion for DCGT Acquisition		—			—			200.0			—			(500.8	)		(300.8	)		—		(300.8	)
Equity contributions from Dominion		—			—			—			—			0.7			0.7			271.8		272.5
Distributions		—			(6.3	)		(4.6	)		(10.1	)		—			(21.0	)		—		(21.0	)
Unit awards (net of unearned compensation)		—			0.1			—			—			—			0.1			—		0.1
June 30, 2015	$	—		$	398.0		$	416.5		$	470.0		$	(12.6	)	$	1,271.9		$	1,405.6	$	2,677.5

The accompanying notes are an integral part of Dominion Midstream’s Consolidated Financial Statements.

8

DOMINION MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	2015			2014
Six Months Ended June 30,				(Predecessor)
(millions)
Operating Activities
Net income including noncontrolling interest and DCGT Predecessor	$	90.0		$	48.8
Adjustments to reconcile net income including noncontrolling interest and DCGT Predecessor to net cash provided by operating activities:
Depreciation and amortization		20.5			15.7
Deferred income taxes		1.5			10.4
Other adjustments to income, net		1.9			—
Changes in:
Customer and other receivables		(2.1	)		(26.5	)
Affiliated receivables		—			(1.6	)
Prepayments		8.6			(1.1	)
Accounts payable		(3.5	)		22.8
Payables to affiliates		3.0			1.5
Accrued payroll and taxes		1.4			(1.0	)
Other operating assets and liabilities		3.4			(2.8	)
Net cash provided by operating activities		124.7			66.2
Investing Activities
Plant construction and other property additions		(479.0	)		(222.3	)
Other		(1.6	)		(0.3	)
Net cash used in investing activities		(480.6	)		(222.6	)
Financing Activities
Dominion credit facility borrowings		5.9			—
Contributions from Dominion		273.1			145.2
Distributions to common unitholders - public		(6.3	)		—
Distribution to common unitholder - Dominion		(4.6	)		—
Distribution to subordinated unitholder - Dominion		(10.1	)
Other		(0.2	)		—
Net cash provided by financing activities		257.8			145.2
Decrease in cash and cash equivalents		(98.1	)		(11.2	)
Cash and cash equivalents at beginning of period		175.4			11.2
Cash and cash equivalents at end of period	$	77.3		$	—
Supplemental Cash Flow Information
Cash paid during the period for:
Income taxes	$	—		$	30.7
Significant noncash investing and financing activities:
Accrued capital expenditures		123.1			7.3
DCGT Acquisition through issuance of debt and equity		500.8			—
Settlement of net current and deferred income tax assets		13.4			—
Equity contribution from Dominion to relieve payables to affiliates		1.7			20.0

The accompanying notes are an integral part of Dominion Midstream’s Consolidated Financial Statements.

9

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1. Description of Business and Basis of Presentation

Description of Business

Dominion Midstream is a Delaware limited partnership formed on March 11, 2014 by Dominion MLP Holding Company, LLC and Dominion Midstream GP, LLC, both indirect wholly-owned subsidiaries of Dominion, to grow a portfolio of natural gas terminaling, processing, storage, transportation and related assets. On October 20, 2014, Dominion Midstream completed the Offering of 20,125,000 common units (including 2,625,000 common units issued pursuant to the exercise of the underwriters’ over-allotment option) representing limited partner interests. A registration statement on Form S-1, as amended through the time of its effectiveness, was filed by Dominion Midstream with the SEC and was declared effective on October 10, 2014.

Dominion Midstream acquired from Dominion the Preferred Equity Interest and non-economic general partner interest in Cove Point, the owner and operator of the Cove Point LNG Facility and the Cove Point Pipeline. The Preferred Equity Interest is a perpetual, non-convertible preferred equity interest entitled to Preferred Return Distributions so long as Cove Point has sufficient cash and undistributed Net Operating Income (determined on a cumulative basis from the closing of the Offering) from which to make Preferred Return Distributions. Preferred Return Distributions are made on a quarterly basis and are not cumulative. The Preferred Equity Interest is also entitled to the Additional Return Distributions.

On April 1, 2015, Dominion Midstream acquired from Dominion all issued and outstanding membership interests in DCGT as described further in Note 2. DCGT owns and operates nearly 1,500 miles of FERC-regulated open access, transportation-only interstate natural gas pipeline in South Carolina and southeastern Georgia.

Basis of Presentation

The contribution by Dominion to Dominion Midstream of the general partner interest in Cove Point and a portion of the Preferred Equity Interest is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis is equal to Dominion’s cost basis in the general partner interest in Cove Point and a portion of the Preferred Equity Interest. Dominion Midstream owns the general partner interest and controls Cove Point and therefore consolidates Cove Point. As such, Dominion Midstream’s investment in the Preferred Equity Interest and Cove Point’s preferred equity interest are eliminated in consolidation. Dominion’s retained common equity interest in Cove Point is reflected as noncontrolling interest.

The DCGT Acquisition is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis in DCGT is equal to Dominion’s cost basis in the assets and liabilities of DCGT. On April 1, 2015, DCGT became a wholly-owned subsidiary of Dominion Midstream and is therefore consolidated by Dominion Midstream. The accompanying financial statements and related notes have been retrospectively adjusted to include the historical results and financial position of DCGT beginning January 31, 2015, the inception date of common control.

For the period prior to the closing of the Offering on October 20, 2014, the financial statements included in this Quarterly Report on Form 10-Q were derived from the financial statements and accounting records of Cove Point, as our predecessor for accounting purposes. The financial statements were prepared using Dominion’s historical basis in the assets and liabilities of Cove Point and include all revenues, costs, assets and liabilities attributed to Cove Point. For the period subsequent to the closing of the Offering, the Consolidated Financial Statements represent the consolidated results of operations, financial position and cash flows of Dominion Midstream.

The financial statements for all periods presented include costs for certain general, administrative and corporate expenses assigned by DRS or Dominion Payroll to Dominion Midstream and Cove Point on the basis of direct and allocated methods in accordance with Dominion Midstream’s services agreements with DRS and Dominion Payroll and Cove Point’s services agreement with DRS. Where costs incurred cannot be determined by specific identification, the costs are allocated based on the proportional level of effort devoted by DRS or Dominion Payroll resources that is attributable to the entities, determined by reference to number of employees, salaries and wages and other similar measures for the relevant DRS or Dominion Payroll department. Management believes the assumptions and methodologies underlying the allocation of general corporate overhead expenses are reasonable. Nevertheless, the Consolidated Financial Statements prior to the Offering may not include all of the actual expenses that would have been incurred had we been a stand-alone publicly traded partnership during the periods presented, and may not reflect our actual results of operations, financial position and cash flows had we been a stand-alone publicly traded partnership during the periods prior to the Offering.

10

Note 2. Acquisition

DCGT

On April 1, 2015, Dominion Midstream entered into a Purchase, Sale and Contribution Agreement with Dominion pursuant to which Dominion Midstream purchased from Dominion all of the issued and outstanding membership interests of DCGT in exchange for total consideration of approximately $500.8 million, as adjusted for working capital. Total consideration to Dominion consisted of the issuance of a two-year $300.8 million senior unsecured promissory note, as adjusted for working capital, payable to Dominion at an annual interest rate of 0.6%, and 5,112,139 common units, valued at $200.0 million, representing limited partner interests in Dominion Midstream, to Dominion. The number of units was based on the volume weighted average trading price of Dominion Midstream’s common units for the 10 trading days prior to April 1, 2015, or $39.12 per unit. Total transaction and transition costs of $1.0 million associated with the DCGT Acquisition were expensed as incurred to operations and maintenance expense in the Consolidated Income Statement for the three months ended June 30, 2015. These costs were paid by Dominion. Dominion did not seek reimbursement for $0.7 million of such costs incurred during the three months ended June 30, 2015, and accordingly Dominion Midstream recognized a capital contribution by the general partner. The DCGT Acquisition supports the expansion of Dominion Midstream’s portfolio of natural gas terminaling, processing, storage, transportation and related assets.

The contribution of DCGT by Dominion to Dominion Midstream is considered to be a reorganization of entities under common control. Accordingly, Dominion Midstream’s net investment in DCGT is recorded at Dominion’s historical cost of $501.6 million as of April 1, 2015. Common control began on January 31, 2015, concurrent with Dominion’s acquisition of DCGT from SCANA, which was accounted for using the acquisition method of accounting. Accordingly, the Consolidated Financial Statements of Dominion Midstream reflect DCGT’s financial results beginning January 31, 2015.

In connection with the DCGT Acquisition, Dominion Midstream entered into a registration rights agreement with Dominion pursuant to which Dominion Midstream must register the 5,112,139 common units issued to Dominion at its request, subject to certain terms and conditions. Additionally, at the time of Dominion’s acquisition of DCGT, DCGT entered into services agreements and an intercompany tax sharing agreement with Dominion as described in Note 15.

The assets and liabilities of DCGT are included in the Consolidated Balance Sheet as of June 30, 2015. The results of operations of DCGT are included in the Consolidated Statement of Income for the three months ended June 30, 2015. The following table presents Dominion Midstream’s Consolidated Statement of Income for the six months ended June 30, 2015 giving effect to the DCGT Acquisition. The results of DCGT from January 31, 2015 through March 31, 2015 are included in “DCGT Predecessor.” The results of DCGT beginning on April 1, 2015 are included in “Dominion Midstream.”

11

	Six Months Ended June 30, 2015
	Dominion Midstream		DCGT Predecessor		Dominion Midstream (as reported)
(in millions)
Operating Revenue	$	172.6	$	11.2	$	183.8
Operating Expenses
Purchased gas		29.4		—		29.4
Other operations and maintenance:
Affiliated suppliers		8.7		2.5		11.2
Other		15.8		2.3		18.1
Depreciation and amortization		19.2		1.3		20.5
Other taxes		11.9		0.8		12.7
Total operating expenses		85.0		6.9		91.9
Income from operations		87.6		4.3		91.9
Other income		0.3		0.1		0.4
Interest and related charges		0.2		—		0.2
Income from operations including noncontrolling interest before income taxes		87.7		4.4		92.1
Income tax expense		—		2.1		2.1
Net income including noncontrolling interest and DCGT Predecessor		87.7		2.3		90.0
Less: Net income attributable to DCGT Predecessor		—		2.3		2.3
Net income including noncontrolling interest		87.7		—		87.7
Less: Net income attributable to noncontrolling interest		58.3		—		58.3
Net income attributable to partners	$	29.4	$	—	$	29.4

Note 3. Significant Accounting Policies

Interim Financial Information and Estimates

As permitted by the rules and regulations of the SEC, Dominion Midstream’s accompanying unaudited Consolidated Financial Statements exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014.

In the opinion of management, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly Dominion Midstream’s financial position as of June 30, 2015, its results of operations for the three and six months ended June 30, 2015 and 2014, and its cash flows and changes in equity for the six months ended June 30, 2015 and 2014. Such adjustments are normal and recurring in nature unless otherwise noted.

Dominion Midstream makes certain estimates and assumptions in preparing its Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses for the periods presented. Actual results may differ from those estimates.

The results of operations for interim periods are not necessarily indicative of the results expected for the full year. Information for quarterly periods is affected by seasonal variations in sales, rate changes, purchased gas expenses and other factors.

Asset Retirement Obligations

Dominion Midstream recognizes AROs at fair value as incurred or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, Dominion Midstream evaluates the key assumptions underlying its

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AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion Midstream reports accretion of AROs and depreciation on asset retirement costs associated with its natural gas pipeline assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs.

Note 4. Net Income Per Limited Partner Unit

Net income per limited partner unit applicable to common and subordinated units is computed by dividing the respective limited partners’ interest in net income attributable to Dominion Midstream, after deducting any incentive distributions, by the weighted average number of common units and subordinated units outstanding. Because Dominion Midstream has more than one class of participating securities, the two-class method is used when calculating the net income per unit applicable to limited partners. The classes of participating securities include common units, subordinated units, and IDRs.

Dominion Midstream’s net income is allocated to the limited partners in accordance with their respective partnership percentages, after giving effect to priority income allocations for incentive distributions, if any, to Dominion, the holder of the IDRs, pursuant to the partnership agreement. The distributions are declared and paid following the close of each quarter. Earnings in excess of distributions are allocated to the limited partners based on their respective ownership interests. Payments made to Dominion Midstream’s unitholders are determined in relation to actual distributions declared and are not based on the net income allocations used in the calculation of earnings per limited partner unit.

Net income per limited partner unit is only calculated for the periods subsequent to the Offering as no units were outstanding prior to October 20, 2014. Diluted net income per limited partner unit is the same as basic net income per limited partner unit as there were no potentially dilutive common or subordinated units outstanding as of June 30, 2015.

The calculation of earnings per limited partner unit is as follows:

	Three Months Ended June 30, 2015			Six Months Ended June 30, 2015
(millions)
Net income attributable to partners	$	17.6		$	29.4
Less: General partner allocation(1)		(0.7	)		(0.7	)
Distributions declared on:
Incentive distribution holder rights(2)		—			—
Common units(3)		6.9			13.4
Subordinated units(3)		6.0			11.6
Total distributions declared		12.9			25.0
Undistributed earnings	$	5.4		$	5.1

(1) See Note 2 for further information.

(2) Dominion is a non-economic general partner that holds all of the IDRs.

(3) On July 17, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1875 per unit, totaling $12.9 million, for the three months ended June 30, 2015. This distribution will be paid on August 14, 2015 to unitholders of record on August 4, 2015. The amount of distributions declared shown above is based on the units outstanding at June 30, 2015.

On April 22, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1750 per unit, totaling $12.1 million, for the three months ended March 31, 2015. This distribution was paid on May 15, 2015 to unitholders of record on May 5, 2015.

Basic and diluted net income per limited partner unit
Three Months Ended June 30, 2015	Common Units		Subordinated Units		General Partner			Total
(millions, except for weighted average units and per unit data)
General partner allocation	$	—	$	—	$	(0.7	)	$	(0.7	)
Distributions declared		6.9		6.0		—			12.9
Undistributed earnings		2.9		2.5		—			5.4
Net income attributable to partners	$	9.8	$	8.5	$	(0.7	)	$	17.6
Weighted average units outstanding		37,092,305		31,972,789
Net income per limited partner unit	$	0.26	$	0.26

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Basic and diluted net income per limited partner unit
Six Months Ended June 30, 2015	Common Units		Subordinated Units		General Partner			Total
(millions, except for weighted average units and per unit data)
General partner allocation	$	—	$	—	$	(0.7	)	$	(0.7	)
Distributions declared		13.4		11.6		—			25.0
Undistributed earnings		2.6		2.5		—			5.1
Net income attributable to partners	$	16.0	$	14.1	$	(0.7	)	$	29.4
Weighted average units outstanding		34,550,329		31,972,789
Net income per limited partner unit	$	0.47	$	0.44

Note 5. Unit Activity

Activity in the number of units was as follows:

	Common
	Public		Dominion		Subordinated		General Partner		Total
							(non-economic interest)
Balance at December 31, 2014		20,127,322		11,847,789		31,972,789		—		63,947,900
Unit-based compensation		5,055		—		—		—		5,055
Units issued in connection with the DCGT Acquisition		—		5,112,139		—		—		5,112,139
Balance at June 30, 2015		20,132,377		16,959,928		31,972,789		—		69,065,094

Note 6. Operating Revenue

Dominion Midstream’s operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(millions)
Gas transportation and storage	$	78.9	$	64.9	$	153.6	$	130.5
Other		26.5		46.3		30.2		49.6
Total operating revenue	$	105.4	$	111.2	$	183.8	$	180.1

Note 7. Property, Plant and Equipment

Major classes of property, plant and equipment and their respective balances for Dominion Midstream are as follows:

	June 30, 2015		December 31, 2014
(millions)
Storage	$	875.1	$	882.0
Transmission		666.2		323.9
Plant under construction		1,575.6		972.3
General and other		35.9		24.9
Total property, plant and equipment	$	3,152.8	$	2,203.1

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The increase in property, plant and equipment is primarily related to the DCGT Acquisition and capital expenditures for the Liquefaction Project.

During the six months ended June 30, 2015, Dominion Midstream capitalized interest costs and AFUDC of $0.6 million to property, plant and equipment. No such costs were capitalized in 2014.

Depreciation rates on utility property, plant and equipment are as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(percent)
Storage		2.39		2.38		2.38		2.38
Transmission		2.28		2.82		2.28		2.82
General and other		7.68		4.24		7.65		3.58

Note 8. Goodwill and Intangible Assets

Goodwill

The changes in Dominion Midstream’s carrying amount and segment allocation of goodwill are presented below:

	Dominion Energy		Corporate and Other		Total
(millions)
Six Months Ended June 30, 2015
Beginning balance(1)	$	45.9	$	—	$	45.9
DCGT Acquisition		249.6		—		249.6
Ending balance(1)	$	295.5	$	—	$	295.5

(1) There are no accumulated impairment losses.

Other Intangible Assets

Dominion Midstream’s other intangible assets are subject to amortization over their estimated useful lives. Amortization expense for intangible assets was $0.6 million and $0.9 million for the three and six months ended June 30, 2015, respectively. Amortization expense was $0.1 million and 0.3 million for the three and six months ended June 30, 2014, respectively. The increase in intangible assets is primarily due to software acquired in the DCGT Acquisition. The acquired intangible assets have an estimated weighted-average amortization period of approximately 5 years. The components of intangible assets are as follows:

	June 30, 2015				December 31, 2014
	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
(millions)
Software and other	$	30.8	$	22.3	$	6.5	$	2.4
Licenses		11.0		3.2		11.0		3.0
Total	$	41.8	$	25.5	$	17.5	$	5.4

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Note 9. Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2015		December 31, 2014
(millions)
Regulatory assets:
Unrecovered gas costs(1)	$	2.2	$	1.5
Other		0.4		0.2
Regulatory assets-current		2.6		1.7
Income taxes recoverable through future rates(2)		2.6		2.5
Regulatory assets-non-current		2.6		2.5
Total regulatory assets	$	5.2	$	4.2
Regulatory liabilities:
Overrecovered gas costs(1)	$	—	$	0.5
LNG cargo obligations(3)		3.6		3.0
Customer bankruptcy settlement(4)		2.9		—
Other		0.7		0.1
Regulatory liabilities-current		7.2		3.6
Provision for future cost of removal(5)		47.7		33.0
Customer bankruptcy settlement(4)		21.9		—
Other		1.4		0.5
Regulatory liabilities-non-current		71.0		33.5
Total regulatory liabilities	$	78.2	$	37.1

(1) Reflects unrecovered/overrecovered gas costs, which are subject to annual filings with the FERC.

(2) Amounts to be recovered through future rates to pay income taxes that become payable by unitholders when rate revenue is provided to recover AFUDC-equity when such amounts are recovered through book depreciation.

(3) Reflects obligations to the Import Shippers for LNG cargo received. See Note 9 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014 for further information.

(4) Represents the balance of proceeds from the monetization of a bankruptcy claim acquired as part of the DCGT Acquisition, which is being amortized into operating revenue through February 2024.

(5) Rates charged to customers include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.

At June 30, 2015, approximately $2.6 million of regulatory assets represented past expenditures on which Dominion Midstream does not currently earn a return. These expenditures are expected to be recovered within one year.

Note 10. Regulatory Matters

The FERC regulates the transportation and sale for resale of natural gas in interstate commerce under the NGA and the Natural Gas Policy Act of 1978, as amended. Under the NGA, the FERC has authority over rates, terms and conditions of services performed by Cove Point and DCGT. The FERC also has jurisdiction over siting, construction and operation of natural gas import facilities and interstate natural gas pipeline facilities.

There have been no significant developments regarding the regulatory matters disclosed in Note 9 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014.

During the second quarter of 2013, DCGT executed binding precedent agreements for the approximately $35 million Edgemoor Project. The FERC approved the Edgemoor Project in February 2015 and construction commenced in March 2015. The project is expected to be placed into service in the fourth quarter of 2015.

In April 2014, DCGT executed a binding precedent agreement for the approximately $35 million Columbia to Eastover Project. In May 2015, DCGT filed an application to request FERC authorization to construct and operate the project facilities, which are expected to be in service in the second quarter of 2016.

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In connection with Dominion’s acquisition of DCGT on January 31, 2015, Dominion agreed to a rate moratorium which precludes DCGT from filing a Section 4 NGA general rate case to establish base rates that would be effective prior to January 1, 2018.

Note 11. Asset Retirement Obligations

AROs represent obligations that result from laws, statutes, contracts and regulations related to the eventual retirement of certain of Dominion Midstream’s long-lived assets. Dominion Midstream’s AROs primarily represent the cost associated with the legal obligation to cap and purge underground transmission pipe and the interim retirement of natural gas transmission pipeline components.

The changes to AROs during 2014 and 2015 are as follows:

	Six Months Ended June 30, 2015			Year Ended December 31, 2014
(millions)
Beginning balance(1)	$	0.4		$	0.4
DCGT Acquisition		12.6			—
Obligations settled during the period		(0.3	)		—
Accretion		0.3			—
Ending balance(1)	$	13.0		$	0.4

(1) Includes $0.1 million and $0.3 million reported in other current liabilities at December 31, 2014, and June 30, 2015, respectively.

Under the terms of the 2005 Agreement, Cove Point would be responsible for certain onshore and offshore site restoration activities at the Cove Point site only if it voluntarily tenders title according to the terms of this agreement. As Cove Point is permitted to operate the Cove Point LNG Facility for an indefinite time period and currently has no plans to voluntarily tender title, Cove Point does not have sufficient information to determine a reasonable range of settlement dates for decommissioning and therefore has not recorded an asset retirement obligation.

Note 12. Affiliated Long-Term Debt

In connection with the DCGT Acquisition, Dominion Midstream issued a two-year, $300.8 million senior unsecured promissory note payable to Dominion, as adjusted for working capital, at an annual fixed interest rate of 0.6%. Interest on the note is payable quarterly, and all principal and accrued interest is due and payable at maturity on April 1, 2017, which under certain conditions can be extended at the option of Dominion Midstream to October 1, 2017. Interest charges related to Dominion Midstream’s borrowing from Dominion were $0.5 million for the three and six months ended June 30, 2015. At June 30, 2015, accrued interest payable to Dominion of $0.5 million was recorded in payables to affiliates on the Consolidated Balance Sheet.

The debt instrument described above is reported at historical cost. At June 30, 2015, the fair value of Dominion Midstream’s outstanding debt was $289.6 million. The estimated fair value has been determined using available market information and valuation methodologies considered appropriate by management. The fair value was calculated using market interest rates currently available for issuance of debt with similar terms and remaining maturities. The fair value measurement is classified as Level 2.

The key terms of the note payable to Dominion include a prohibition on the incurrence of additional indebtedness (other than under the credit facility with Dominion discussed in Note 15) and a negative pledge applicable to liens on the assets of Dominion Midstream, but which does not apply to the assets of subsidiaries of Dominion Midstream. The note payable does not include any financial covenants. If Dominion Midstream fails to make payments under the note payable or becomes subject to bankruptcy or other insolvency proceedings, Dominion may accelerate Dominion Midstream’s payment obligations under the note payable.

Note 13. Commitments and Contingencies

As a result of issues generated in the ordinary course of business, Dominion Midstream is involved in legal proceedings before various courts and is periodically subject to governmental examinations (including by the FERC), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an

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initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for Dominion Midstream to estimate a range of possible loss. For such matters that Dominion Midstream cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that Dominion Midstream is able to estimate a range of possible loss. For legal proceedings and governmental examinations for which Dominion Midstream is able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Any estimated range of possible loss may not represent Dominion Midstream’s maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. Management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on Dominion Midstream’s financial position, liquidity or results of operations.

Cove Point Natural Heritage Trust

Under the terms of the 2005 Agreement, Cove Point is required to make an annual contribution to the Cove Point Natural Heritage Trust, an affiliated non-profit trust focused on the preservation and protection of ecologically sensitive sites at or near Cove Point, of $0.3 million for each year the facility is in operation. These annual payments are recorded in other operations and maintenance expense in the Consolidated Statements of Income. If Cove Point voluntarily tenders title according to the terms of this agreement, no contributions are required. There are no current plans to voluntarily tender title to the Cove Point site.

Surety Bonds

At June 30, 2015, Cove Point had purchased $10.8 million of surety bonds. Under the terms of surety bonds, Cove Point is obligated to indemnify the respective surety bond company for any amounts paid.

Lease Commitments

Dominion Midstream leases various facilities, vehicles and equipment under operating lease arrangements, the majority of which include terms of one year or less, require payments on a monthly or annual basis, and can be canceled at any time. Rental expense for Dominion Midstream totaled $0.7 million and $1.4 million for the three and six months ended June 30, 2015, respectively. The majority of rent expense is included within other operations and maintenance expense in the Consolidated Statements of Income.

Note 14. Credit Risk

Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition. In addition, counterparties may make available collateral, including letters of credit, payment guarantees, or cash deposits.

Dominion Midstream provides service to approximately seventy customers, including the Storage Customers, marketers or end users and the Import Shippers. The two largest customers comprised approximately 71% of the total transportation and storage revenues for each of the three and six months ended June 30, 2015, with Dominion Midstream’s largest customer representing approximately 56% and 57% of such amounts in each period, respectively.

For each of the three and six months ended June 30, 2014, Cove Point’s three largest customers comprised approximately 87% of the total transportation and storage revenues, with Cove Point’s largest customer representing approximately 68% of such amounts in each period.

Dominion Midstream maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends and other information. At June 30, 2015, the provision for credit losses was less than $0.1 million. Management believes, based on credit policies and the June 30, 2015 provision for credit losses, that it is unlikely that a material adverse effect on financial position, results of operations or cash flows would occur as a result of counterparty nonperformance.

Note 15. Related-Party Transactions

Dominion Midstream engages in related-party transactions primarily with other Dominion subsidiaries (affiliates). Dominion Midstream’s receivable and payable balances with affiliates are settled based on contractual terms or on a monthly basis, depending on the nature of the underlying transactions. Participation in certain Dominion benefit plans is described in Note 10 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31,

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2014. At June 30, 2015 and December 31, 2014, amounts due to Dominion associated with these benefit plans were $4.7 million and $4.4 million, respectively, recorded in pension and other postretirement benefit liabilities in the Consolidated Balance Sheets. Transactions related to the DCGT Acquisition are described in Notes 2 and 12. A discussion of the remaining significant related party transactions follows.

Transactions with Affiliates

In connection with the Offering, our general partner entered into a services agreement with DRS. DRS provides administrative, management and other services to Dominion and its subsidiaries as a subsidiary service company. From time to time and at the option of our general partner, our general partner will request that DRS provide, and reimburse DRS for the cost of providing, such administrative, management and other services as it deems necessary or appropriate for our operations. We will reimburse our general partner and its affiliates for the associated costs of obtaining these services.

In connection with Dominion’s acquisition of DCGT, DCGT entered into services agreements beginning February 1, 2015 with DRS, for similar services as described above, and with Dominion Payroll, which provides human resources and operations services to Dominion and its subsidiaries as a subsidiary service company. Additionally, Dominion may seek reimbursement from DCGT for costs incurred related to Dominion’s transition services agreement with SCANA to provide administrative functions related to DCGT. During the three months ended June 30, 2015, DCGT reimbursed Dominion $1.1 million for such costs.

Dominion Midstream provides transportation services to affiliates and affiliates provide goods and services to Dominion Midstream.

Affiliated transactions are presented below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(millions)
Sales of natural gas transportation services to affiliates	$	0.4	$	0.5	$	1.1	$	1.3
Purchased gas from affiliates		0.1		0.2		0.3		0.4
Services provided by DRS and Dominion Payroll(1)(2)		4.2		2.8		7.8		6.1
Goods and services provided by affiliates to Dominion Midstream(1)		5.3		0.8		8.9		1.5

(1) Includes $3.1 million and $5.5 million of capitalized expenditures for the three and six months ended June 30, 2015, and $1.7 million and $3.7 million for the three and six months ended June 30, 2014.

(2) Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with DRS, an affiliated variable interest entity, and therefore none is the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated subsidiaries has an obligation to absorb more than its allocated share of DRS costs. Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with Dominion Payroll, an affiliated variable interest entity, and therefore none is the primary beneficiary. Dominion Payroll provides human resources and operations services to certain Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated entities has an obligation to absorb more than its allocated share of Dominion Payroll costs.

Advance from Affiliate

An outstanding advance of $20.0 million previously received by Cove Point from an affiliate was converted to an equity contribution in March 2014.

Dominion Credit Facility

In connection with the Offering, Dominion Midstream entered into a credit facility with Dominion with a borrowing capacity of $300 million. A summary of certain key terms of the credit facility with Dominion is included in Note 14 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014. At June 30, 2015, $5.9 million was outstanding against the credit facility. No amounts were outstanding at December 31, 2014. Outstanding borrowings are presented within current liabilities as such amounts could become payable on demand after a 90-day termination notice provided by either party. No such notice has been provided through the date of this filing. Interest charges related to Dominion Midstream’s borrowings against the facility were less than $0.1 million for the three and six months ended June 30, 2015.

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Income Taxes

Prior to the Offering, Cove Point participated in Dominion’s intercompany tax sharing agreement as described in Note 15 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014. Cove Point’s participation in this tax sharing agreement was terminated in 2014 in connection with the Offering.

At the time of the Offering, Cove Point settled net income taxes payable and deferred income taxes to Dominion of $147.9 million through equity contributions from Dominion. Prior to the Offering, Cove Point settled net income taxes payable to Dominion of $1.2 million through equity contributions from Dominion during the year ended December 31, 2014.

DCGT participated in Dominion’s intercompany tax sharing agreement from February 1, 2015 through March 31, 2015. DCGT’s participation in this tax sharing agreement was subsequently terminated in connection with the DCGT Acquisition. At the time of the DCGT Acquisition, DCGT settled income taxes payable and net deferred income taxes of $13.4 million through an equity transaction with Dominion.

Natural Gas Imbalances

Dominion Midstream maintains natural gas imbalances with affiliates. The imbalances with affiliates are provided below:

	June 30, 2015		December 31, 2014
(millions)
Imbalances payable to affiliates	$	3.4	$	2.5

Right of First Offer

In connection with the Offering, Dominion Midstream entered into a right of first offer agreement with Dominion as described in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014. There have been no changes to this agreement.

Contributions from Dominion

During the second quarter of 2015, Dominion contributed $271.8 million to Cove Point to fund capital expenditures related to the Liquefaction Project. In July 2015, Dominion made additional contributions of $110.2 million to Cove Point to fund capital expenditures related to the Liquefaction Project. In February 2015, Dominion contributed $1.3 million in cash to DCGT to fund operations.

Transaction and transition costs incurred by the DCGT Predecessor were attributed to Dominion Midstream and expensed in Operations and maintenance expense in the Consolidated Income Statement. At the time of the DCGT Acquisition, Dominion Midstream settled amounts payable to Dominion of $1.0 million through equity contributions from Dominion.

Subsequent to the DCGT Acquisition, Dominion allocated transaction and transition costs of $1.0 million to Dominion Midstream, of which Dominion did not seek reimbursement for $0.7 million as described further in Note 2.

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Note 16. Income Taxes

Dominion Midstream is organized as an MLP, a pass-through entity for U.S. federal and state income tax purposes. Each unitholder is responsible for taking into account the unitholder’s respective share of Dominion Midstream’s items of taxable income, gain, loss and deduction in the preparation of income tax returns. Upon the closing of the Offering, Cove Point became a pass-through entity for U.S. federal and state income tax purposes. Effective April 1, 2015, the date of the DCGT Acquisition, DCGT is treated as a component of Dominion Midstream for income tax purposes. Accordingly, for the quarter ended June 30, 2015, Dominion Midstream’s Consolidated Financial Statements do not include income taxes.

Prior to the completion of the Offering, Cove Point was not treated as a partnership for U.S. federal and state income tax purposes. Its business activities were included in the consolidated U.S. federal and certain state income tax returns of Dominion or DCPI. DCGT operated as a taxable corporation at the time of Dominion’s acquisition of DCGT. In March 2015, DCGT converted to a single member limited liability company and as a result, became a disregarded entity for income tax purposes and was treated as a taxable division of its corporate parent. Its business activities from January 31, 2015 through March 31, 2015, will be included in the consolidated U.S. federal and certain state income tax returns of Dominion. Cove Point and DCGT’s current income taxes were based on taxable income or loss, determined on a separate company basis, and, where applicable, settled in accordance with the principles of Dominion’s intercompany tax sharing agreement. The settlement of DCGT’s federal and state income taxes payable and net deferred income taxes is reflected as an equity transaction in Dominion Midstream’s Consolidated Financial Statements.

For the six months ended June 30, 2015 and 2014, the statutory U.S. federal income tax rate reconciles to the effective income tax rate as follows:

Six Months Ended June 30,	2015			2014
U.S. statutory rate		35.0	%		35.0	%
Partnership income not subject to income taxes(1)		(32.9	)		—
Increases resulting from:
State taxes, net of federal benefit(2)		0.2			3.2
Effective tax rate		2.3	%		38.2	%

(1) Reflects the pass-through entity status of Dominion Midstream, including the operations of DCGT subsequent to the DCGT Acquisition, and Cove Point.

(2) 2015 amounts are attributable to the operations of DCGT prior to the DCGT Acquisition, and 2014 amounts are attributable to Cove Point.

See Note 15 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014 for additional information.

Note 17. Operating Segment

Dominion Midstream is organized primarily on the basis of products and services sold in the U.S. Dominion Energy, Dominion Midstream’s operating segment, consists of natural gas transportation, storage and regasification services.

Dominion Midstream also reports a Corporate and Other segment. The Corporate and Other segment primarily includes specific items attributable to Dominion Midstream’s operating segment that are not included in profit measures evaluated by executive management in assessing the segment’s performance.

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The following table presents segment information pertaining to Dominion Midstream’s operations:

	Dominion Energy		Corporate and Other			Total
(millions)
Three Months Ended June 30, 2015
Operating revenue	$	105.4	$	—		$	105.4
Net income including noncontrolling interest and DCGT Predecessor		47.9		(0.7	)		47.2
Net income attributable to partners		18.3		(0.7	)		17.6
Three Months Ended June 30, 2014
Operating revenue	$	111.2	$	—		$	111.2
Net income including noncontrolling interest and DCGT Predecessor		24.2		—			24.2
Six Months Ended June 30, 2015
Operating revenue	$	183.8	$	—		$	183.8
Net income including noncontrolling interest and DCGT Predecessor		91.7		(1.7	)		90.0
Net income including noncontrolling interest		88.4		(0.7	)		87.7
Net income attributable to partners		30.1		(0.7	)		29.4
Six Months Ended June 30, 2014
Operating revenue	$	180.1	$	—		$	180.1
Net income including noncontrolling interest and DCGT Predecessor		48.8		—			48.8

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS

OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

MD&A discusses our results of operations and general financial condition. MD&A should be read in conjunction with the Consolidated Financial Statements.

Contents of MD&A

MD&A consists of the following information:

• Forward-Looking Statements

• How We Evaluate Our Operations

• Factors Impacting Comparability of Our Financial Results

• Accounting Matters

• Results of Operations

• Analysis of Consolidated Operations

• Segment Results of Operations

• Liquidity and Capital Resources

• Future Issues and Other Matters

Forward-Looking Statements

This report contains statements concerning expectations, plans, objectives, future financial performance and other statements that are not historical facts. In most cases, the reader can identify these forward-looking statements by such words as “anticipate,” “estimate,” “forecast,” “expect,” “believe,” “should,” “could,” “plan,” “may,” “continue,” “target” or other similar words.

We make forward-looking statements with full knowledge that risks and uncertainties exist that may cause actual results to differ materially from predicted results. Factors that may cause actual results to differ are often presented with the forward-looking statements themselves. Additionally, other factors may cause actual results to differ materially from those indicated in any forward-looking statement. These factors include but are not limited to:

• Unusual weather conditions and their effect on energy sales to customers and energy commodity prices;

• Extreme weather events and other natural disasters, including, but not limited to, hurricanes, high winds, severe storms, earthquakes, flooding and changes in water availability that can cause outages and property damage to facilities;

• Federal, state and local legislative and regulatory developments, including changes in federal and state tax laws and regulations;

• Changes to federal, state and local environmental laws and regulations, including those related to climate change, the tightening of emission or discharge limits for GHGs and other emissions, more extensive permitting requirements and the regulation of additional substances;

• The cost of environmental compliance, including those costs related to climate change;

• Changes in enforcement practices of regulators relating to environmental and safety standards and litigation exposure for remedial activities;

• Changes in regulator implementation of environmental and safety standards and litigation exposure for remedial activities;

• Difficulty in anticipating mitigation requirements associated with environmental and other regulatory approvals;

• Fluctuations in energy-related commodity prices and the effect these could have on our earnings, liquidity position and the underlying value of our assets;

• Counterparty credit and performance risk;

• Employee workforce factors;

• Risks of operating businesses in regulated industries that are subject to changing regulatory structures;

• The ability to negotiate and consummate acquisitions from Dominion and third parties and the impacts of such acquisitions;

• Receipt of approvals for, and timing of, closing dates for acquisitions;

• The timing and execution of our growth strategy;

• Political and economic conditions, including inflation and deflation;

• Domestic terrorism and other threats to our physical and intangible assets, as well as threats to cybersecurity;

• The timing and receipt of regulatory approvals necessary for planned construction or any future expansion projects, including the overall development of the Liquefaction Project, and compliance with conditions associated with such regulatory approvals;

• Changes in demand for our services, including industrial, commercial and residential growth or decline in our service areas, changes in supplies of natural gas delivered to DCGT’s pipeline systems, failure to maintain or replace customer contracts on favorable terms, changes in customer growth or usage patterns, including as a result of energy conservation programs and the availability of energy efficient devices;

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• Additional competition in industries in which we operate;

• Changes to regulated gas transportation rates collected by DCGT;

• Changes in operating, maintenance and construction costs;

• Adverse outcomes in litigation matters or regulatory proceedings;

• The impact of operational hazards, including adverse developments with respect to pipeline and plant safety or integrity, equipment loss, malfunction or failure, operator error, and other catastrophic events;

• The inability to complete planned construction, conversion or expansion projects, including the Liquefaction Project, at all, or with the outcomes or within the terms and time frames initially anticipated;

• Contractual arrangements to be entered into with or performed by our customers substantially in the future, including any revenues anticipated thereunder and any possibility of termination and inability to replace such contractual arrangements;

• Capital market conditions, including the availability of credit and the ability to obtain financing on reasonable terms;

• Fluctuations in interest rates and increases in our level of indebtedness;

• Changes in availability and cost of capital;

• Changes in financial or regulatory accounting principles or policies imposed by governing bodies; and

• Conflicts of interest with Dominion and its affiliates.

Additionally, other risks that could cause actual results to differ from predicted results are referenced in Part II, Item 1A. Risk Factors.

Forward-looking statements are based on beliefs and assumptions using information available at the time the statements are made. We caution the reader not to place undue reliance on forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, differ materially from actual results. We undertake no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.

How We Evaluate Our Operations

Dominion Midstream management uses a variety of financial metrics to analyze our performance. These metrics are significant factors in assessing our operating results and include: (1) EBITDA; (2) Adjusted EBITDA; and (3) distributable cash flow.

EBITDA, Adjusted EBITDA and Distributable Cash Flow

EBITDA represents net income including noncontrolling interest and DCGT Predecessor before interest and related charges, income tax and depreciation and amortization. Adjusted EBITDA represents EBITDA after adjustment for the EBITDA attributable to the DCGT Predecessor and a noncontrolling interest in Cove Point held by Dominion subsequent to the Offering. Subsequent to the DCGT Acquisition in the second quarter of 2015, we define distributable cash flow as Adjusted EBITDA less maintenance capital expenditures, less interest expense and adjusted for known timing differences between cash and income. During the first quarter of 2015, the remaining net proceeds from the Offering were used to fund capital expenditures. As a result, the reconciliation of distributable cash flow no longer includes adjustments for expansion capital expenditures or the use of net proceeds from the Offering. All periods presented reflect the adjustments described above.

Although we have not quantified Adjusted EBITDA and distributable cash flow for Cove Point as our Predecessor, we intend to use these metrics to analyze our performance. EBITDA, Adjusted EBITDA and distributable cash flow are used as supplemental financial measures by our management and by external users of our financial statements, such as investors and securities analysts, to assess:

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

• The ability of our assets to generate cash sufficient to pay interest on our indebtedness, if any, and to make distributions; and

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

The GAAP measure most directly comparable to EBITDA and Adjusted EBITDA is net income, and the GAAP measure most directly comparable to distributable cash flow is net cash provided by operating activities. EBITDA, Adjusted EBITDA and distributable cash flow should not be considered alternatives to net income, operating income, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. EBITDA, Adjusted EBITDA and distributable cash flow exclude some, but not all, items that affect net income and operating income, and these measures may vary among other companies. Therefore, EBITDA, Adjusted EBITDA and distributable cash flow as presented may not be comparable to similarly titled measures of other companies.

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Factors Impacting Comparability of Our Financial Results

As of June 30, 2015, there have been no significant changes with regard to the factors impacting comparability of our financial results as disclosed in MD&A in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014. The factors disclosed included import contracts, the Liquefaction Project, income taxes and general and administrative expenses.

On April 1, 2015, Dominion Midstream entered into a Purchase, Sale and Contribution Agreement with Dominion pursuant to which Dominion Midstream purchased from Dominion all of the issued and outstanding membership interests of DCGT in exchange for total consideration of approximately $500.8 million, as adjusted for working capital, as further described in Note 2. The sale of DCGT from Dominion to Dominion Midstream is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis is equal to Dominion’s cost basis in the assets and liabilities of DCGT. Subsequent to the transaction, Dominion Midstream owns 100% of the membership interests in DCGT and therefore consolidates DCGT.

Accounting Matters

Critical Accounting Policies and Estimates

As of June 30, 2015, there have been no significant changes to the critical accounting policies and estimates disclosed in MD&A in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014. The policies previously disclosed included the accounting for regulated operations, use of estimates in goodwill impairment testing, and use of estimates in long-lived asset impairment testing.

Results of Operations

Presented below are selected amounts related to Dominion Midstream’s results of operations:

	Second Quarter							Year-To-Date
	2015		2014		$ Change			2015		2014		$ Change
(millions)
Operating revenue	$	105.4	$	111.2	$	(5.8	)	$	183.8	$	180.1	$	3.7
Purchased gas		25.5		47.8		(22.3	)		29.4		53.1		(23.7	)
Net revenue		79.9		63.4		16.5			154.4		127.0		27.4
Other operations and maintenance		16.0		10.8		5.2			29.3		21.2		8.1
Depreciation and amortization		9.9		7.9		2.0			20.5		15.7		4.8
Other taxes		6.8		5.5		1.3			12.7		11.1		1.6
Other income		0.2		—		0.2			0.4		—		0.4
Interest and related charges		0.2		—		0.2			0.2		—		0.2
Income tax expense		—		15.0		(15.0	)		2.1		30.2		(28.1	)
Net income including noncontrolling interest and DCGT Predecessor	$	47.2	$	24.2	$	23.0		$	90.0	$	48.8	$	41.2
Less: Net income attributable to DCGT Predecessor		—							2.3
Less: Net income attributable to noncontrolling interest		29.6							58.3
Net income attributable to partners	$	17.6						$	29.4
EBITDA	$	57.3	$	47.1	$	10.2		$	112.8	$	94.7	$	18.1
Adjusted EBITDA	$	19.9						$	31.7
Distributable cash flow	$	19.3						$	31.2

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The following table presents a reconciliation of EBITDA and Adjusted EBITDA to the most directly comparable GAAP financial measure for each year. The Adjusted EBITDA measure is not applicable to the three and six month periods ended June 30, 2014.

	Second Quarter				Year-To-Date
	2015		2014		2015		2014
(millions)
Adjustments to reconcile net income including noncontrolling interest and DCGT Predecessor to EBITDA and Adjusted EBITDA:
Net income including noncontrolling interest and DCGT Predecessor	$	47.2	$	24.2	$	90.0	$	48.8
Add:
Depreciation and amortization		9.9		7.9		20.5		15.7
Interest and related charges		0.2		—		0.2		—
Income tax expense		—		15.0		2.1		30.2
EBITDA	$	57.3	$	47.1	$	112.8	$	94.7
EBITDA attributable to DCGT Predecessor		—				5.7
EBITDA attributable to noncontrolling interest		37.4				75.4
Adjusted EBITDA	$	19.9			$	31.7

The following table presents a reconciliation of distributable cash flow to the most directly comparable GAAP financial measure for the three and six month periods ended June 30, 2015. This measure is not applicable to the three and six month periods ended June 30, 2014.

	Second Quarter 2015			Year-To- Date 2015
(millions)
Adjustments to reconcile net cash provided by operating activities to distributable cash flow:
Net cash provided by operating activities	$	68.0		$	124.7
Less:
Cash attributable to noncontrolling interest(1)		44.5			80.0
Cash attributable to DCGT Predecessor(2)		—			10.4
Other changes in working capital and noncash adjustments		(3.6	)		(2.6	)
Adjusted EBITDA		19.9			31.7
Adjustments to cash:
Plus: Other taxes(3)		1.2			1.2
Plus: Deferred revenue(4)		1.0			1.0
Less: Amortization of regulatory liability(5)		(0.7	)		(0.7	)
Less: Maintenance capital expenditures(6)		(2.4	)		(2.4	)
Plus: Transition costs funded by Dominion		0.7			0.7
Less: Interest expense and AFUDC equity		(0.4	)		(0.4	)
Plus: Non-cash director compensation		—			0.1
Distributable cash flow	$	19.3		$	31.2

(1) The Preferred Equity Interest is a perpetual, non-convertible preferred equity interest entitled to the Preferred Return Distributions. Any excess in cash available over the $50.0 million is attributable to the noncontrolling interest held by Dominion but not available for distribution until the distribution reserve has been fully funded.

(2) Represents net cash provided by operating activities of DCGT from January 31, 2015, the inception date of common control, through March 31, 2015, the date just prior to Dominion Midstream acquiring DCGT.

(3) Adjustment to reflect the timing difference between cash paid for property taxes and the amount recognized into expense.

(4) Adjustment to reflect the difference between cash received and revenue recognized related to facilities payments that are deferred and will be recognized over the related customer contract periods.

(5) Represents the monetization of a bankruptcy claim being amortized into income through February 2024.

(6) For the three and six months ended June 30, 2015, amount excludes $3.5 million and $7.3 million, respectively, of Dominion funded maintenance capital expenditures related to the Cove Point LNG Facility and Cove Point Pipeline. Dominion has indicated that it intends to continue providing the funding necessary for such expenditures, but it is under no obligation to do so. In addition, the six month period ended June 30, 2015 excludes $1.3 million of maintenance capital expenditures incurred by the DCGT Predecessor.

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Analysis of Consolidated Operations

Overview

Net revenue reflects operating revenue less purchased gas expense. Purchased gas expense includes the value of natural gas retained for use in routine operations and the cost of LNG cooling cargo purchases. Increases or decreases in purchased gas expenses are offset by corresponding increases or decreases in operating revenues and are thus financially neutral to Dominion Midstream. LNG cooling cargo purchases are required for Cove Point to maintain the cryogenic readiness of the Cove Point LNG Facility. Each year, one or two LNG cooling cargos are procured and billed to the Import Shippers pursuant to certain provisions in Cove Point’s FERC gas tariff.

An analysis of Dominion Midstream’s results of operations follows:

Second Quarter 2015 vs. 2014

Net revenue increased 26% primarily related to increased transportation and storage revenue as a result of the DCGT Acquisition. Operating revenue and purchased gas decreased approximately $20.6 million due to pricing declines related to the LNG cooling cargo. Cove Point received one LNG cooling cargo in each period.

Other operations and maintenance increased 48%, primarily due to the DCGT Acquisition ($6.5 million), increased corporate general and administrative costs associated with operating as a stand-alone publicly traded partnership ($0.6 million) and transition service costs associated with the DCGT Acquisition ($1.0 million). These increases were partially offset by a decrease of $4.1 million in stakeholder outreach expenditures associated with the Liquefaction Project.

Depreciation and amortization increased 25% primarily due to the DCGT Acquisition.

Other taxes increased 24% primarily due to the DCGT Acquisition.

Income tax expense decreased $15.0 million as a result of Dominion Midstream’s treatment as a pass-through entity for federal and state income tax purposes effective October 20, 2014.

Year-To-Date 2015 vs. 2014

Net revenue increased 22%, primarily related to increased transportation and storage revenue as a result of the DCGT Acquisition. Operating revenue and purchased gas decreased approximately $20.6 million due to pricing declines related to the LNG cooling cargo. Cove Point received one LNG cooling cargo in each period.

Other operations and maintenance increased 38%, primarily due to the DCGT Acquisition ($10.3 million), corporate general and administrative costs associated with operating as a stand-alone publicly traded partnership ($1.3 million) and transition service costs associated with the DCGT Acquisition ($2.0 million). This increase was partially offset by a decrease of $7.5 million in stakeholder outreach expenditures associated with the Liquefaction Project.

Depreciation and amortization increased 31% primarily due to the DCGT Acquisition ($3.4 million) and accelerated depreciation from 2015 asset retirements associated with the Liquefaction Project ($1.5 million).

Other taxes increased 14% primarily due to the DCGT Acquisition.

Income tax expense decreased $30.2 million as a result of Dominion Midstream’s treatment as a pass-through entity for federal and state income tax purposes effective October 20, 2014, partially offset by $2.1 million of income taxes attributable to the DCGT Predecessor.

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Segment Results of Operations

Presented below is a summary of contributions by Dominion Midstream’s operating segment to net income including noncontrolling interest and DCGT Predecessor:

	Second Quarter								Year-To-Date
	2015			2014		$ Change			2015			2014		$ Change
(millions)
Dominion Energy	$	47.9		$	24.2	$	23.7		$	91.7		$	48.8	$	42.9
Corporate and Other		(0.7	)		—		(0.7	)		(1.7	)		—		(1.7	)
Consolidated	$	47.2		$	24.2	$	23.0		$	90.0		$	48.8	$	41.2

Dominion Energy

The following table summarizes, on an after-tax basis, the key factors impacting Dominion Energy’s contribution to net income including noncontrolling interest and DCGT Predecessor. Subsequent to October 20, 2014, Dominion Midstream, as a pass-through entity, is generally not subject to income taxes.

	Second Quarter 2015 vs. 2014 Increase/(Decrease)			Year-To-Date 2015 vs. 2014 Increase/(Decrease)
(millions)
Stakeholder outreach expenses for the Liquefaction Project	$	2.6		$	4.7
Absence of income taxes subsequent to the Offering		15.0			30.2
DCGT Acquisition		7.2			10.5
Accelerated depreciation		—			(0.9	)
Other		(1.1	)		(1.6	)
Change in net income contribution	$	23.7		$	42.9

Corporate and Other

Corporate and Other includes items attributable to Dominion Midstream’s operating segment that are not included in profit measures evaluated by executive management in assessing segment performance or in allocating resources among the segments. Corporate and Other expenses increased $0.7 million and $1.7 million during the three and six months ended June 30, 2015, respectively, due to transition service costs associated with the DCGT Acquisition. There were no such costs in the three and six months ended June 30, 2014.

Liquidity and Capital Resources

Overview

Dominion Midstream’s ongoing principal sources of liquidity may include distributions received from Cove Point from our Preferred Equity Interest, cash generated from operations of DCGT, borrowings under our credit facility with Dominion, and issuances of debt and equity securities. We believe that cash from these sources will be sufficient to pay distributions while continuing to meet our short-term working capital requirements and our long-term capital expenditure requirements. We expect to have sufficient distributable cash flow to pay the minimum quarterly distribution of $0.1750 per common unit and subordinated unit, which equates to $12.1 million per quarter, or $48.3 million per year in the aggregate, based on the number of common units and subordinated units outstanding at June 30, 2015. However, we do not have a legal or contractual obligation to pay distributions quarterly or on any other basis or at the minimum quarterly distribution rate or at any other rate, and there is no guarantee that we will pay distributions to our unitholders in any quarter.

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Outstanding Indebtedness

In connection with the Offering, Dominion Midstream entered into a $300 million credit facility with Dominion, allowing it to competitively pursue acquisitions and future organic growth opportunities or to otherwise meet its financial needs. In June 2015, we borrowed $5.9 million against the credit facility to fund expansion capital expenditures.

On April 1, 2015, in connection with the DCGT Acquisition, Dominion Midstream issued a two-year, $300.8 million senior unsecured promissory note payable to Dominion, as adjusted for working capital, at an annual interest rate of 0.6%. Interest on the note is payable quarterly, and all principal and accrued interest is due and payable at maturity on April 1, 2017, which under certain conditions can be extended at the option of Dominion Midstream to October 1, 2017.

See Notes 12 and 15 to the Consolidated Financial Statements.

Capital Requirements

Capital Spending

Our operations can be capital intensive, requiring investments to expand, upgrade, maintain or enhance existing operations and to meet environmental and operational regulations. As defined in our partnership agreement, our capital requirements consist of:

• Maintenance capital expenditures used to maintain the long-term operating capacity and operating income of our pipelines and facilities. Examples include expenditures to refurbish and replace pipelines, terminals and storage facilities, to maintain equipment reliability, integrity and safety and to address environmental laws and regulations; and

• Expansion capital expenditures used to increase our operating capacity or operating income over the long term. Examples include the acquisition of equipment, the development of a new facility or the expansion of an existing facility.

For the six months ended June 30, 2015, Dominion Midstream paid total capital expenditures of $479.0 million, which included $11.0 million of maintenance capital expenditures.

Our significant capital projects, all of which are expansion projects, are described further below:

• Total costs of developing the Liquefaction Project are estimated to be $3.4 billion to $3.8 billion, excluding financing costs. Through June 30, 2015, Cove Point incurred $1.5 billion of development and construction costs associated with the Liquefaction Project. We caused Cove Point to use the net proceeds contributed to it from the Offering to fund a portion of development and construction costs associated with the Liquefaction Project.

• Total costs of the St. Charles Transportation Project and Keys Energy Project are estimated to be approximately $30 million and $40 million, respectively. Through June 30, 2015, we incurred $3 million of costs associated with these projects. Service under each 20-year contract is expected to commence in June 2016 for the St. Charles Transportation Project and March 2017 for the Keys Energy Project.

• Total costs of the Edgemoor Project are estimated to be approximately $35 million. Through June 30, 2015, approximately $22 million of costs had been incurred, of which Dominion Midstream funded $4 million subsequent to the DCGT Acquisition. FERC approved the Edgemoor project in February 2015 and construction commenced in March 2015. The project is expected to be placed into service in the last quarter of 2015.

• Total costs of the Columbia to Eastover Project are estimated to be approximately $35 million. Through June 30, 2015, approximately $5 million of costs had been incurred, of which Dominion Midstream funded $1 million subsequent to the DCGT Acquisition. In May 2015, DCGT filed an application to request FERC authorization to construct and operate the project facilities, which are expected to be placed into service in the second quarter of 2016.

• In 2014, DCGT executed binding precedent agreements with three customers for the Transco to Charleston project. The project is expected to cost approximately $120 million, and provide 80,000 Dths per day of firm transportation service from an existing interconnect with Transco in Spartanburg County, South Carolina to customers in Dillon, Marlboro, Sumter, Charleston, Lexington and Richland Counties, South Carolina. In July 2015, DCGT requested authorization to utilize the FERC pre-filing process. DCGT expects to file the application to request FERC authorization to construct and operate the project facilities in the first quarter of 2016. The project is expected to be placed into service in the fourth quarter of 2017.

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Dominion has indicated that it intends to provide the funding necessary for the remaining construction costs and other capital expenditures of Cove Point, including the Liquefaction Project, St. Charles Transportation Project and Keys Energy Project, but it is under no contractual obligation to do so and has not secured all of the funding necessary to cover these costs, as it intends to finance these costs as they are incurred using its consolidated operating cash flows in addition to proceeds from capital markets transactions. However, Dominion has entered into guarantee arrangements on behalf of Cove Point to facilitate the Liquefaction Project, including guarantees supporting the terminal services and transportation agreements as well as the engineering, procurement and construction contract for the Liquefaction Project. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million. In the event that Dominion does not satisfy its obligations under these guarantee arrangements or otherwise does not agree to provide the funding necessary for the remaining development costs and other capital expenditures of Cove Point, or is unable to obtain such funding in the amounts required or on terms acceptable to Dominion, Cove Point would require substantial external debt or equity financing to complete the construction of the Liquefaction Project, St. Charles Transportation Project and Keys Energy Project.

Distributions

Distributions are declared subsequent to quarter end. The table below summarizes the quarterly cash distributions declared during 2015.

Quarterly Period Ended	Total Quarterly Distribution (per unit)			Total Cash Distribution (in millions)		Date of Declaration		Date of Record		Date of Distribution
December 31, 2014		0.1389	(1)	$	8.9		January 23, 2015		February 3, 2015		February 13, 2015
March 31, 2015		0.1750		$	12.1		April 22, 2015		May 5, 2015		May 15, 2015
June 30, 2015		0.1875		$	12.9		July 17, 2015		August 4, 2015		August 14, 2015

⁽¹⁾  For the period subsequent to the Offering through December 31, 2014, the initial quarterly cash distribution was calculated as the minimum quarterly distribution of $0.1750 per unit prorated for the portion of the quarter subsequent to the Offering.

Cash Flows

A summary of cash flows for the periods indicated is presented below:

	Six Months Ended June 30,
	2015			2014
(millions)
Cash and cash equivalents at beginning of period	$	175.4		$	11.2
Cash flows provided by (used in):
Operating activities		124.7			66.2
Investing activities		(480.6	)		(222.6	)
Financing activities		257.8			145.2
Net decrease in cash and cash equivalents		(98.1	)		(11.2	)
Cash and cash equivalents at end of period	$	77.3		$	—

Operating Cash Flows

In the first six months of 2015, net cash provided by Dominion Midstream’s operating activities increased by $58.5 million, primarily due to the absence of federal and state income taxes as a result of our treatment as a pass-through entity for federal and state tax purposes effective October 20, 2014, the closing date of the Offering, net changes in working capital items, and the DCGT Acquisition.

Investing Cash Flows

In the first six months of 2015, net cash used in Dominion Midstream’s investing activities increased by $258.0 million, primarily due to higher expenditures for the Liquefaction Project.

Financing Cash Flows

In the first six months of 2015, net cash provided by Dominion Midstream’s financing activities increased $112.6 million, primarily due to higher capital contributions from Dominion to fund the Liquefaction Project, partially offset by the payment of quarterly distributions to unitholders.

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Customer Concentration

Dominion Midstream provides service to approximately seventy customers, including the Storage Customers, marketers or end users and the Import Shippers. The two largest customers comprised approximately 71% of the total transportation and storage revenues for each of the three and six months ended June 30, 2015. See Note 14 to the Consolidated Financial Statements for additional information.

Contractual Obligations

As of June 30, 2015, there have been no material changes outside the ordinary course of business to Dominion Midstream’s contractual obligations as disclosed in MD&A in the Dominion Midstream Annual Report on Form 10-K for the year ended December 31, 2014.

Presented below is a table summarizing cash payments that may result from outstanding debt agreements to which Dominion Midstream is a party as of June 30, 2015.

	Remainder of 2015		2016- 2017		2018- 2019		2020 and thereafter		Total
(millions)
Affiliated long-term debt	$	—	$	300.8	$	—	$	—	$	300.8
Interest payments		0.9		2.7		—		—		3.6

Off-Balance Sheet Arrangements

Other than the holding of surety bonds as discussed in Note 13 to the Consolidated Financial Statements, Dominion Midstream had no off-balance sheet arrangements at June 30, 2015.

Future Issues and Other Matters

The following discussion of future issues and other information includes current developments of previously disclosed matters and new issues arising during the period covered by, and subsequent to, the dates of the Consolidated Financial Statements that may impact Dominion Midstream’s future results of operations, financial condition and/or cash flows. This section should be read in conjunction with Item 1. Business and Future Issues and Other Matters in MD&A in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014 and Future Issues and Other Matters in MD&A in Dominion Midstream’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2015.

Environmental Matters

Dominion Midstream is subject to costs resulting from a number of federal, state and local laws and regulations designed to protect human health and the environment. These laws and regulations affect future planning and existing operations. They can result in increased capital, operating and other costs as a result of compliance, remediation, containment and monitoring obligations. See Note 13 to the Consolidated Financial Statements in this report for additional information on various environmental matters.

Air

The CAA is a comprehensive program utilizing a broad range of regulatory tools to protect and preserve the nation’s air quality. At a minimum, delegated states are required to establish regulatory programs to address all requirements of the CAA. However, states may choose to develop regulatory programs that are more restrictive. Dominion Midstream’s facilities are subject to the CAA’s permitting and other requirements.

In January 2015, as part of its Climate Action Plan, the EPA announced plans to reduce methane emissions from the oil and gas sector including natural gas processing and transmission sources. The plan, which is expected to be proposed in the summer 2015 and finalized in 2016, would impose regulations to reduce methane emissions from new and modified sources, including sources at compressor stations. The EPA is also expected to develop control technology guidelines to reduce emissions of volatile organic compounds from existing sources in ozone nonattainment areas and the Northeast Ozone Transport Region (which includes states within which Dominion Midstream operates facilities). The proposed regulation is expected to rely on current industry voluntary reduction measures implemented through programs such as the EPA’s Natural Gas Star program and pipeline safety and natural gas infrastructure improvement programs. Until these regulations and guidelines are finalized, we are unable to predict future requirements or estimate compliance costs with certainty.

Legal Matters

See Item 3. Legal Proceedings in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014, and Notes 10 and 13 to the Consolidated Financial Statements and Part II, Item 1. Legal Proceedings in this report for additional information on various legal matters.

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Regulatory Matters

See Note 9 to the Consolidated Financial Statements in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014 and Note 10 to the Consolidated Financial Statements in this report for additional information on various regulatory matters.

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ITEM 3.

QUANTITATIVE AND QUALITATIVE

DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

Upon the closing of the Offering, we entered into a $300 million variable rate revolving credit facility with Dominion. We may hedge the interest on portions of our borrowings under the credit facility from time-to-time in order to manage risks associated with floating interest rates. As of June 30, 2015, we have $5.9 million outstanding indebtedness against the credit facility. A hypothetical 10% increase in market interest rates would not have resulted in a material change in earnings at June  30, 2015.

ITEM 4. CONTROLS AND PROCEDURES

Senior management of Dominion Midstream’s general partner, including the general partner’s CEO and CFO, evaluated the effectiveness of Dominion Midstream’s disclosure controls and procedures as of June 30, 2015, the end of the period covered by this report. Based on this evaluation process, the CEO and CFO of Dominion Midstream’s general partner have concluded that Dominion Midstream’s disclosure controls and procedures are effective.

During the quarter ended June 30, 2015, there were no changes in Dominion Midstream’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, Dominion Midstream’s internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time Dominion Midstream, Cove Point and DCGT may be alleged to be in violation or in default under orders, statutes, rules or regulations relating to the environment, compliance plans imposed or agreed to by Dominion Midstream, Cove Point or DCGT, as applicable, or permits issued by various local, state or federal agencies for the construction or operation of facilities. Administrative proceedings may also be pending on these matters. In addition, in the ordinary course of business Dominion Midstream, Cove Point and DCGT may be involved in various legal proceedings.

See Notes 9 and 12 to the Consolidated Financial Statements and Future Issues and Other Matters in MD&A in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014, which information is incorporated herein by reference, for discussion of various environmental and other regulatory proceedings to which Dominion Midstream is a party.

ITEM 1A. RISK FACTORS

Dominion Midstream’s business is influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond its control. These risk factors have been identified in Dominion Midstream’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2015, which should be taken into consideration when reviewing the information contained in this report. There have been no material changes with regard to the risk factors previously disclosed in Dominion Midstream’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2015. For other factors that may cause actual results to differ materially from those indicated in any forward-looking statement or projection contained in this report, see Forward-Looking Statements in MD&A.

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ITEM 6. EXHIBITS

Exhibit Number	Description
2.1	Purchase, Sale and Contribution Agreement by and among Dominion Resources, Inc., Dominion MLP Holding Company II, Inc. and Dominion Midstream Partners, LP dated April 1, 2015 (Exhibit 2.1, Form 8-K filed April 1, 2015, File No. 1-36684).
3.1	Certificate of Limited Partnership of Dominion Midstream Partners, LP (Exhibit 3.1, Form S-1 Registration Statement filed March 28, 2014, File No. 333-194864).
3.2	First Amended and Restated Agreement of Limited Partnership of Dominion Midstream Partners, LP, dated October 20, 2014, by and between Dominion Midstream GP, LLC and Dominion MLP Holding Company, LLC (Exhibit 3.1, Form 8-K filed October 20, 2014, File No. 1-36684).
4.1	Registration Rights Agreement by and between Dominion Midstream Partners, LP and Dominion MLP Holding Company II, Inc. (filed herewith).
10.1	Form of Promissory Note in the initial principal amount of $295,331,972 dated April 1, 2015 (Exhibit 10.1, Form 8-K filed April 1, 2015, File No. 1-36684).
10.2	Fourth Amended and Restated Agreement of Limited Partnership of Dominion Cove Point LNG, LP among Cove Point GP Holding Company, LLC, Dominion Gas Projects Company, LLC and Dominion Cove Point, Inc. (Exhibit 10.2, Form 10-Q for the quarter ended March 31, 2015 filed May 5, 2015, File No. 1-36684).
31.a	Certification by Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
31.b	Certification by Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
32	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).
101	The following financial statements from Dominion Midstream’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, filed on August 6, 2015, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Equity and Partners’ Capital, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.

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SIGNATURE

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

	DOMINION MIDSTREAM PARTNERS, LP Registrant
	By: Dominion Midstream GP, LLC, its general partner
August 6, 2015	/s/    Michele L. Cardiff
	Michele L. Cardiff
	Vice President, Controller and Chief Accounting Officer

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EXHIBIT INDEX

Exhibit Number	Description
2.1	Purchase, Sale and Contribution Agreement by and among Dominion Resources, Inc., Dominion MLP Holding Company II, Inc. and Dominion Midstream Partners, LP dated April 1, 2015 (Exhibit 2.1, Form 8-K filed April 1, 2015, File No. 1-36684).
3.1	Certificate of Limited Partnership of Dominion Midstream Partners, LP (Exhibit 3.1, Form S-1 Registration Statement filed March 28, 2014, File No. 333-194864).
3.2	First Amended and Restated Agreement of Limited Partnership of Dominion Midstream Partners, LP, dated October 20, 2014, by and between Dominion Midstream GP, LLC and Dominion MLP Holding Company, LLC (Exhibit 3.1, Form 8-K filed October 20, 2014, File No. 1-36684).
4.1	Registration Rights Agreement by and between Dominion Midstream Partners, LP and Dominion MLP Holding Company II, Inc. (filed herewith).
10.1	Form of Promissory Note in the initial principal amount of $295,331,972 dated April 1, 2015 (Exhibit 10.1, Form 8-K filed April 1, 2015, File No. 1-36684).
10.2	Fourth Amended and Restated Agreement of Limited Partnership of Dominion Cove Point LNG, LP among Cove Point GP Holding Company, LLC, Dominion Gas Projects Company, LLC and Dominion Cove Point, Inc. (Exhibit 10.2, Form 10-Q for the quarter ended March 31, 2015 filed May 5, 2015, File No. 1-36684).
31.a	Certification by Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
31.b	Certification by Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
32	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).
101	The following financial statements from Dominion Midstream’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, filed on August 6, 2015, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Equity and Partners’ Capital, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.

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EX-4.1

Exhibit 4.1

REGISTRATION RIGHTS AGREEMENT

THIS REGISTRATION RIGHTS AGREEMENT (this “Agreement”) is made and entered into as of April 1, 2015, by and between Dominion Midstream Partners, LP, a Delaware limited partnership (the “Partnership”), and Dominion MLP Holding Company II, Inc., a Virginia corporation (“MLP Holdco”).

WHEREAS, this Agreement is made in connection with the transactions contemplated by the Purchase, Sale and Contribution Agreement, dated as of the date hereof, by and among Dominion Resources, Inc., the Partnership and MLP Holdco (the “Purchase Agreement”); and

WHEREAS, the Partnership has agreed to provide the registration and other rights set forth in this Agreement for the benefit of MLP Holdco pursuant to the Purchase Agreement;

NOW THEREFORE, in consideration of the mutual covenants and agreements set forth herein and for good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged by each party hereto, the parties hereby agree as follows:

ARTICLE I

DEFINITIONS

Section 1.01. Definitions. Capitalized terms used herein without definition shall have the meanings given to them in the First Amended and Restated Agreement of Limited Partnership of the Partnership dated October 20, 2014, as amended from time to time (the “Partnership Agreement”). The terms set forth below are used herein as so defined:

“Affiliate” means, with respect to a specified Person, any other Person that directly or indirectly controls, is controlled by, or is under direct or indirect common control with such specified Person. For the purposes of this definition, “control” means the power to direct or cause the direction of the management and policies of a Person, directly or indirectly, whether through the ownership of voting securities, by contract or otherwise.

“Agreement” has the meaning given to such term in the introductory paragraph.

“Commission” has the meaning given to such term in Section 1.02.

“Effectiveness Period” has the meaning given to such term in Section 2.01.

“Exchange Act” has the meaning given to such term in Section 2.07(a).

“Holder” means the record holder of any Registrable Securities.

“Losses” has the meaning given to such term in Section 2.07(a).

“Managing Underwriter(s)” means, with respect to any Underwritten Offering, the book-running lead manager(s) of such Underwritten Offering.

“MLP Holdco” has the meaning given to such term in the introductory paragraph.

“Notice” has the meaning given to such term in Section 2.01.

“Partnership” has the meaning given to such term in the introductory paragraph.

“Person” means any individual, corporation, partnership, limited liability company, voluntary association, joint venture, trust, limited liability partnership, unincorporated organization, government or any agency, instrumentality or political subdivision thereof, or any other form of entity.

“Purchase Agreement” has the meaning given to such term in the recitals of this Agreement.

“Registrable Securities” means the Common Units issued (or issuable) to MLP Holdco pursuant to the Purchase Agreement, which Registrable Securities are subject to the rights provided herein until such rights terminate pursuant to the provisions hereof.

“Registration Expenses” means all expenses (other than Selling Expenses) incident to the Partnership’s performance under or compliance with this Agreement to effect the registration of Registrable Securities on a Registration Statement pursuant to Section 2.01 and/or in connection with an Underwritten Offering pursuant to Section 2.02(a), and the disposition of such Registrable Securities, including, without limitation, all registration, filing, securities exchange listing and securities exchange fees, all registration, filing, qualification and other fees and expenses of complying with securities or blue sky laws, fees of the Financial Industry Regulatory Authority, fees of transfer agents and registrars, all word processing, duplicating and printing expenses, any transfer taxes and the fees and disbursements of counsel and independent public accountants for the Partnership, including the expenses of any special audits or “cold comfort” letters required by or incident to such performance and compliance.

“Registration Statement” has the meaning given to such term in Section 2.01.

“Securities Act” has the meaning given to such term in Section 1.02.

“Selling Expenses” means all underwriting fees, discounts and selling commissions applicable to the sale of Registrable Securities.

“Selling Holder” means a Holder who is selling Registrable Securities pursuant to a Registration Statement.

“Shelf Registration Statement” has the meaning given to such term in Section 2.01.

“Testing-the-Waters Communication” means any oral or written communication with potential investors undertaken in reliance on Section 5(d) of the Securities Act.

“Underwritten Offering” means an offering (including an offering pursuant to a Registration Statement) in which Registrable Securities are sold to an underwriter on a firm commitment basis for reoffering to the public or an offering that is a “bought deal” with one or more investment banks.

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“Written Testing-the-Waters Communication” means any Testing-the-Waters Communication that is a written communication within the meaning of Rule 405 under the Securities Act.

Section 1.02. Registrable Securities. Any Registrable Security will cease to be a Registrable Security (a) at the time a Registration Statement covering such Registrable Security has been declared effective by the Securities and Exchange Commission (the “Commission”), or otherwise has become effective, and such Registrable Security has been sold or disposed of pursuant to such Registration Statement; (b) at the time such Registrable Security has been disposed of pursuant to Rule 144 (or any similar provision then in effect under the Securities Act of 1933, as amended, and the rules and regulations promulgated thereunder (the “Securities Act”)); (c) 10 years after MLP Holdco ceases to be an Affiliate of the General Partner (including where the General Partner ceases to be the general partner of the Partnership); (d) if such Registrable Security is held by the Partnership or one of its subsidiaries; (e) at the time such Registrable Security has been sold in a private transaction in which the transferor’s rights under this Agreement are not assigned to the transferee of such securities; or (f) if such Registrable Security has been sold in a private transaction in which the transferor’s rights under this Agreement are assigned to the transferee and such transferee is not an Affiliate of the General Partner, at the time that is two years following the transfer of such Registrable Security to such transferee.

ARTICLE II

REGISTRATION RIGHTS

Section 2.01. Demand Registration. Upon the written request (a “Notice”) by MLP Holdco or by any other Holder[s] owning at least ten percent (10%) of the then-outstanding Registrable Securities (subject to adjustment pursuant to Section 3.04), the Partnership shall file with the Commission, as soon as reasonably practicable, but in no event more than 90 days following the receipt of the Notice, a registration statement (each, a “Registration Statement”) under the Securities Act providing for the resale of the Registrable Securities (which may, at the option of the Holders giving such Notice, be a registration statement under the Securities Act that provides for the resale of the Registrable Securities pursuant to Rule 415 from time to time by the Holders (a “Shelf Registration Statement”)). The Partnership shall use its commercially reasonable efforts to cause each Registration Statement to be declared effective by the Commission as soon as reasonably practicable after the initial filing of the Registration Statement. Any Registration Statement shall provide for the resale pursuant to any method or combination of methods legally available to, and requested by, the Holders of any and all Registrable Securities covered by such Registration Statement. The Partnership shall use its commercially reasonable efforts to cause each Registration Statement filed pursuant to this Section 2.01 to be continuously effective, supplemented and amended to the extent necessary to ensure that it is available for the resale of all Registrable Securities by the Holders until all Registrable Securities covered by such Registration Statement have ceased to be Registrable Securities (the “Effectiveness Period”). Each Registration Statement when effective (and the documents incorporated therein by reference) shall comply as to form in all material respects

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with all applicable requirements of the Securities Act and shall not contain an untrue statement of a material fact or omit to state a material fact required to be stated therein or necessary to make the statements therein not misleading. There shall be no limit on the number of Registration Statements that may be required by the Holders hereunder.

Section 2.02. Underwritten Offerings.

(a) Request for Underwritten Offering. In the event that one or more Holders collectively elect to dispose of at least fifteen percent (15%) of the then-outstanding Registrable Securities (subject to adjustment pursuant to Section 3.04) under a Registration Statement pursuant to an Underwritten Offering, the Partnership shall, upon written request by such Holders, retain underwriters in order to permit such Holders to effect such sale through an Underwritten Offering. The obligation of the Partnership to retain underwriters shall include entering into an underwriting agreement in customary form with the Managing Underwriter(s), which shall include customary indemnities in favor of, and taking all reasonable actions as are requested by, the Managing Underwriter(s) to expedite or facilitate the disposition of such Registrable Securities. The Partnership shall, upon request of the Holders, cause its management to participate in a roadshow or similar marketing effort on behalf of the Holders.

(b) Limitation on Underwritten Offerings. In no event shall the Partnership be required under Section 2.02(a) to participate in more than two Underwritten Offerings in any twelve-month period.

(c) General Procedures. In connection with any Underwritten Offering under this Agreement, the Holders of a majority of the Registrable Securities being sold in such Underwritten Offering shall be entitled, subject to the Partnership’s consent (which is not to be unreasonably withheld), to select the Managing Underwriter(s). In connection with any Underwritten Offering under this Agreement, each Selling Holder and the Partnership shall be obligated to enter into an underwriting agreement that contains such representations and warranties, covenants, indemnities and other rights and obligations as are customary in underwriting agreements for firm commitment offerings of securities. No Selling Holder may participate in such Underwritten Offering unless such Selling Holder agrees to sell its Registrable Securities on the basis provided in such underwriting agreement and completes and executes all questionnaires, powers of attorney, indemnities and other documents reasonably required under the terms of such underwriting agreement. Each Selling Holder may, at its option, require that any or all of the representations and warranties by, and the other agreements on the part of, the Partnership to and for the benefit of such underwriters also be made to and for such Selling Holder’s benefit and that any or all of the conditions precedent to the obligations of such underwriters under such underwriting agreement also be conditions precedent to such Selling Holder’s obligations. If any Selling Holder disapproves of the terms of an underwriting, such Selling Holder may elect to withdraw from the Underwritten Offering by notice to the Partnership and the Managing Underwriter(s); provided, however, that such withdrawal must be made at a time prior to the time of pricing of such Underwritten Offering. No such withdrawal shall affect the Partnership’s obligation to pay Registration Expenses.

Section 2.03. Delay Rights. If the General Partner determines that the Partnership’s compliance with its obligations under this Article II would be materially detrimental to the

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Partnership and its Partners because such registration would (a) materially interfere with a significant acquisition, reorganization, financing or other similar transaction involving the Partnership, (b) require premature disclosure of material information that the Partnership has a bona fide business purpose for preserving as confidential or (c) render the Partnership unable to comply with applicable securities laws, then the Partnership shall have the right to postpone compliance with its obligations under this Article II for a period of not more than three months, provided, that such right pursuant to this Section 2.03 may not be utilized more than twice in any twelve-month period.

Section 2.04. Sale Procedures. In connection with its obligations under this Article II, the Partnership will, as expeditiously as possible:

(a) prepare and file with the Commission such amendments and supplements to each Registration Statement and the prospectus used in connection therewith as may be necessary to keep each Registration Statement effective for the Effectiveness Period and as may be necessary to comply with the provisions of the Securities Act with respect to the disposition of all Registrable Securities covered by such Registration Statement;

(b) if a prospectus supplement will be used in connection with the marketing of an Underwritten Offering and the Managing Underwriter(s) notifies the Partnership in writing that, in the sole judgment of such Managing Underwriter(s), inclusion of detailed information in such prospectus supplement is of material importance to the success of the Underwritten Offering of such Registrable Securities, use its commercially reasonable efforts to include such information in such prospectus supplement;

(c) furnish to each Selling Holder (i) as far in advance as reasonably practicable before filing a Registration Statement or any supplement or amendment thereto, upon request, copies of reasonably complete drafts of all such documents proposed to be filed (including exhibits and each document incorporated by reference therein to the extent then required by the rules and regulations of the Commission), and provide each such Selling Holder the opportunity to object to any information pertaining to such Selling Holder and its plan of distribution that is contained therein and make the corrections reasonably requested by such Selling Holder with respect to such information prior to filing a Registration Statement or supplement or amendment thereto, and (ii) such number of copies of such Registration Statement and the prospectus included therein and any supplements and amendments thereto as such Persons may reasonably request in order to facilitate the public sale or other disposition of the Registrable Securities covered by such Registration Statement;

(d) if applicable, use its commercially reasonable efforts to register or qualify the Registrable Securities covered by a Registration Statement under the securities or blue sky laws of such jurisdictions as the Selling Holders or, in the case of an Underwritten Offering, the Managing Underwriter(s), shall reasonably request; provided, however, that the Partnership will not be required to qualify generally to transact business in any jurisdiction where it is not then required to so qualify or to take any action that would subject it to general service of process in any jurisdiction where it is not then so subject;

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(e) promptly notify each Selling Holder and each underwriter, at any time when a prospectus is required to be delivered under the Securities Act, of (i) the filing of a Registration Statement or any prospectus or prospectus supplement to be used in connection therewith, or any amendment or supplement thereto, and, with respect to such Registration Statement or any post-effective amendment thereto, when the same has become effective; and (ii) any written comments from the Commission with respect to any filing referred to in clause (i) and any written request by the Commission for amendments or supplements to a Registration Statement or any prospectus or prospectus supplement thereto;

(f) immediately notify each Selling Holder and each underwriter, at any time when a prospectus is required to be delivered under the Securities Act, of (i) the happening of any event as a result of which the prospectus or prospectus supplement contained in a Registration Statement, as then in effect, includes an untrue statement of a material fact or omits to state any material fact required to be stated therein or necessary in order to make the statements therein not misleading (in the case of the prospectus contained therein, in the light of the circumstances under which a statement is made); (ii) the issuance or threat of issuance by the Commission of any stop order suspending the effectiveness of a Registration Statement, or the initiation of any proceedings for that purpose; or (iii) the receipt by the Partnership of any notification with respect to the suspension of the qualification of any Registrable Securities for sale under the applicable securities or blue sky laws of any jurisdiction. Following the provision of such notice, the Partnership agrees to, as promptly as practicable, amend or supplement the prospectus or prospectus supplement or take other appropriate action so that the prospectus or prospectus supplement does not include an untrue statement of a material fact or omit to state a material fact required to be stated therein or necessary in order to make the statements therein not misleading in the light of the circumstances then existing and to take such other commercially reasonable action as is necessary to remove a stop order, suspension, threat thereof or proceedings related thereto;

(g) upon request and subject to appropriate confidentiality obligations, furnish to each Selling Holder copies of any and all transmittal letters or other correspondence with the Commission or any other governmental agency or self-regulatory body or other body having jurisdiction (including any domestic or foreign securities exchange) relating to any offering of Registrable Securities;

(h) in the case of an Underwritten Offering, furnish upon request, (i) an opinion of counsel for the Partnership dated the date of the closing under the underwriting agreement and (ii) a “cold comfort” letter, dated the pricing date of such Underwritten Offering (to the extent available) and a letter of like kind dated the date of the closing under the underwriting agreement, in each case, signed by the independent public accountants who have certified the Partnership’s financial statements included or incorporated by reference into the applicable registration statement, and each of the opinion and the “cold comfort” letter shall be in customary form and covering substantially the same matters with respect to such registration statement (and the prospectus and any prospectus supplement included therein) as have been customarily covered in opinions of issuer’s counsel and in accountants’ letters delivered to the underwriters in Underwritten Offerings of securities by the Partnership and such other matters as such underwriters and Selling Holders may reasonably request;

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(i) otherwise use its commercially reasonable efforts to comply with all applicable rules and regulations of the Commission, and make available to its security holders, as soon as reasonably practicable, an earnings statement, which earnings statement shall satisfy the provisions of Section 11(a) of the Securities Act and Rule 158 promulgated thereunder;

(j) make available to the appropriate representatives of the Managing Underwriter(s) and Selling Holders access to such information and Partnership personnel as is reasonable and customary to enable such parties to establish a due diligence defense under the Securities Act;

(k) cause all Registrable Securities registered pursuant to this Agreement to be listed on each securities exchange or nationally recognized quotation system on which similar securities issued by the Partnership are then listed;

(l) use its commercially reasonable efforts to cause the Registrable Securities to be registered with or approved by such other governmental agencies or authorities as may be necessary by virtue of the business and operations of the Partnership to enable the Selling Holders to consummate the disposition of the Registrable Securities;

(m) provide a transfer agent and registrar for all Registrable Securities covered by a Registration Statement not later than the effective date of such registration statement; and

(n) enter into customary agreements and take such other actions as are reasonably requested by the Selling Holders or the underwriters, if any, in order to expedite or facilitate the disposition of the Registrable Securities.

Each Selling Holder, upon receipt of notice from the Partnership of the happening of any event of the kind described in subsection (f) of this Section 2.04, shall forthwith discontinue disposition of the Registrable Securities by means of a prospectus or prospectus supplement until such Selling Holder’s receipt of the copies of the supplemented or amended prospectus contemplated by subsection (f) of this Section 2.04 or until it is advised in writing by the Partnership that the use of the prospectus may be resumed, and has received copies of any additional or supplemental filings incorporated by reference in the prospectus.

Section 2.05. Cooperation by Holders. The Partnership shall have no obligation to include in a Registration Statement, or in an Underwritten Offering pursuant to Section 2.02(a), Registrable Securities of a Selling Holder who has failed to timely furnish such information that the Partnership determines, after consultation with counsel, is reasonably required in order for the Registration Statement or prospectus supplement, as applicable, to comply with the Securities Act.

Section 2.06. Expenses. The Partnership will pay all reasonable Registration Expenses, including in the case of an Underwritten Offering, regardless of whether any sale is made in such Underwritten Offering. Each Selling Holder shall pay all Selling Expenses in connection with any sale of its Registrable Securities hereunder. In addition, except as otherwise provided in Section 2.07, the Partnership shall not be responsible for legal fees incurred by Holders in connection with the exercise of such Holders’ rights hereunder.

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Section 2.07. Indemnification.

(a) By the Partnership. In the event of a registration of any Registrable Securities under the Securities Act pursuant to this Agreement, the Partnership will indemnify and hold harmless each Selling Holder participating therein, its directors, officers, employees and agents, and each Person, if any, who controls such Selling Holder within the meaning of the Securities Act and the Securities Exchange Act of 1934, as amended, and the rules and regulations promulgated thereunder (the “Exchange Act”), and its directors, officers, employees or agents, against any losses, claims, damages, expenses or liabilities (including reasonable attorneys’ fees and expenses) (collectively, “Losses”), joint or several, to which such Selling Holder, director, officer, employee, agent or controlling Person may become subject under the Securities Act, the Exchange Act or otherwise, insofar as such Losses (or actions or proceedings, whether commenced or threatened, in respect thereof) arise out of or are based upon any untrue statement or alleged untrue statement of any material fact (in the case of any prospectus or any Written Testing-the-Waters Communication, in the light of the circumstances under which such statement is made) contained in any Written Testing-the-Waters Communication, a Registration Statement, any preliminary prospectus or prospectus supplement, free writing prospectus or final prospectus or prospectus supplement contained therein, or any amendment or supplement thereof, or arise out of or are based upon the omission or alleged omission to state therein a material fact required to be stated therein or necessary to make the statements therein (in the case of a prospectus or any Written Testing-the-Waters Communication, in the light of the circumstances under which they were made) not misleading, and will reimburse each such Selling Holder, its directors, officers, employee and agents, and each such controlling Person for any legal or other expenses reasonably incurred by them in connection with investigating or defending any such Loss or actions or proceedings as such expenses are incurred; provided, however, that the Partnership will not be liable in any such case if and to the extent that any such Loss arises out of or is based upon an untrue statement or alleged untrue statement or omission or alleged omission so made in conformity with information furnished by such Selling Holder, its directors, officers, employees and agents or such controlling Person in writing specifically for use in any Written Testing-the-Waters Communication, a Registration Statement, or prospectus or any amendment or supplement thereto, as applicable. Such indemnity shall remain in full force and effect regardless of any investigation made by or on behalf of such Selling Holder or any such directors, officers, employees agents or controlling Person, and shall survive the transfer of such securities by such Selling Holder.

(b) By Each Selling Holder. Each Selling Holder agrees severally and not jointly to indemnify and hold harmless the Partnership, its directors, officers, employees and agents and each Person, if any, who controls the Partnership within the meaning of the Securities Act or of the Exchange Act, and its directors, officers, employees and agents, to the same extent as the foregoing indemnity from the Partnership to the Selling Holders, but only with respect to information regarding such Selling Holder furnished in writing by or on behalf of such Selling Holder expressly for inclusion in any Written Testing-the-Waters Communication, a Registration Statement, any preliminary prospectus or prospectus supplement, free writing prospectus or final prospectus or prospectus supplement contained therein, or any amendment or supplement thereof; provided, however, that the liability of each Selling Holder shall not be greater in amount than the dollar amount of the proceeds (net of any Selling Expenses) received by such Selling Holder from the sale of the Registrable Securities giving rise to such indemnification.

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(c) Notice. Promptly after receipt by an indemnified party hereunder of notice of the commencement of any action, such indemnified party shall, if a claim in respect thereof is to be made against the indemnifying party hereunder, notify the indemnifying party in writing thereof, but the omission so to notify the indemnifying party shall not relieve the indemnifying party from any liability that it may have to any indemnified party other than under this Section 2.07. In any action brought against any indemnified party, the indemnified party shall notify the indemnifying party of the commencement thereof. The indemnifying party shall be entitled to participate in and, to the extent it shall wish, to assume and undertake the defense thereof with counsel reasonably satisfactory to such indemnified party and, after notice from the indemnifying party to such indemnified party of its election so to assume and undertake the defense thereof, the indemnifying party shall not be liable to such indemnified party under this Section 2.07 for any legal expenses subsequently incurred by such indemnified party in connection with the defense thereof other than reasonable costs of investigation and of liaison with counsel so selected; provided, however, that, (i) if the indemnifying party has failed to assume the defense or employ counsel reasonably acceptable to the indemnified party or (ii) if the defendants in any such action include both the indemnified party and the indemnifying party and counsel to the indemnified party shall have concluded that there may be reasonable defenses available to the indemnified party that are different from or additional to those available to the indemnifying party, or if the interests of the indemnified party reasonably may be deemed to conflict with the interests of the indemnifying party, then the indemnified party shall have the right to select a separate counsel and to assume such legal defense and otherwise to participate in the defense of such action, with the reasonable expenses and fees of such separate counsel and other reasonable expenses related to such participation to be reimbursed by the indemnifying party as incurred. Notwithstanding any other provision of this Agreement, no indemnified party shall settle any action brought against it with respect to which it is entitled to indemnification hereunder without the consent of the indemnifying party, unless the settlement thereof imposes no liability or obligation on, and includes a complete and unconditional release from all liability of, the indemnifying party.

(d) Contribution. If the indemnification provided for in this Section 2.07 is held by a court or government agency of competent jurisdiction to be unavailable to any indemnified party or is insufficient to hold them harmless in respect of any Losses, then each indemnifying party, in lieu of indemnifying such indemnified party, shall contribute to the amount paid or payable by such indemnified party as a result of such Loss in such proportion as is appropriate to reflect the relative fault of the indemnifying party on the one hand and of such indemnified party on the other in connection with the statements or omissions that resulted in such Losses, as well as any other relevant equitable considerations; provided, however, that in no event shall the Selling Holder be required to contribute an aggregate amount in excess of the dollar amount of proceeds (net of Selling Expenses) received by such Selling Holder from the sale of Registrable Securities giving rise to such indemnification. The relative fault of the indemnifying party on the one hand and the indemnified party on the other shall be determined by reference to, among other things, whether the untrue or alleged untrue statement of a material fact or the omission or alleged omission to state a material fact has been made by, or relates to, information supplied by such party, and the parties’ relative intent, knowledge, access to information and opportunity to correct or prevent such statement or omission. The parties hereto agree that it would not be just and equitable if contributions pursuant to this paragraph were to be determined by pro rata allocation or by any other method of allocation that does not take account of the equitable

9

considerations referred to herein. The amount paid by an indemnified party as a result of the Losses referred to in the first sentence of this paragraph shall be deemed to include any legal and other expenses reasonably incurred by such indemnified party in connection with investigating or defending any Loss that is the subject of this paragraph. No person guilty of fraudulent misrepresentation (within the meaning of Section 11(f) of the Securities Act) shall be entitled to contribution from any Person who is not guilty of fraudulent misrepresentation.

(e) Other Indemnification. The provisions of this Section 2.07 shall be in addition to any other rights to indemnification or contribution that an indemnified party may have pursuant to law, equity, contract or otherwise.

Section 2.08. Rule 144 Reporting. With a view to making available the benefits of certain rules and regulations of the Commission that may permit the sale of the Registrable Securities to the public without registration, the Partnership agrees to use its commercially reasonable efforts to:

(a) make and keep public information regarding the Partnership available, as those terms are understood and defined in Rule 144 under the Securities Act, at all times from and after the date hereof;

(b) file with the Commission in a timely manner all reports and other documents required of the Partnership under the Exchange Act at all times from and after the date hereof; and

(c) so long as a Holder owns any Registrable Securities, unless otherwise available via EDGAR, furnish to such Holder forthwith upon request a copy of the most recent annual or quarterly report of the Partnership, and such other reports and documents so filed as such Holder may reasonably request in availing itself of any rule or regulation of the Commission allowing such Holder to sell any such securities without registration.

Section 2.09. Transfer or Assignment of Registration Rights. The rights to cause the Partnership to register Registrable Securities granted to a Holder by the Partnership under this Article II may be transferred or assigned by such Holder to one or more transferee(s) or assignee(s) of such Registrable Securities; provided, however, that (a) unless such transferee or assignee is an Affiliate of MLP Holdco, each such transferee or assignee holds Registrable Securities representing at least five percent (5%) of the then-outstanding Registrable Securities (subject to adjustment pursuant to Section 3.04), (b) the Partnership is given written notice prior to any said transfer or assignment, stating the name and address of each such transferee and identifying the Registrable Securities with respect to which such registration rights are being transferred or assigned, and (c) each such transferee agrees to be bound by this Agreement.

Section 2.10. Restrictions on Public Sale by Holders of Registrable Securities. MLP Holdco and any other Holder(s) who, along with its Affiliates, holds at least five percent (5%) of the then-outstanding Registrable Securities (subject to adjustment pursuant to Section 3.04), agrees to enter into a customary letter agreement with underwriters providing such Holder will not effect any public sale or distribution of the Registrable Securities during the 90 calendar day period beginning on the date of a prospectus or prospectus supplement filed with the

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Commission with respect to the pricing of an Underwritten Offering, provided that (i) the duration of the foregoing restrictions shall be no longer than the duration of the shortest restriction generally imposed by the underwriters on the Partnership or the officers, directors or any other unitholder of the Partnership on whom a restriction is imposed and (ii) the restrictions set forth in this Section 2.10 shall not apply to any Registrable Securities that are included in such Underwritten Offering by such Holder.

ARTICLE III

MISCELLANEOUS

Section 3.01. Communications. All notices and other communications provided for or permitted hereunder shall be made in writing by facsimile, electronic mail, courier service or personal delivery:

(a) if to MLP Holdco:

Dominion MLP Holding Company II, Inc.

120 Tredegar Street

Richmond, Virginia 23220

Attention: Treasurer

Facsimile: 804-819-2638

Electronic Mail: scott.hetzer@dom.com

(b) if to a transferee of MLP Holdco, to such Holder at the address provided pursuant to Section 2.09; and

(c) if to the Partnership:

Dominion Midstream Partners, LP

c/o Dominion Midstream GP, LLC

120 Tredegar Street

Richmond, Virginia 23220

Attention: General Counsel

Facsimile: 804-819-2202

Electronic Mail: mark.webb@dom.com

All such notices and communications shall be deemed to have been received at the time delivered by hand, if personally delivered; when receipt acknowledged, if sent via facsimile or sent via electronic mail; and when actually received, if sent by courier service or any other means.

Section 3.02. Successor and Assigns. This Agreement shall inure to the benefit of and be binding upon the successors and assigns of each of the parties, including subsequent Holders of Registrable Securities to the extent permitted herein.

Section 3.03. Assignment of Rights. All or any portion of the rights and obligations of the Holders under this Agreement may be transferred or assigned by the Holders in accordance with Section 2.09 hereof.

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Section 3.04. Recapitalization, Exchanges, Etc. Affecting the Registrable Securities. The provisions of this Agreement shall apply to the full extent set forth herein with respect to any and all securities of the Partnership or any successor or assign of the Partnership (whether by merger, consolidation, sale of assets or otherwise) that may be issued in respect of, in exchange for or in substitution of, the Registrable Securities, and shall be appropriately adjusted for combinations, splits, recapitalizations, pro rata distributions and the like occurring after the date of this Agreement.

Section 3.05. Specific Performance. Damages in the event of breach of this Agreement by a party hereto may be difficult, if not impossible, to ascertain, and it is therefore agreed that each party in addition to and without limiting any other remedy or right it may have, will have the right to an injunction or other equitable relief in any court of competent jurisdiction, enjoining any such breach, and enforcing specifically the terms and provisions hereof, and each of the parties hereto hereby waives any and all defenses it may have on the ground of lack of jurisdiction or competence of the court to grant such an injunction or other equitable relief. The existence of this right will not preclude any such party from pursuing any other rights and remedies at law or in equity that such party may have.

Section 3.06. Counterparts. This Agreement may be executed in any number of counterparts and by different parties hereto in separate counterparts, each of which counterparts, when so executed and delivered, shall be deemed to be an original and all of which counterparts, taken together, shall constitute but one and the same Agreement.

Section 3.07. Headings. The headings in this Agreement are for convenience of reference only and shall not limit or otherwise affect the meaning hereof.

Section 3.08. Governing Law. The laws of the State of Delaware shall govern this Agreement. Each of the parties hereto agrees (a) that this Agreement involves at least $100,000.00, and (b) that this Agreement has been entered into by the parties hereto in express reliance upon 6 Del. C. § 2708. Each of the parties hereto hereby irrevocably and unconditionally agrees (i) that it is and shall continue to be subject to the jurisdiction of the courts of the State of Delaware and of the federal courts sitting in the State of Delaware, and (ii)(A) to the extent that such party is not otherwise subject to service of process in the State of Delaware, to appoint and maintain an agent in the State of Delaware as such party’s agent for acceptance of legal process and notify the other parties hereto of the name and address of such agent, and (B) to the fullest extent permitted by law, that service of process may also be made on such party by prepaid certified mail with a proof of mailing receipt validated by the U.S. Postal Service constituting evidence of valid service, and that, to the fullest extent permitted by applicable law, service made pursuant to (ii)(A) or (B) above shall have the same legal force and effect as if served upon such party personally within the State of Delaware. This Agreement may be executed in several counterparts, each of which shall be considered an original but which together shall be deemed one and the same instrument. An executed copy of this Agreement delivered by facsimile, email or other means of electronic transmission shall be deemed to have the same legal effect as delivery of an original executed copy of this Agreement.

Section 3.09. Severability of Provisions. Any provision of this Agreement that is prohibited or unenforceable in any jurisdiction shall, as to such jurisdiction, be ineffective to the

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extent of such prohibition or unenforceability without invalidating the remaining provisions hereof or affecting or impairing the validity or enforceability of such provision in any other jurisdiction.

Section 3.10. Scope of Agreement. The rights granted pursuant to this Agreement are intended to supplement and not to reduce or replace any rights any Holders may have under the Partnership Agreement with respect to the Registrable Securities. This Agreement is intended by the parties as a final expression of their agreement and intended to be a complete and exclusive statement of the agreement and understanding of the parties hereto in respect of the subject matter contained herein. Except as provided in the Partnership Agreement, there are no restrictions, promises, warranties or undertakings, other than those set forth or referred to herein with respect to the rights granted by the Partnership set forth herein. Except as provided in the Partnership Agreement, this Agreement supersedes all prior agreements and understandings between the parties with respect to such subject matter.

Section 3.11. Amendment. This Agreement may be amended only by means of a written amendment signed by the Partnership and the Holders of a majority of the then outstanding Registrable Securities; provided, however, that no such amendment shall materially and adversely affect the rights of any Holder hereunder without the consent of such Holder.

Section 3.12. No Presumption. If any claim is made by a party relating to any conflict, omission, or ambiguity in this Agreement, no presumption or burden of proof or persuasion shall be implied by virtue of the fact that this Agreement was prepared by or at the request of a particular party or its counsel.

Section 3.13. Aggregation of Registrable Securities. All Registrable Securities held or acquired by Persons who are Affiliates of one another shall be aggregated together for the purpose of determining the availability of any rights under this Agreement.

Section 3.14. Obligations Limited to Parties to Agreement. Each of the parties hereto covenants, agrees and acknowledges that no Person other than the Partnership and the Holders shall have any obligation hereunder and that, notwithstanding that one or more of the Holders may be a corporation, partnership or limited liability company, no recourse under this Agreement or under any documents or instruments delivered in connection herewith or therewith shall be had against any former, current or future director, officer, employee, agent, general or limited partner, manager, member, stockholder or Affiliate of any of the Holders or any former, current or future director, officer, employee, agent, general or limited partner, manager, member, stockholder or Affiliate of any of the foregoing, whether by the enforcement of any assessment or by any legal or equitable proceeding, or by virtue of any applicable law, it being expressly agreed and acknowledged that no personal liability whatsoever shall attach to, be imposed on or otherwise be incurred by any former, current or future director, officer, employee, agent, general or limited partner, manager, member, stockholder or Affiliate of any of the Holders or any former, current or future director, officer, employee, agent, general or limited partner, manager, member, stockholder or Affiliate of any of the foregoing, as such, for any obligations of the Holders under this Agreement or any documents or instruments delivered in connection herewith or therewith or for any claim based on, in respect of or by reason of such obligation or its creation, except in each case for any assignee of the Holders hereunder.

Section 3.15. Interpretation. All references to “Articles” and “Sections” shall be deemed to be references to Articles and Sections of this Agreement, unless otherwise specified.

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All references to instruments, documents, contracts and agreements are references to such instruments, documents, contracts and agreements as the same may be amended, supplemented and otherwise modified from time to time, unless otherwise specified. The word “including” shall mean “including but not limited to.” Whenever any determination, consent or approval is to be made or given by the Holders under this Agreement, such action shall be in the Holders’ sole discretion unless otherwise specified.

[Signature page follows]

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IN WITNESS WHEREOF, the parties hereto execute this Agreement, effective as of the date first above written.

DOMINION MLP HOLDING COMPANY II, INC.
By:	/s/ G. Scott Hetzer
Name:	G. Scott Hetzer
Title:	Senior Vice President and Treasurer
DOMINION MIDSTREAM PARTNERS, LP
By:	Dominion Midstream GP, LLC
Its:	General Partner
	By:	/s/ Mark O. Webb
	Name:	Mark O. Webb
	Title:	Vice President and General Counsel

SIGNATURE PAGE

TO

REGISTRATION RIGHTS AGREEMENT

EX-31.A

Exhibit 31.a

I, Thomas F. Farrell II, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Midstream 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 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)) 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) 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

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

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of 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: August 6, 2015	/s/    Thomas F. Farrell II
	Thomas F. Farrell II
	President and Chief Executive Officer Of Dominion Midstream GP, LLC
	(the general partner of Dominion Midstream Partners, LP)

EX-31.B

Exhibit 31.b

I, Mark F. McGettrick, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Midstream 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 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)) 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) 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

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

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of 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: August 6, 2015	/s/    Mark F. McGettrick
	Mark F. McGettrick
	Executive Vice President and Chief Financial Officer
	Of Dominion Midstream GP, LLC
	(the general partner of Dominion Midstream Partners, LP)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned officers of Dominion Midstream GP, LLC, the general partner of Dominion Midstream Partners, LP (“Dominion Midstream”), certify that:

1. the Quarterly Report on Form 10-Q for the quarter ended June 30, 2015 (the “Report”), of Dominion Midstream to which this certification is an exhibit fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)).

2. the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Dominion Midstream as of June 30, 2015, and for the period then ended.

/s/ Thomas F. Farrell II

Thomas F. Farrell II

President and Chief Executive Officer

Of Dominion Midstream GP, LLC

(the general partner of Dominion Midstream Partners, LP)

August 6, 2015

/s/ Mark F. McGettrick

Mark F. McGettrick

Executive Vice President and Chief Financial Officer

Of Dominion Midstream GP, LLC

(the general partner of Dominion Midstream Partners, LP)

August 6, 2015

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Net Income Per Limited Partner Unit (Details) - USD ($) $ / shares in Units, $ in Millions				3 Months Ended	6 Months Ended
		Jul. 17, 2015	Apr. 22, 2015	Jun. 30, 2015	Jun. 30, 2015
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income attributable to partners				$ 17.6	$ 29.4
General partner allocation	[1]			(0.7)	(0.7)
Incentive distribution holder rights	[2]			0.0	0.0
Distribution declared on Common and Subordinated unitholders			$ 12.1
Total distributions declared				12.9	25.0
Undistributed earnings				5.4	5.1
Quarterly distribution per unit			$ 0.1750
General Partner
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income attributable to partners				(0.7)	(0.7)
General partner allocation				(0.7)	(0.7)
Total distributions declared				0.0	0.0
Undistributed earnings				0.0	0.0
Subsequent Event
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distribution declared on Common and Subordinated unitholders		$ 12.9
Quarterly distribution per unit		$ 0.1875
Common Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distribution declared on Common and Subordinated unitholders	[3]			$ 6.9	$ 13.4
Net income per limited partner unit (basic and diluted)				$ 0.26	$ 0.47
Common Units | Limited Partners
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income attributable to partners				$ 9.8	$ 16.0
General partner allocation				0.0	0.0
Total distributions declared				6.9	13.4
Undistributed earnings				$ 2.9	$ 2.6
Weighted average units outstanding				37,092,305	34,550,329
Net income per limited partner unit (basic and diluted)				$ 0.26	$ 0.47
Subordinated Units
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Distribution declared on Common and Subordinated unitholders	[3]			$ 6.0	$ 11.6
Net income per limited partner unit (basic and diluted)				$ 0.26	$ 0.44
Subordinated Units | Limited Partners
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items]
Net income attributable to partners				$ 8.5	$ 14.1
General partner allocation				0.0	0.0
Total distributions declared				6.0	11.6
Undistributed earnings				$ 2.5	$ 2.5
Weighted average units outstanding				31,972,789	31,972,789
Net income per limited partner unit (basic and diluted)				$ 0.26	$ 0.44

[1] See Note 2 for further information.

[2] Dominion is a non-economic general partner that holds all of the IDRs.

[3] On July 17, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1875 per unit, totaling $12.9 million, for the three months ended June 30, 2015. This distribution will be paid on August 14, 2015 to unitholders of record on August 4, 2015. The amount of distributions declared shown above is based on the units outstanding at June 30, 2015.On April 22, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1750 per unit, totaling $12.1 million, for the three months ended March 31, 2015. This distribution was paid on May 15, 2015 to unitholders of record on May 5, 2015.

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Related Party Transactions (Details) - USD ($)				1 Months Ended		3 Months Ended		6 Months Ended		10 Months Ended
		Apr. 01, 2015	Oct. 20, 2014	Jul. 31, 2015	Feb. 28, 2015	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Oct. 19, 2014	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Imbalances payable to affiliates	[1]					$ 3,500,000		$ 3,500,000			$ 2,700,000
Equity contributions from Dominion								272,500,000
Dominion | DCGT
Related Party Transaction [Line Items]
Equity contributions from Dominion								2,300,000
Affiliates
Related Party Transaction [Line Items]
Sales of natural gas transportation services to affiliates						400,000		1,100,000
Capital expenditures						3,100,000		5,500,000
Imbalances payable to affiliates						3,400,000		3,400,000			2,500,000
Affiliates | Pension and Other Postretirement Benefit Liabilities
Related Party Transaction [Line Items]
Amounts due to Dominion associated with benefit plans						4,700,000		4,700,000			4,400,000
Affiliates | Predecessor
Related Party Transaction [Line Items]
Sales of natural gas transportation services to affiliates							$ 500,000		$ 1,300,000
Capital expenditures							1,700,000		3,700,000
Affiliates | Cove Point | Predecessor | Payables to Affiliates
Related Party Transaction [Line Items]
Advance from affiliate												$ 20,000,000
Affiliates | Dominion | DCGT | Partnership Interest
Related Party Transaction [Line Items]
Equity contribution from Dominion to relieve payables to affiliates		$ 1,000,000
Total transaction costs associated with DCGT acquisition						1,000,000
Affiliates | Dominion | DCGT | General Partner Dominion (non-economic interest) | Partnership Interest
Related Party Transaction [Line Items]
Equity contributions from Dominion						700,000
Affiliates | Reimbursement of transition services costs by affiliate | DCGT
Related Party Transaction [Line Items]
Goods and services provided by affiliates						1,100,000
Affiliates | Purchased gas from affiliates
Related Party Transaction [Line Items]
Purchased gas from affiliates						100,000		300,000
Affiliates | Purchased gas from affiliates | Predecessor
Related Party Transaction [Line Items]
Purchased gas from affiliates							200,000		400,000
Affiliates | Services provided by DRS
Related Party Transaction [Line Items]
Goods and services provided by affiliates	[2],[3]					4,200,000		7,800,000
Affiliates | Services provided by DRS | Predecessor
Related Party Transaction [Line Items]
Goods and services provided by affiliates	[2],[3]						2,800,000		6,100,000
Affiliates | Goods and services provided by affiliates to Cove Point
Related Party Transaction [Line Items]
Goods and services provided by affiliates	[3]					5,300,000		8,900,000
Affiliates | Goods and services provided by affiliates to Cove Point | Predecessor
Related Party Transaction [Line Items]
Goods and services provided by affiliates	[3]						$ 800,000		$ 1,500,000
Affiliates | Credit Facility with Dominion | Line of Credit
Related Party Transaction [Line Items]
Amount outstanding against the credit facility						5,900,000		$ 5,900,000			$ 0
Termination notice period								90 days
Interest charges related to borrowing from Dominion						100,000		$ 100,000
Affiliates | Credit Facility with Dominion | IPO | Line of Credit
Related Party Transaction [Line Items]
Borrowing capacity			$ 300,000,000
Affiliates | Tax Sharing Agreement | DCGT | Equity contribution from Dominion related to income taxes
Related Party Transaction [Line Items]
Settlement of income taxes payable and net deferred income taxes through an equity transaction with Dominion		$ 13,400,000
Affiliates | Tax Sharing Agreement | Cove Point | Equity contribution from Dominion related to income taxes
Related Party Transaction [Line Items]
Equity contribution from Dominion to relieve payables to affiliates			$ 147,900,000
Affiliates | Tax Sharing Agreement | Cove Point | Predecessor | Equity contribution from Dominion related to income taxes
Related Party Transaction [Line Items]
Equity contribution from Dominion to relieve payables to affiliates										$ 1,200,000
Affiliates | Capital Expenditures related to Liquefaction Project | Cove Point
Related Party Transaction [Line Items]
Contributions from Dominion						$ 271,800,000
Affiliates | Capital Expenditures related to Liquefaction Project | Cove Point | Subsequent Event
Related Party Transaction [Line Items]
Contributions from Dominion				$ 110,200,000
Affiliates | Contribution to Fund Operations | DCGT | Predecessor
Related Party Transaction [Line Items]
Contributions from Dominion					$ 1,300,000

[1] See Note 15 for amounts attributable to related parties.

[2] Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with DRS, an affiliated variable interest entity, and therefore none is the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated subsidiaries has an obligation to absorb more than its allocated share of DRS costs.Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with Dominion Payroll, an affiliated variable interest entity, and therefore none is the primary beneficiary. Dominion Payroll provides human resources and operations services to certain Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated entities has an obligation to absorb more than its allocated share of Dominion Payroll costs.

[3] Includes $3.1 million and $5.5 million of capitalized expenditures for the three and six months ended June 30, 2015, and $1.7 million and $3.7 million for the three and six months ended June 30, 2014.

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Regulatory Assets and Liabilities (Regulatory Liabilities) (Details) - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		$ 7.2	$ 3.6
Regulatory liabilities-non-current		71.0	33.5
Total regulatory liabilities		78.2	37.1
Overrecovered gas costs
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[1]	0.0	0.5
LNG cargo obligations
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[2]	3.6	3.0
Customer bankruptcy settlement
Regulatory Liabilities [Line Items]
Regulatory liabilities-current	[3]	2.9	0.0
Regulatory liabilities-non-current	[3]	21.9	0.0
Other
Regulatory Liabilities [Line Items]
Regulatory liabilities-current		0.7	0.1
Regulatory liabilities-non-current		1.4	0.5
Provision for future cost of removal
Regulatory Liabilities [Line Items]
Regulatory liabilities-non-current	[4]	$ 47.7	$ 33.0

[1] Reflects unrecovered/overrecovered gas costs, which are subject to annual filings with the FERC.

[2] Reflects obligations to the Import Shippers for LNG cargo received. See Note 9 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014 for further information.

[3] Represents the balance of proceeds from the monetization of a bankruptcy claim acquired as part of the DCGT Acquisition, which is being amortized into operating revenue through February 2024.

[4] Rates charged to customers include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.

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Income Taxes (Details)		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014
Income Taxes [Line Items]
U.S. statutory rate		35.00%
Income not subject to income taxes	[1]	(32.90%)
Increases resulting from:
State taxes, net of federal benefit	[2]	0.20%
Effective tax rate		2.30%
Predecessor
Income Taxes [Line Items]
U.S. statutory rate			35.00%
Income not subject to income taxes	[1]		(0.00%)
Increases resulting from:
State taxes, net of federal benefit	[2]		3.20%
Effective tax rate			38.20%

[1] Reflects the pass-through entity status of Dominion Midstream, including the operations of DCGT subsequent to the DCGT Acquisition, and Cove Point.

[2] 2015 amounts are attributable to the operations of DCGT prior to the DCGT Acquisition, and 2014 amounts are attributable to Cove Point.

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Goodwill and Intangible Assets (Schedule of Components of Intangible Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 41.8	$ 17.5
Accumulated Amortization	25.5	5.4
Software and other
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	30.8	6.5
Accumulated Amortization	22.3	2.4
Licenses
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	11.0	11.0
Accumulated Amortization	$ 3.2	$ 3.0

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Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2015

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

Affiliated transactions are presented below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(millions)
Sales of natural gas transportation services to affiliates	$	0.4	$	0.5	$	1.1	$	1.3
Purchased gas from affiliates	0.1		0.2		0.3		0.4
Services provided by DRS and Dominion Payroll(1)(2)	4.2		2.8		7.8		6.1
Goods and services provided by affiliates to Dominion Midstream(1)	5.3		0.8		8.9		1.5

(1) Includes $3.1 million and $5.5 million of capitalized expenditures for the three and six months ended June 30, 2015, and $1.7 millionand $3.7 million for the three and six months ended June 30, 2014.

(2) Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with DRS, an affiliated variable interest entity, and therefore none is the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated subsidiaries has an obligation to absorb more than its allocated share of DRS costs.

Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with Dominion Payroll, an affiliated variable interest entity, and therefore none is the primary beneficiary. Dominion Payroll provides human resources and operations services to certain Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated entities has an obligation to absorb more than its allocated share of Dominion Payroll costs.

The imbalances with affiliates are provided below:

	June 30, 2015		December 31, 2014
(millions)
Imbalances payable to affiliates	$	3.4	$	2.5

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Acquisition (Tables)

6 Months Ended

Jun. 30, 2015

Business Combinations [Abstract]

Schedule of Consolidated Statement of Income

The following table presents Dominion Midstream's Consolidated Statement of Income for the six months ended June 30, 2015 giving effect to the DCGT Acquisition. The results of DCGT from January 31, 2015 through March 31, 2015 are included in "DCGT Predecessor." The results of DCGT beginning on April 1, 2015 are included in "Dominion Midstream."

	Six Months Ended June 30, 2015
	Dominion Midstream		DCGT Predecessor		Dominion Midstream (as reported)
(in millions)
Operating Revenue	$	172.6	$	11.2	$	183.8
Operating Expenses
Purchased gas	29.4		—		29.4
Other operations and maintenance:
Affiliated suppliers	8.7		2.5		11.2
Other	15.8		2.3		18.1
Depreciation and amortization	19.2		1.3		20.5
Other taxes	11.9		0.8		12.7
Total operating expenses	85.0		6.9		91.9
Income from operations	87.6		4.3		91.9
Other income	0.3		0.1		0.4
Interest and related charges	0.2		—		0.2
Income from operations including noncontrolling interest before income taxes	87.7		4.4		92.1
Income tax expense	—		2.1		2.1
Net income including noncontrolling interest and DCGT Predecessor	87.7		2.3		90.0
Less: Net income attributable to DCGT Predecessor	—		2.3		2.3
Net income including noncontrolling interest	87.7		—		87.7
Less: Net income attributable to noncontrolling interest	58.3		—		58.3
Net income attributable to partners	$	29.4	$	—	$	29.4

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Asset Retirement Obligations (Details) - USD ($) $ in Millions		6 Months Ended	12 Months Ended
		Jun. 30, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	[1]	$ 0.4
DCGT Acquisition		12.6	$ 0.0
Obligations settled during the period		(0.3)	0.0
Accretion		0.3	0.0
Ending balance	[1]	13.0	0.4
Other Current Liabilities
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Amounts reported in other current liabilities		$ 0.3	0.1
Predecessor
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	[1]		$ 0.4

[1] Includes $0.1 million and $0.3 million reported in other current liabilities at December 31, 2014, and June 30, 2015, respectively.

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Property Plant and Equipment (Schedule of Property Plant and Equipment) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 3,152.8		$ 2,203.1
Capitalized interest costs and AFUDC	0.6
Storage
Property, Plant and Equipment [Line Items]
Property, plant and equipment	875.1		882.0
Transmission
Property, Plant and Equipment [Line Items]
Property, plant and equipment	666.2		323.9
Plant under construction
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,575.6		972.3
General and other
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 35.9		$ 24.9
Predecessor
Property, Plant and Equipment [Line Items]
Capitalized interest costs and AFUDC		$ 0.0

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Acquisition (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended	6 Months Ended
	Apr. 01, 2015	Jun. 30, 2015	Jun. 30, 2015
Business Acquisition [Line Items]
Equity contributions from Dominion			$ 272.5
DCGT | Dominion
Business Acquisition [Line Items]
Equity contributions from Dominion			$ 2.3
DCGT | Dominion | Affiliates
Business Acquisition [Line Items]
Total consideration	$ 500.8
Historical cost of assets and liabilities of DCGT	$ 501.6
DCGT | Dominion | Affiliates | Other Operations and Maintenance Expense
Business Acquisition [Line Items]
Total transaction costs associated with DCGT acquisition		$ 1.0
DCGT | Dominion | Affiliates | Partnership Interest
Business Acquisition [Line Items]
Number of common units issued	5,112,139
Value of common units issued	$ 200.0
Number of trading days	10 days
Price per unit	$ 39.12
Total transaction costs associated with DCGT acquisition		1.0
DCGT | Dominion | Affiliates | Partnership Interest | General Partner Dominion (non-economic interest)
Business Acquisition [Line Items]
Equity contributions from Dominion		$ 0.7
DCGT | Dominion | Affiliates | Notes Payable | Senior Unsecured Promissory Note Payable
Business Acquisition [Line Items]
Term of senior unsecured promissory note payable	2 years
Senior unsecured promissory note payable	$ 300.8
Annual interest rate (percentage)	0.60%

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Commitments and Contingencies (Details) - Jun. 30, 2015 - USD ($)	Total	Total
Other Operations and Maintenance Expense
Other Commitments [Line Items]
Rental expense	$ 700,000	$ 1,400,000
Surety Bond
Other Commitments [Line Items]
Total amount of commitment	10,800,000	$ 10,800,000
Maximum
Other Commitments [Line Items]
Operating lease arrangements term		1 year
Annual Contributions to Cove Point Natural Heritage Trust
Other Commitments [Line Items]
Total amount of commitment	300,000	$ 300,000
Annual Contributions to Cove Point Natural Heritage Trust | Minimum
Other Commitments [Line Items]
Total amount of commitment	$ 0	$ 0

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Regulatory Assets and Liabilities (Regulatory Assets) (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2015	Dec. 31, 2014
Regulatory Assets [Line Items]
Regulatory assets-current		$ 2.6	$ 1.7
Regulatory assets-non-current		2.6	2.5
Total regulatory assets		5.2	4.2
Past expenditures in which no return is expected		$ 2.6
Recovery period of expenditures		1 year
Unrecovered gas costs
Regulatory Assets [Line Items]
Regulatory assets-current	[1]	$ 2.2	1.5
Other
Regulatory Assets [Line Items]
Regulatory assets-current		0.4	0.2
Income taxes recoverable through future rates
Regulatory Assets [Line Items]
Regulatory assets-non-current	[2]	$ 2.6	$ 2.5

[1] Reflects unrecovered/overrecovered gas costs, which are subject to annual filings with the FERC.

[2] Amounts to be recovered through future rates to pay income taxes that become payable by unitholders when rate revenue is provided to recover AFUDC-equity when such amounts are recovered through book depreciation.

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Significant Accounting Policies

6 Months Ended

Jun. 30, 2015

Accounting Policies [Abstract]

Significant Accounting Policies

Significant Accounting Policies

Interim Financial Information and Estimates

As permitted by the rules and regulations of the SEC, Dominion Midstream's accompanying unaudited Consolidated Financial Statements exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014.

In the opinion of management, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly Dominion Midstream's financial position as of June 30, 2015, its results of operations for the three and six months ended June 30, 2015 and 2014, and its cash flows and changes in equity for the six months ended June 30, 2015 and 2014. Such adjustments are normal and recurring in nature unless otherwise noted.

Dominion Midstream makes certain estimates and assumptions in preparing its Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses for the periods presented. Actual results may differ from those estimates.

The results of operations for interim periods are not necessarily indicative of the results expected for the full year. Information for quarterly periods is affected by seasonal variations in sales, rate changes, purchased gas expenses and other factors.

Asset Retirement Obligations

Dominion Midstream recognizes AROs at fair value as incurred or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, Dominion Midstream evaluates the key assumptions underlying its AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion Midstream reports accretion of AROs and depreciation on asset retirement costs associated with its natural gas pipeline assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs.

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Property Plant and Equipment (Schedule of Depreciation Rates on Utility Property Plant and Equipment) (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Storage
Property, Plant and Equipment [Line Items]
Depreciation rates (percentage)	2.39%		2.38%
Transmission
Property, Plant and Equipment [Line Items]
Depreciation rates (percentage)	2.28%		2.28%
General and other
Property, Plant and Equipment [Line Items]
Depreciation rates (percentage)	7.68%		7.65%
Predecessor | Storage
Property, Plant and Equipment [Line Items]
Depreciation rates (percentage)		2.38%		2.38%
Predecessor | Transmission
Property, Plant and Equipment [Line Items]
Depreciation rates (percentage)		2.82%		2.82%
Predecessor | General and other
Property, Plant and Equipment [Line Items]
Depreciation rates (percentage)		4.24%		3.58%

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Property Plant and Equipment (Tables)

6 Months Ended

Jun. 30, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Depreciation rates on utility property, plant and equipment are as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2015	2014	2015	2014
(percent)
Storage	2.39	2.38	2.38	2.38
Transmission	2.28	2.82	2.28	2.82
General and other	7.68	4.24	7.65	3.58

Major classes of property, plant and equipment and their respective balances for Dominion Midstream are as follows:

	June 30, 2015		December 31, 2014
(millions)
Storage	$	875.1	$	882.0
Transmission	666.2		323.9
Plant under construction	1,575.6		972.3
General and other	35.9		24.9
Total property, plant and equipment	$	3,152.8	$	2,203.1

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Operating Revenue (Tables)

6 Months Ended

Jun. 30, 2015

Revenue Recognition [Abstract]

Operating Revenue

Dominion Midstream's operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(millions)
Gas transportation and storage	$	78.9	$	64.9	$	153.6	$	130.5
Other	26.5		46.3		30.2		49.6
Total operating revenue	$	105.4	$	111.2	$	183.8	$	180.1

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Operating Segment (Schedule of Segment Reporting Information, by Segment) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Segment Reporting Information [Line Items]
Operating revenue	[1]	$ 105.4		$ 183.8
Net income including noncontrolling interest and DCGT Predecessor		47.2		90.0
Net income including noncontrolling interest		47.2		87.7
Net income attributable to partners		17.6		29.4
Predecessor
Segment Reporting Information [Line Items]
Operating revenue	[1]		$ 111.2		$ 180.1
Net income including noncontrolling interest and DCGT Predecessor			24.2		48.8
Dominion Energy
Segment Reporting Information [Line Items]
Operating revenue		105.4		183.8
Net income including noncontrolling interest and DCGT Predecessor		47.9		91.7
Net income including noncontrolling interest				88.4
Net income attributable to partners		18.3		30.1
Dominion Energy | Predecessor
Segment Reporting Information [Line Items]
Operating revenue			111.2		180.1
Net income including noncontrolling interest and DCGT Predecessor			24.2		48.8
Corporate and Other
Segment Reporting Information [Line Items]
Operating revenue		0.0		0.0
Net income including noncontrolling interest and DCGT Predecessor		(0.7)		(1.7)
Net income including noncontrolling interest				(0.7)
Net income attributable to partners		$ (0.7)		$ (0.7)
Corporate and Other | Predecessor
Segment Reporting Information [Line Items]
Operating revenue			0.0		0.0
Net income including noncontrolling interest and DCGT Predecessor			$ 0.0		$ 0.0

[1] See Note 15 for amounts attributable to related parties.

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Goodwill and Intangible Assets (Schedule of Goodwill) (Details) $ in Millions		6 Months Ended
		Jun. 30, 2015 USD ($)
Goodwill [Roll Forward]
Beginning balance	[1]	$ 45.9
Acquired goodwill		249.6
Ending balance	[1]	295.5
Dominion Energy
Goodwill [Roll Forward]
Beginning balance	[1]	45.9
Acquired goodwill		249.6
Ending balance	[1]	295.5
Corporate and Other
Goodwill [Roll Forward]
Beginning balance	[1]	0.0
Acquired goodwill		0.0
Ending balance	[1]	$ 0.0

[1] There are no accumulated impairment losses.

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Goodwill and Intangible Assets (Tables)

6 Months Ended

Jun. 30, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Schedule of Goodwill

The changes in Dominion Midstream's carrying amount and segment allocation of goodwill are presented below:

	Dominion Energy		Corporate and Other		Total
(millions)
Six Months Ended June 30, 2015
Beginning balance(1)	$	45.9	$	—	$	45.9
DCGT Acquisition	249.6		—		249.6
Ending balance(1)	$	295.5	$	—	$	295.5

(1) There are no accumulated impairment losses.

Schedule of Components of Intangible Assets

The components of intangible assets are as follows:

	June 30, 2015				December 31, 2014
	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
(millions)
Software and other	$	30.8	$	22.3	$	6.5	$	2.4
Licenses	11.0		3.2		11.0		3.0
Total	$	41.8	$	25.5	$	17.5	$	5.4

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Regulatory Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2015

Regulated Operations [Abstract]

Schedule of Regulatory Assets

Regulatory assets and liabilities include the following:

	June 30, 2015		December 31, 2014
(millions)
Regulatory assets:
Unrecovered gas costs(1)	$	2.2	$	1.5
Other	0.4		0.2
Regulatory assets-current	2.6		1.7
Income taxes recoverable through future rates(2)	2.6		2.5
Regulatory assets-non-current	2.6		2.5
Total regulatory assets	$	5.2	$	4.2
Regulatory liabilities:
Overrecovered gas costs(1)	$	—	$	0.5
LNG cargo obligations(3)	3.6		3.0
Customer bankruptcy settlement(4)	2.9		—
Other	0.7		0.1
Regulatory liabilities-current	7.2		3.6
Provision for future cost of removal(5)	47.7		33.0
Customer bankruptcy settlement(4)	21.9		—
Other	1.4		0.5
Regulatory liabilities-non-current	71.0		33.5
Total regulatory liabilities	$	78.2	$	37.1

(1) Reflects unrecovered/overrecovered gas costs, which are subject to annual filings with the FERC.

(2) Amounts to be recovered through future rates to pay income taxes that become payable by unitholders when rate revenue is provided to recover AFUDC-equity when such amounts are recovered through book depreciation.

(3) Reflects obligations to the Import Shippers for LNG cargo received. See Note 9 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014 for further information.

(4) Represents the balance of proceeds from the monetization of a bankruptcy claim acquired as part of the DCGT Acquisition, which is being amortized into operating revenue through February 2024.

(5) Rates charged to customers include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.

Schedule of Regulatory Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2015		December 31, 2014
(millions)
Regulatory assets:
Unrecovered gas costs(1)	$	2.2	$	1.5
Other	0.4		0.2
Regulatory assets-current	2.6		1.7
Income taxes recoverable through future rates(2)	2.6		2.5
Regulatory assets-non-current	2.6		2.5
Total regulatory assets	$	5.2	$	4.2
Regulatory liabilities:
Overrecovered gas costs(1)	$	—	$	0.5
LNG cargo obligations(3)	3.6		3.0
Customer bankruptcy settlement(4)	2.9		—
Other	0.7		0.1
Regulatory liabilities-current	7.2		3.6
Provision for future cost of removal(5)	47.7		33.0
Customer bankruptcy settlement(4)	21.9		—
Other	1.4		0.5
Regulatory liabilities-non-current	71.0		33.5
Total regulatory liabilities	$	78.2	$	37.1

(1) Reflects unrecovered/overrecovered gas costs, which are subject to annual filings with the FERC.

(2) Amounts to be recovered through future rates to pay income taxes that become payable by unitholders when rate revenue is provided to recover AFUDC-equity when such amounts are recovered through book depreciation.

(3) Reflects obligations to the Import Shippers for LNG cargo received. See Note 9 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014 for further information.

(4) Represents the balance of proceeds from the monetization of a bankruptcy claim acquired as part of the DCGT Acquisition, which is being amortized into operating revenue through February 2024.

(5) Rates charged to customers include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.

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Acquisition

6 Months Ended

Jun. 30, 2015

Business Combinations [Abstract]

Acquisition

Acquisition

DCGT

On April 1, 2015, Dominion Midstream entered into a Purchase, Sale and Contribution Agreement with Dominion pursuant to which Dominion Midstream purchased from Dominion all of the issued and outstanding membership interests of DCGT in exchange for total consideration of approximately $500.8 million, as adjusted for working capital. Total consideration to Dominion consisted of the issuance of a two-year $300.8 million senior unsecured promissory note, as adjusted for working capital, payable to Dominion at an annual interest rate of 0.6%, and 5,112,139 common units, valued at $200.0 million, representing limited partner interests in Dominion Midstream, to Dominion. The number of units was based on the volume weighted average trading price of Dominion Midstream's common units for the 10 trading days prior to April 1, 2015, or $39.12 per unit. Total transaction and transition costs of $1.0 million associated with the DCGT Acquisition were expensed as incurred to operations and maintenance expense in the Consolidated Income Statement for the three months ended June 30, 2015. These costs were paid by Dominion. Dominion did not seek reimbursement for $0.7 million of such costs incurred during the three months ended June 30, 2015, and accordingly Dominion Midstream recognized a capital contribution by the general partner. The DCGT Acquisition supports the expansion of Dominion Midstream's portfolio of natural gas terminaling, processing, storage, transportation and related assets.

The contribution of DCGT by Dominion to Dominion Midstream is considered to be a reorganization of entities under common control. Accordingly, Dominion Midstream's net investment in DCGT is recorded at Dominion's historical cost of $501.6 million as of April 1, 2015. Common control began on January 31, 2015, concurrent with Dominion's acquisition of DCGT from SCANA, which was accounted for using the acquisition method of accounting. Accordingly, the Consolidated Financial Statements of Dominion Midstream reflect DCGT's financial results beginning January 31, 2015.

In connection with the DCGT Acquisition, Dominion Midstream entered into a registration rights agreement with Dominion pursuant to which Dominion Midstream must register the 5,112,139 common units issued to Dominion at its request, subject to certain terms and conditions. Additionally, at the time of Dominion's acquisition of DCGT, DCGT entered into services agreements and an intercompany tax sharing agreement with Dominion as described in Note 15.

The assets and liabilities of DCGT are included in the Consolidated Balance Sheet as of June 30, 2015. The results of operations of DCGT are included in the Consolidated Statement of Income for the three months ended June 30, 2015. The following table presents Dominion Midstream's Consolidated Statement of Income for the six months ended June 30, 2015 giving effect to the DCGT Acquisition. The results of DCGT from January 31, 2015 through March 31, 2015 are included in "DCGT Predecessor." The results of DCGT beginning on April 1, 2015 are included in "Dominion Midstream."

	Six Months Ended June 30, 2015
	Dominion Midstream		DCGT Predecessor		Dominion Midstream (as reported)
(in millions)
Operating Revenue	$	172.6	$	11.2	$	183.8
Operating Expenses
Purchased gas	29.4		—		29.4
Other operations and maintenance:
Affiliated suppliers	8.7		2.5		11.2
Other	15.8		2.3		18.1
Depreciation and amortization	19.2		1.3		20.5
Other taxes	11.9		0.8		12.7
Total operating expenses	85.0		6.9		91.9
Income from operations	87.6		4.3		91.9
Other income	0.3		0.1		0.4
Interest and related charges	0.2		—		0.2
Income from operations including noncontrolling interest before income taxes	87.7		4.4		92.1
Income tax expense	—		2.1		2.1
Net income including noncontrolling interest and DCGT Predecessor	87.7		2.3		90.0
Less: Net income attributable to DCGT Predecessor	—		2.3		2.3
Net income including noncontrolling interest	87.7		—		87.7
Less: Net income attributable to noncontrolling interest	58.3		—		58.3
Net income attributable to partners	$	29.4	$	—	$	29.4

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Asset Retirement Obligations (Tables)

6 Months Ended

Jun. 30, 2015

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Change in Asset Retirement Obligation

The changes to AROs during 2014 and 2015 were as follows:

	Six Months Ended			Year Ended
	June 30, 2015			December 31, 2014
(millions)
Beginning balance(1)	$	0.4		$	0.4
DCGT Acquisition	12.6			—
Obligations settled during the period	(0.3		)	—
Accretion	0.3			—
Ending balance(1)	$	13.0		$	0.4

(1) Includes $0.1 million and $0.3 million reported in other current liabilities at December 31, 2014, and June 30, 2015, respectively.

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Unit Activity (Details)	6 Months Ended
	Jun. 30, 2015 shares
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2014	63,947,900
Unit-based compensation	5,055
Units issued in connection with the DCGT Acquisition	5,112,139
Balance at June 30, 2015	69,065,094
General Partner Dominion (non-economic interest) | General Partner Dominion (non-economic interest) | Dominion
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2014	0
Unit-based compensation	0
Units issued in connection with the DCGT Acquisition	0
Balance at June 30, 2015	0
Common Units | Common Unitholders and Subordinated Unitholder | Limited Partners
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2014	20,127,322
Unit-based compensation	5,055
Units issued in connection with the DCGT Acquisition	0
Balance at June 30, 2015	20,132,377
Common Units | Common Unitholders and Subordinated Unitholder | Limited Partners | Dominion
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2014	11,847,789
Unit-based compensation	0
Units issued in connection with the DCGT Acquisition	5,112,139
Balance at June 30, 2015	16,959,928
Subordinated Units | Common Unitholders and Subordinated Unitholder | Limited Partners | Dominion
Increase (Decrease) in Partners' Capital [Roll Forward]
Balance at December 31, 2014	31,972,789
Unit-based compensation	0
Units issued in connection with the DCGT Acquisition	0
Balance at June 30, 2015	31,972,789

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Credit Risk (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015 USD ($) customer	Jun. 30, 2014 customer	Jun. 30, 2015 USD ($) customer	Jun. 30, 2014 customer
Customer Concentration Risk | Sales Revenue, Net
Concentration Risk [Line Items]
Number of customers			70
Customer Concentration Risk | Sales Revenue, Net | Two Largest Customers
Concentration Risk [Line Items]
Number of customers	2		2
Percentage of total transportation and storage revenues	71.00%		71.00%
Customer Concentration Risk | Sales Revenue, Net | Largest Customer
Concentration Risk [Line Items]
Percentage of total transportation and storage revenues	56.00%		57.00%
Credit Concentration Risk | Accounts Receivable
Concentration Risk [Line Items]
Provision for credit losses (less than $0.1 million) | $	$ 0.1		$ 0.1
Predecessor | Customer Concentration Risk | Sales Revenue, Net | Largest Customer
Concentration Risk [Line Items]
Percentage of total transportation and storage revenues		68.00%		68.00%
Predecessor | Customer Concentration Risk | Sales Revenue, Net | Three Largest Customers
Concentration Risk [Line Items]
Number of customers		3		3
Percentage of total transportation and storage revenues		87.00%		87.00%

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Consolidated Statements of Income - USD ($) $ in Millions		3 Months Ended	6 Months Ended
		Jun. 30, 2015	Jun. 30, 2015
Operating revenue	[1]	$ 105.4	$ 183.8
Operating Expenses
Purchased gas	[1]	25.5	29.4
Other operations and maintenance:
Affiliated suppliers		6.4	11.2
Other		9.6	18.1
Depreciation and amortization		9.9	20.5
Other taxes		6.8	12.7
Total operating expenses		58.2	91.9
Income from operations		47.2	91.9
Other income		0.2	0.4
Interest and related charges	[1]	0.2	0.2
Income from operations including noncontrolling interest before income taxes		47.2	92.1
Income tax expense		0.0	2.1
Net income including noncontrolling interest and DCGT Predecessor		47.2	90.0
Less: Net income attributable to DCGT Predecessor		0.0	2.3
Net income including noncontrolling interest		47.2	87.7
Less: Net income attributable to noncontrolling interest		29.6	58.3
Net income attributable to partners		17.6	29.4
Net income attributable to partners' ownership interest
General partner's interest in net income	[2]	(0.7)	(0.7)
Common Units
Net income attributable to partners' ownership interest
Net income attributable to limited partners		$ 10.3	$ 16.2
Net income per limited partner unit (basic and diluted)
Net income per limited partner unit (basic and diluted)		$ 0.26	$ 0.47
Subordinated Units
Net income attributable to partners' ownership interest
Net income attributable to limited partners		$ 8.0	$ 13.9
Net income per limited partner unit (basic and diluted)
Net income per limited partner unit (basic and diluted)		$ 0.26	$ 0.44

[1] See Note 15 for amounts attributable to related parties.

[2] See Note 2 for further information.

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Goodwill and Intangible Assets (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Finite-Lived Intangible Assets [Line Items]
Amortization expense	$ 0.6		$ 0.9
DCGT | Computer Software, Intangible Asset
Finite-Lived Intangible Assets [Line Items]
Weighted average amortization period			5 years
Predecessor
Finite-Lived Intangible Assets [Line Items]
Amortization expense		$ 0.1		$ 0.3

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Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Operating Activities
Net income including noncontrolling interest and DCGT Predecessor	$ 90.0
Adjustments to reconcile net income including noncontrolling interest to net cash provided by operating activities:
Depreciation and amortization	20.5
Deferred income taxes	1.5
Other adjustments to income, net	1.9
Changes in:
Customer and other receivables	(2.1)
Affiliated receivables	0.0
Prepayments	8.6
Accounts payable	(3.5)
Payables to affiliates	3.0
Accrued payroll and taxes	1.4
Other operating assets and liabilities	3.4
Net cash provided by operating activities	124.7
Investing Activities
Plant construction and other property additions	(479.0)
Other	(1.6)
Net cash used in investing activities	(480.6)
Financing Activities
Dominion credit facility borrowings	5.9
Contributions from Dominion	273.1
Other	(0.2)
Net cash provided by financing activities	257.8
Decrease in cash and cash equivalents	(98.1)
Cash and cash equivalents at beginning of period	175.4
Cash and cash equivalents at end of period	77.3
Supplemental Cash Flow Information
Income taxes	0.0
Significant noncash investing and financing activities:
Accrued capital expenditures	123.1
DCGT Acquisition through issuance of debt and equity
Significant noncash investing and financing activities:
DCGT Acquisition through issuance of debt and equity and Settlement of net current and deferred income tax assets	500.8
Settlement of net current and deferred income tax assets
Significant noncash investing and financing activities:
DCGT Acquisition through issuance of debt and equity and Settlement of net current and deferred income tax assets	13.4
Equity contribution from Dominion to relieve payables to affiliates
Significant noncash investing and financing activities:
Equity contribution from Dominion to relieve payables to affiliates	1.7
Common Units
Financing Activities
Distributions to unitholders	(6.3)
Dominion | Common Units
Financing Activities
Distributions to unitholders	(4.6)
Dominion | Subordinated Units
Financing Activities
Distributions to unitholders	$ (10.1)
Predecessor
Operating Activities
Net income including noncontrolling interest and DCGT Predecessor		$ 48.8
Adjustments to reconcile net income including noncontrolling interest to net cash provided by operating activities:
Depreciation and amortization		15.7
Deferred income taxes		10.4
Other adjustments to income, net		0.0
Changes in:
Customer and other receivables		(26.5)
Affiliated receivables		(1.6)
Prepayments		(1.1)
Accounts payable		22.8
Payables to affiliates		1.5
Accrued payroll and taxes		(1.0)
Other operating assets and liabilities		(2.8)
Net cash provided by operating activities		66.2
Investing Activities
Plant construction and other property additions		(222.3)
Other		(0.3)
Net cash used in investing activities		(222.6)
Financing Activities
Dominion credit facility borrowings		0.0
Contributions from Dominion		145.2
Other		0.0
Net cash provided by financing activities		145.2
Decrease in cash and cash equivalents		(11.2)
Cash and cash equivalents at beginning of period		11.2
Cash and cash equivalents at end of period		0.0
Supplemental Cash Flow Information
Income taxes		30.7
Significant noncash investing and financing activities:
Accrued capital expenditures		7.3
Predecessor | DCGT Acquisition through issuance of debt and equity
Significant noncash investing and financing activities:
DCGT Acquisition through issuance of debt and equity and Settlement of net current and deferred income tax assets		0.0
Predecessor | Settlement of net current and deferred income tax assets
Significant noncash investing and financing activities:
DCGT Acquisition through issuance of debt and equity and Settlement of net current and deferred income tax assets		0.0
Predecessor | Equity contribution from Dominion to relieve payables to affiliates
Significant noncash investing and financing activities:
Equity contribution from Dominion to relieve payables to affiliates		20.0
Predecessor | Common Units
Financing Activities
Distributions to unitholders		0.0
Predecessor | Dominion | Common Units
Financing Activities
Distributions to unitholders		$ 0.0
Predecessor | Dominion | Subordinated Units
Financing Activities
Distributions to unitholders

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Operating Segment (Tables)

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

The following table presents segment information pertaining to Dominion Midstream's operations:

	Dominion Energy		Corporate and Other			Total
(millions)
Three Months Ended June 30, 2015
Operating revenue	$	105.4	$	—		$	105.4
Net income including noncontrolling interest and DCGT Predecessor	47.9		(0.7		)	47.2
Net income attributable to partners	18.3		(0.7		)	17.6
Three Months Ended June 30, 2014
Operating revenue	$	111.2	$	—		$	111.2
Net income including noncontrolling interest and DCGT Predecessor	24.2		—			24.2
Six Months Ended June 30, 2015
Operating revenue	$	183.8	$	—		$	183.8
Net income including noncontrolling interest and DCGT Predecessor	91.7		(1.7		)	90.0
Net income including noncontrolling interest	88.4		(0.7		)	87.7
Net income attributable to partners	30.1		(0.7		)	29.4
Six Months Ended June 30, 2014
Operating revenue	$	180.1	$	—		$	180.1
Net income including noncontrolling interest and DCGT Predecessor	48.8		—			48.8

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Income Taxes

6 Months Ended

Jun. 30, 2015

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

Dominion Midstream is organized as an MLP, a pass-through entity for U.S. federal and state income tax purposes. Each unitholder is responsible for taking into account the unitholder’s respective share of Dominion Midstream’s items of taxable income, gain, loss and deduction in the preparation of income tax returns. Upon the closing of the Offering, Cove Point became a pass-through entity for U.S. federal and state income tax purposes. Effective April 1, 2015, the date of the DCGT Acquisition, DCGT is treated as a component of Dominion Midstream for income tax purposes. Accordingly, for the quarter ended June 30, 2015, Dominion Midstream's Consolidated Financial Statements do not include income taxes.

Prior to the completion of the Offering, Cove Point was not treated as a partnership for U.S. federal and state income tax purposes. Its business activities were included in the consolidated U.S. federal and certain state income tax returns of Dominion or DCPI. DCGT operated as a taxable corporation at the time of Dominion's acquisition of DCGT. In March 2015, DCGT converted to a single member limited liability company and as a result, became a disregarded entity for income tax purposes and was treated as a taxable division of its corporate parent. Its business activities from January 31, 2015 through March 31, 2015, will be included in the consolidated U.S. federal and certain state income tax returns of Dominion. Cove Point and DCGT's current income taxes were based on taxable income or loss, determined on a separate company basis, and, where applicable, settled in accordance with the principles of Dominion’s intercompany tax sharing agreement. The settlement of DCGT’s federal and state income taxes payable and net deferred income taxes is reflected as an equity transaction in Dominion Midstream’s Consolidated Financial Statements.

For the six months ended June 30, 2015 and 2014, the statutory U.S. federal income tax rate reconciles to the effective income tax rate as follows:

Six Months Ended June 30,	2015		2014
U.S. statutory rate	35.0	%	35.0	%
Partnership income not subject to income taxes(1)	(32.9	)	—
Increases resulting from:
State taxes, net of federal benefit(2)	0.2		3.2
Effective tax rate	2.3	%	38.2	%

(1) Reflects the pass-through entity status of Dominion Midstream, including the operations of DCGT subsequent to the DCGT Acquisition, and Cove Point.

(2) 2015 amounts are attributable to the operations of DCGT prior to the DCGT Acquisition, and 2014 amounts are attributable to Cove Point.

See Note 15 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014 for additional information.

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Description of Business and Basis of Presentation (Details)	Apr. 01, 2015 mi	Oct. 20, 2014 shares
DCGT | Affiliates | Dominion
Subsidiary, Sale of Stock [Line Items]
Length of FERC regulated interstate natural gas pipeline | mi	1,500
Common Units | IPO
Subsidiary, Sale of Stock [Line Items]
Number of units issued		20,125,000
Common Units | Over-Allotment Option
Subsidiary, Sale of Stock [Line Items]
Number of units issued		2,625,000

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Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2015

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The contribution by Dominion to Dominion Midstream of the general partner interest in Cove Point and a portion of the Preferred Equity Interest is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis is equal to Dominion’s cost basis in the general partner interest in Cove Point and a portion of the Preferred Equity Interest. Dominion Midstream owns the general partner interest and controls Cove Point and therefore consolidates Cove Point. As such, Dominion Midstream’s investment in the Preferred Equity Interest and Cove Point's preferred equity interest are eliminated in consolidation. Dominion's retained common equity interest in Cove Point is reflected as noncontrolling interest.

The DCGT Acquisition is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis in DCGT is equal to Dominion’s cost basis in the assets and liabilities of DCGT. On April 1, 2015, DCGT became a wholly-owned subsidiary of Dominion Midstream and is therefore consolidated by Dominion Midstream. The accompanying financial statements and related notes have been retrospectively adjusted to include the historical results and financial position of DCGT beginning January 31, 2015, the inception date of common control.

For the period prior to the closing of the Offering on October 20, 2014, the financial statements included in this Quarterly Report on Form 10-Q were derived from the financial statements and accounting records of Cove Point, as our predecessor for accounting purposes. The financial statements were prepared using Dominion's historical basis in the assets and liabilities of Cove Point and include all revenues, costs, assets and liabilities attributed to Cove Point. For the period subsequent to the closing of the Offering, the Consolidated Financial Statements represent the consolidated results of operations, financial position and cash flows of Dominion Midstream.

The financial statements for all periods presented include costs for certain general, administrative and corporate expenses assigned by DRS or Dominion Payroll to Dominion Midstream and Cove Point on the basis of direct and allocated methods in accordance with Dominion Midstream's services agreements with DRS and Dominion Payroll and Cove Point's services agreement with DRS. Where costs incurred cannot be determined by specific identification, the costs are allocated based on the proportional level of effort devoted by DRS or Dominion Payroll resources that is attributable to the entities, determined by reference to number of employees, salaries and wages and other similar measures for the relevant DRS or Dominion Payroll department. Management believes the assumptions and methodologies underlying the allocation of general corporate overhead expenses are reasonable. Nevertheless, the Consolidated Financial Statements prior to the Offering may not include all of the actual expenses that would have been incurred had we been a stand-alone publicly traded partnership during the periods presented, and may not reflect our actual results of operations, financial position and cash flows had we been a stand-alone publicly traded partnership during the periods prior to the Offering.

Basis of Accounting

As permitted by the rules and regulations of the SEC, Dominion Midstream's accompanying unaudited Consolidated Financial Statements exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in Dominion Midstream’s Annual Report on Form 10-K for the year ended December 31, 2014.

Estimates

Dominion Midstream makes certain estimates and assumptions in preparing its Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses for the periods presented. Actual results may differ from those estimates.

Asset Retirement Obligations

Asset Retirement Obligations

Dominion Midstream recognizes AROs at fair value as incurred or when sufficient information becomes available to determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, Dominion Midstream evaluates the key assumptions underlying its AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion Midstream reports accretion of AROs and depreciation on asset retirement costs associated with its natural gas pipeline assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs.

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Description of Business and Basis of Presentation

6 Months Ended

Jun. 30, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Description of Business and Basis of Presentation

Description of Business and Basis of Presentation

Description of Business

Dominion Midstream is a Delaware limited partnership formed on March 11, 2014 by Dominion MLP Holding Company, LLC and Dominion Midstream GP, LLC, both indirect wholly-owned subsidiaries of Dominion, to grow a portfolio of natural gas terminaling, processing, storage, transportation and related assets. On October 20, 2014, Dominion Midstream completed the Offering of 20,125,000 common units (including 2,625,000 common units issued pursuant to the exercise of the underwriters' over-allotment option) representing limited partner interests. A registration statement on Form S-1, as amended through the time of its effectiveness, was filed by Dominion Midstream with the SEC and was declared effective on October 10, 2014.

Dominion Midstream acquired from Dominion the Preferred Equity Interest and non-economic general partner interest in Cove Point, the owner and operator of the Cove Point LNG Facility and the Cove Point Pipeline. The Preferred Equity Interest is a perpetual, non-convertible preferred equity interest entitled to Preferred Return Distributions so long as Cove Point has sufficient cash and undistributed Net Operating Income (determined on a cumulative basis from the closing of the Offering) from which to make Preferred Return Distributions. Preferred Return Distributions are made on a quarterly basis and are not cumulative. The Preferred Equity Interest is also entitled to the Additional Return Distributions.

On April 1, 2015, Dominion Midstream acquired from Dominion all issued and outstanding membership interests in DCGT as described further in Note 2. DCGT owns and operates nearly 1,500 miles of FERC-regulated open access, transportation-only interstate natural gas pipeline in South Carolina and southeastern Georgia.

Basis of Presentation

The contribution by Dominion to Dominion Midstream of the general partner interest in Cove Point and a portion of the Preferred Equity Interest is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis is equal to Dominion’s cost basis in the general partner interest in Cove Point and a portion of the Preferred Equity Interest. Dominion Midstream owns the general partner interest and controls Cove Point and therefore consolidates Cove Point. As such, Dominion Midstream’s investment in the Preferred Equity Interest and Cove Point's preferred equity interest are eliminated in consolidation. Dominion's retained common equity interest in Cove Point is reflected as noncontrolling interest.

The DCGT Acquisition is considered to be a reorganization of entities under common control. As a result, Dominion Midstream’s basis in DCGT is equal to Dominion’s cost basis in the assets and liabilities of DCGT. On April 1, 2015, DCGT became a wholly-owned subsidiary of Dominion Midstream and is therefore consolidated by Dominion Midstream. The accompanying financial statements and related notes have been retrospectively adjusted to include the historical results and financial position of DCGT beginning January 31, 2015, the inception date of common control.

For the period prior to the closing of the Offering on October 20, 2014, the financial statements included in this Quarterly Report on Form 10-Q were derived from the financial statements and accounting records of Cove Point, as our predecessor for accounting purposes. The financial statements were prepared using Dominion's historical basis in the assets and liabilities of Cove Point and include all revenues, costs, assets and liabilities attributed to Cove Point. For the period subsequent to the closing of the Offering, the Consolidated Financial Statements represent the consolidated results of operations, financial position and cash flows of Dominion Midstream.

The financial statements for all periods presented include costs for certain general, administrative and corporate expenses assigned by DRS or Dominion Payroll to Dominion Midstream and Cove Point on the basis of direct and allocated methods in accordance with Dominion Midstream's services agreements with DRS and Dominion Payroll and Cove Point's services agreement with DRS. Where costs incurred cannot be determined by specific identification, the costs are allocated based on the proportional level of effort devoted by DRS or Dominion Payroll resources that is attributable to the entities, determined by reference to number of employees, salaries and wages and other similar measures for the relevant DRS or Dominion Payroll department. Management believes the assumptions and methodologies underlying the allocation of general corporate overhead expenses are reasonable. Nevertheless, the Consolidated Financial Statements prior to the Offering may not include all of the actual expenses that would have been incurred had we been a stand-alone publicly traded partnership during the periods presented, and may not reflect our actual results of operations, financial position and cash flows had we been a stand-alone publicly traded partnership during the periods prior to the Offering.

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Consolidated Balance Sheets - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014
Current Assets
Cash and cash equivalents		$ 77.3	$ 175.4
Customer and other receivables		28.7	19.9
Affiliated receivables		6.1	6.1
Prepayments		1.0	9.5
Materials and supplies		11.3	8.7
Regulatory assets		2.6	1.7
Other		5.2	4.7
Total current assets		132.2	226.0
Property, Plant and Equipment
Property, plant and equipment		3,152.8	2,203.1
Accumulated depreciation and amortization		(335.1)	(231.2)
Total property, plant and equipment, net		2,817.7	1,971.9
Deferred Charges and Other Assets
Goodwill	[1]	295.5	45.9
Intangible assets, net		16.3	12.1
Regulatory assets		2.6	2.5
Other		0.1	0.0
Total deferred charges and other assets		314.5	60.5
Total assets		3,264.4	2,258.4
Current Liabilities
Accounts payable		109.7	3.3
Payables to affiliates		5.3	2.5
Accrued payroll and taxes		3.6	1.5
Regulatory liabilities		7.2	3.6
Dominion credit facility borrowings		5.9	0.0
Deferred revenue		0.3	3.9
Natural gas imbalances	[2]	3.5	2.7
CPCN obligation		7.9	7.9
Other		22.7	6.4
Total current liabilities		166.1	31.8
Affiliated Long-Term Debt		300.8	0.0
Deferred Credits and Other Liabilities
Pension and other postretirement benefit liabilities	[2]	4.7	4.4
Regulatory liabilities		71.0	33.5
CPCN obligation		28.9	36.2
Asset retirement obligation		12.7	0.3
Other		2.7	1.4
Total deferred credits and other liabilities		120.0	75.8
Total liabilities		$ 586.9	$ 107.6
Commitments and Contingencies (see Note 13)
Equity and Partners' Capital
Total Dominion Midstream Partners, LP partners' capital		$ 1,271.9	$ 1,075.3
Noncontrolling interest		1,405.6	1,075.5
Total equity and partners' capital		2,677.5	2,150.8
Total liabilities and equity and partners' capital		3,264.4	2,258.4
Common Units
Equity and Partners' Capital
Common unitholders and Subordinated unitholder		398.0	395.4
Dominion
Equity and Partners' Capital
General Partner interest - Dominion (non-economic interest)		(12.6)	0.0
Dominion | Common Units
Equity and Partners' Capital
Common unitholders and Subordinated unitholder		416.5	213.7
Dominion | Subordinated Units
Equity and Partners' Capital
Common unitholders and Subordinated unitholder		$ 470.0	$ 466.2

[1] There are no accumulated impairment losses.

[2] See Note 15 for amounts attributable to related parties.

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Asset Retirement Obligations

6 Months Ended

Jun. 30, 2015

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

AROs represent obligations that result from laws, statutes, contracts and regulations related to the eventual retirement of certain of Dominion Midstream's long-lived assets. Dominion Midstream's AROs primarily represent the cost associated with the legal obligation to cap and purge underground transmission pipe and the interim retirement of natural gas transmission pipeline components.

The changes to AROs during 2014 and 2015 were as follows:

	Six Months Ended			Year Ended
	June 30, 2015			December 31, 2014
(millions)
Beginning balance(1)	$	0.4		$	0.4
DCGT Acquisition	12.6			—
Obligations settled during the period	(0.3		)	—
Accretion	0.3			—
Ending balance(1)	$	13.0		$	0.4

(1) Includes $0.1 million and $0.3 million reported in other current liabilities at December 31, 2014, and June 30, 2015, respectively.

Under the terms of the 2005 Agreement, Cove Point would be responsible for certain onshore and offshore site restoration activities at the Cove Point site only if it voluntarily tenders title according to the terms of this agreement. As Cove Point is permitted to operate the Cove Point LNG Facility for an indefinite time period and currently has no plans to voluntarily tender title, Cove Point does not have sufficient information to determine a reasonable range of settlement dates for decommissioning and therefore has not recorded an asset retirement obligation.

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Document and Entity Information - Jun. 30, 2015 - shares	Total
Document and Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Trading Symbol	DM
Entity Registrant Name	Dominion Midstream Partners, LP
Entity Central Index Key	0001603286
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Units Outstanding
Document and Entity Information [Line Items]
Entity Units Outstanding	37,092,305
Entity Subordinated Units Outstanding
Document and Entity Information [Line Items]
Entity Units Outstanding	31,972,789

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Affiliated Long-Term Debt

6 Months Ended

Jun. 30, 2015

Debt Disclosure [Abstract]

Affiliated Long-Term Debt

Affiliated Long-Term Debt

In connection with the DCGT Acquisition, Dominion Midstream issued a two-year, $300.8 million senior unsecured promissory note payable to Dominion, as adjusted for working capital, at an annual fixed interest rate of 0.6%. Interest on the note is payable quarterly, and all principal and accrued interest is due and payable at maturity on April 1, 2017, which under certain conditions can be extended at the option of Dominion Midstream to October 1, 2017. Interest charges related to Dominion Midstream's borrowing from Dominion were $0.5 million for the three and six months ended June 30, 2015. At June 30, 2015, accrued interest payable to Dominion of $0.5 million was recorded in payables to affiliates on the Consolidated Balance Sheet.

The debt instrument described above is reported at historical cost. At June 30, 2015, the fair value of Dominion Midstream's outstanding debt was $289.6 million. The estimated fair value has been determined using available market information and valuation methodologies considered appropriate by management. The fair value was calculated using market interest rates currently available for issuance of debt with similar terms and remaining maturities. The fair value measurement is classified as Level 2.

The key terms of the note payable to Dominion include a prohibition on the incurrence of additional indebtedness (other than under the credit facility with Dominion discussed in Note 15) and a negative pledge applicable to liens on the assets of Dominion Midstream, but which does not apply to the assets of subsidiaries of Dominion Midstream.   The note payable does not include any financial covenants.  If Dominion Midstream fails to make payments under the note payable or becomes subject to bankruptcy or other insolvency proceedings, Dominion may accelerate Dominion Midstream’s payment obligations under the note payable.

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Consolidated Balance Sheets (Parenthetical) - shares	Jun. 30, 2015	Dec. 31, 2014
Common Units
Common unitholders and Subordinated unitholder - units issued	20,132,377	20,127,322
Common unitholders and Subordinated unitholder- units outstanding	20,132,377	20,127,322
Common Units | Dominion
Common unitholders and Subordinated unitholder - units issued	16,959,928	11,847,789
Common unitholders and Subordinated unitholder- units outstanding	16,959,928	11,847,789
Subordinated Units | Dominion
Common unitholders and Subordinated unitholder - units issued	31,972,789	31,972,789
Common unitholders and Subordinated unitholder- units outstanding	31,972,789	31,972,789

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Operating Revenue

6 Months Ended

Jun. 30, 2015

Revenue Recognition [Abstract]

Operating Revenue

Operating Revenue

Dominion Midstream's operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(millions)
Gas transportation and storage	$	78.9	$	64.9	$	153.6	$	130.5
Other	26.5		46.3		30.2		49.6
Total operating revenue	$	105.4	$	111.2	$	183.8	$	180.1

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Unit Activity Unit Activity

6 Months Ended

Jun. 30, 2015

Equity [Abstract]

Unit Activity

Unit Activity

Activity in the number of units was as follows:

	Common
	Public	Dominion	Subordinated	General Partner	Total
				(non-economic interest)
Balance at December 31, 2014	20,127,322	11,847,789	31,972,789	—	63,947,900
Unit-based compensation	5,055	—	—	—	5,055
Units issued in connection with the DCGT Acquisition	—	5,112,139	—	—	5,112,139
Balance at June 30, 2015	20,132,377	16,959,928	31,972,789	—	69,065,094

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Operating Segment

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

Operating Segment

Operating Segment

Dominion Midstream is organized primarily on the basis of products and services sold in the U.S. Dominion Energy, Dominion Midstream's operating segment, consists of natural gas transportation, storage and regasification services.

Dominion Midstream also reports a Corporate and Other segment. The Corporate and Other segment primarily includes specific items attributable to Dominion Midstream's operating segment that are not included in profit measures evaluated by executive management in assessing the segment's performance.

The following table presents segment information pertaining to Dominion Midstream's operations:

	Dominion Energy		Corporate and Other			Total
(millions)
Three Months Ended June 30, 2015
Operating revenue	$	105.4	$	—		$	105.4
Net income including noncontrolling interest and DCGT Predecessor	47.9		(0.7		)	47.2
Net income attributable to partners	18.3		(0.7		)	17.6
Three Months Ended June 30, 2014
Operating revenue	$	111.2	$	—		$	111.2
Net income including noncontrolling interest and DCGT Predecessor	24.2		—			24.2
Six Months Ended June 30, 2015
Operating revenue	$	183.8	$	—		$	183.8
Net income including noncontrolling interest and DCGT Predecessor	91.7		(1.7		)	90.0
Net income including noncontrolling interest	88.4		(0.7		)	87.7
Net income attributable to partners	30.1		(0.7		)	29.4
Six Months Ended June 30, 2014
Operating revenue	$	180.1	$	—		$	180.1
Net income including noncontrolling interest and DCGT Predecessor	48.8		—			48.8

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

As a result of issues generated in the ordinary course of business, Dominion Midstream is involved in legal proceedings before various courts and is periodically subject to governmental examinations (including by the FERC), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for Dominion Midstream to estimate a range of possible loss. For such matters that Dominion Midstream cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that Dominion Midstream is able to estimate a range of possible loss. For legal proceedings and governmental examinations for which Dominion Midstream is able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Any estimated range of possible loss may not represent Dominion Midstream’s maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. Management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on Dominion Midstream’s financial position, liquidity or results of operations.

Cove Point Natural Heritage Trust

Under the terms of the 2005 Agreement, Cove Point is required to make an annual contribution to the Cove Point Natural Heritage Trust, an affiliated non-profit trust focused on the preservation and protection of ecologically sensitive sites at or near Cove Point, of $0.3 million for each year the facility is in operation. These annual payments are recorded in other operations and maintenance expense in the Consolidated Statements of Income. If Cove Point voluntarily tenders title according to the terms of this agreement, no contributions are required. There are no current plans to voluntarily tender title to the Cove Point site.

Surety Bonds

At June 30, 2015, Cove Point had purchased $10.8 million of surety bonds. Under the terms of surety bonds, Cove Point is obligated to indemnify the respective surety bond company for any amounts paid.

Lease Commitments

Dominion Midstream leases various facilities, vehicles and equipment under operating lease arrangements, the majority of which include terms of one year or less, require payments on a monthly or annual basis, and can be canceled at any time. Rental expense for Dominion Midstream totaled $0.7 million and $1.4 million for the three and six month periods ended June 30, 2015, respectively. The majority of rent expense is included within other operations and maintenance expense in the Consolidated Statements of Income.

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Regulatory Assets and Liabilities

6 Months Ended

Jun. 30, 2015

Regulated Operations [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2015		December 31, 2014
(millions)
Regulatory assets:
Unrecovered gas costs(1)	$	2.2	$	1.5
Other	0.4		0.2
Regulatory assets-current	2.6		1.7
Income taxes recoverable through future rates(2)	2.6		2.5
Regulatory assets-non-current	2.6		2.5
Total regulatory assets	$	5.2	$	4.2
Regulatory liabilities:
Overrecovered gas costs(1)	$	—	$	0.5
LNG cargo obligations(3)	3.6		3.0
Customer bankruptcy settlement(4)	2.9		—
Other	0.7		0.1
Regulatory liabilities-current	7.2		3.6
Provision for future cost of removal(5)	47.7		33.0
Customer bankruptcy settlement(4)	21.9		—
Other	1.4		0.5
Regulatory liabilities-non-current	71.0		33.5
Total regulatory liabilities	$	78.2	$	37.1

(1) Reflects unrecovered/overrecovered gas costs, which are subject to annual filings with the FERC.

(2) Amounts to be recovered through future rates to pay income taxes that become payable by unitholders when rate revenue is provided to recover AFUDC-equity when such amounts are recovered through book depreciation.

(3) Reflects obligations to the Import Shippers for LNG cargo received. See Note 9 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014 for further information.

(4) Represents the balance of proceeds from the monetization of a bankruptcy claim acquired as part of the DCGT Acquisition, which is being amortized into operating revenue through February 2024.

(5) Rates charged to customers include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.

At June 30, 2015, approximately $2.6 million of regulatory assets represented past expenditures on which Dominion Midstream does not currently earn a return. These expenditures are expected to be recovered within one year.

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Property Plant and Equipment

6 Months Ended

Jun. 30, 2015

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Property, Plant and Equipment

Major classes of property, plant and equipment and their respective balances for Dominion Midstream are as follows:

	June 30, 2015		December 31, 2014
(millions)
Storage	$	875.1	$	882.0
Transmission	666.2		323.9
Plant under construction	1,575.6		972.3
General and other	35.9		24.9
Total property, plant and equipment	$	3,152.8	$	2,203.1

The increase in property, plant and equipment is primarily related to the DCGT Acquisition and capital expenditures for the Liquefaction Project.

During the six months ended June 30, 2015, Dominion Midstream capitalized interest costs and AFUDC of $0.6 million to property, plant and equipment. No such costs were capitalized in 2014.

Depreciation rates on utility property, plant and equipment are as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2015	2014	2015	2014
(percent)
Storage	2.39	2.38	2.38	2.38
Transmission	2.28	2.82	2.28	2.82
General and other	7.68	4.24	7.65	3.58

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Goodwill and Intangible Assets

6 Months Ended

Jun. 30, 2015

Goodwill and Intangible Assets Disclosure [Abstract]

Goodwill and Intangible Assets

Goodwill and Intangible Assets

Goodwill

The changes in Dominion Midstream's carrying amount and segment allocation of goodwill are presented below:

	Dominion Energy		Corporate and Other		Total
(millions)
Six Months Ended June 30, 2015
Beginning balance(1)	$	45.9	$	—	$	45.9
DCGT Acquisition	249.6		—		249.6
Ending balance(1)	$	295.5	$	—	$	295.5

(1) There are no accumulated impairment losses.

Other Intangible Assets

Dominion Midstream's other intangible assets are subject to amortization over their estimated useful lives. Amortization expense for intangible assets was $0.6 million and $0.9 million for the three and six month periods ended June 30, 2015, respectively. Amortization expense was $0.1 million and 0.3 million for the three and six month periods ended June 30, 2014, respectively. The increase in intangible assets is primarily due to software acquired in the DCGT Acquisition. The acquired intangible assets have an estimated weighted-average amortization period of approximately 5 years. The components of intangible assets are as follows:

	June 30, 2015				December 31, 2014
	Gross Carrying Amount		Accumulated Amortization		Gross Carrying Amount		Accumulated Amortization
(millions)
Software and other	$	30.8	$	22.3	$	6.5	$	2.4
Licenses	11.0		3.2		11.0		3.0
Total	$	41.8	$	25.5	$	17.5	$	5.4

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Regulatory Matters

6 Months Ended

Jun. 30, 2015

Regulated Operations [Abstract]

Regulatory Matters

Regulatory Matters

The FERC regulates the transportation and sale for resale of natural gas in interstate commerce under the NGA and the Natural Gas Policy Act of 1978, as amended. Under the NGA, the FERC has authority over rates, terms and conditions of services performed by Cove Point and DCGT. The FERC also has jurisdiction over siting, construction and operation of natural gas import facilities and interstate natural gas pipeline facilities.

There have been no significant developments regarding the regulatory matters disclosed in Note 9 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014.

In the second quarter of 2013, DCGT executed binding precedent agreements for the approximately $35 million Edgemoor Project. The FERC approved the Edgemoor Project in February 2015 and construction commenced in March 2015.  The project is expected to be placed into service in the fourth quarter of 2015.

In April 2014, DCGT executed a binding precedent agreement for the approximately $35 million Columbia to Eastover Project. In May 2015, DCGT filed an application to request FERC authorization to construct and operate the project facilities, which are expected to be in service in the second quarter of 2016.

In connection with Dominion’s acquisition of DCGT on January 31, 2015, Dominion agreed to a rate moratorium which precludes DCGT from filing a Section 4 NGA general rate case to establish base rates that would be effective prior to January 1, 2018.

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2015

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation

For the six months ended June 30, 2015 and 2014, the statutory U.S. federal income tax rate reconciles to the effective income tax rate as follows:

Six Months Ended June 30,	2015		2014
U.S. statutory rate	35.0	%	35.0	%
Partnership income not subject to income taxes(1)	(32.9	)	—
Increases resulting from:
State taxes, net of federal benefit(2)	0.2		3.2
Effective tax rate	2.3	%	38.2	%

(1) Reflects the pass-through entity status of Dominion Midstream, including the operations of DCGT subsequent to the DCGT Acquisition, and Cove Point.

(2) 2015 amounts are attributable to the operations of DCGT prior to the DCGT Acquisition, and 2014 amounts are attributable to Cove Point.

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Affiliated Long-Term Debt (Details) - Senior Unsecured Promissory Note Payable - Notes Payable - Dominion - Affiliates - USD ($)		3 Months Ended	6 Months Ended
	Apr. 01, 2015	Jun. 30, 2015	Jun. 30, 2015
Debt Instrument [Line Items]
Interest charges related to borrowing from Dominion		$ 500,000	$ 500,000
Fair Value, Inputs, Level 2
Debt Instrument [Line Items]
Fair value of outstanding debt		289,600,000	289,600,000
Payables to Affiliates
Debt Instrument [Line Items]
Accrued interest payable to Dominion		$ 500,000	$ 500,000
DCGT
Debt Instrument [Line Items]
Term of senior unsecured promissory note payable	2 years
Principal amount	$ 300,800,000.0
Annual interest rate (percentage)	0.60%

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Related Party Transactions

6 Months Ended

Jun. 30, 2015

Related Party Transactions [Abstract]

Related Party Transactions

Related-Party Transactions

Dominion Midstream engages in related-party transactions primarily with other Dominion subsidiaries (affiliates). Dominion Midstream's receivable and payable balances with affiliates are settled based on contractual terms or on a monthly basis, depending on the nature of the underlying transactions. Participation in certain Dominion benefit plans is described in Note 10 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014. At June 30, 2015 and December 31, 2014, amounts due to Dominion associated with these benefit plans were $4.7 million and $4.4 million, respectively, recorded in pension and other postretirement benefit liabilities in the Consolidated Balance Sheets. Transactions related to the DCGT Acquisition are described in Notes 2 and 12. A discussion of the remaining significant related party transactions follows.

Transactions with Affiliates

In connection with the Offering, our general partner entered into a services agreement with DRS. DRS provides administrative, management and other services to Dominion and its subsidiaries as a subsidiary service company. From time to time and at the option of our general partner, our general partner will request that DRS provide, and reimburse DRS for the cost of providing, such administrative, management and other services as it deems necessary or appropriate for our operations. We will reimburse our general partner and its affiliates for the associated costs of obtaining these services.

In connection with Dominion’s acquisition of DCGT, DCGT entered into services agreements beginning February 1, 2015 with DRS, for similar services as described above, and with Dominion Payroll, which provides human resources and operations services to Dominion and its subsidiaries as a subsidiary service company. Additionally, Dominion may seek reimbursement from DCGT for costs incurred related to Dominion's transition services agreement with SCANA to provide administrative functions related to DCGT. During the three months ended June 30, 2015, DCGT reimbursed Dominion $1.1 million for such costs.

Dominion Midstream provides transportation services to affiliates and affiliates provide goods and services to Dominion Midstream.

Affiliated transactions are presented below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
(millions)
Sales of natural gas transportation services to affiliates	$	0.4	$	0.5	$	1.1	$	1.3
Purchased gas from affiliates	0.1		0.2		0.3		0.4
Services provided by DRS and Dominion Payroll(1)(2)	4.2		2.8		7.8		6.1
Goods and services provided by affiliates to Dominion Midstream(1)	5.3		0.8		8.9		1.5

(1) Includes $3.1 million and $5.5 million of capitalized expenditures for the three and six months ended June 30, 2015, and $1.7 millionand $3.7 million for the three and six months ended June 30, 2014.

(2) Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with DRS, an affiliated variable interest entity, and therefore none is the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated subsidiaries has an obligation to absorb more than its allocated share of DRS costs.

Dominion Midstream determined that neither it nor any of its consolidated entities is the most closely associated entity with Dominion Payroll, an affiliated variable interest entity, and therefore none is the primary beneficiary. Dominion Payroll provides human resources and operations services to certain Dominion subsidiaries, including Dominion Midstream. Neither Dominion Midstream nor any of its consolidated entities has an obligation to absorb more than its allocated share of Dominion Payroll costs.

Advance from Affiliate

An outstanding advance of $20.0 million previously received by Cove Point from an affiliate was converted to an equity contribution in March 2014.

Dominion Credit Facility

In connection with the Offering, Dominion Midstream entered into a credit facility with Dominion with a borrowing capacity of $300 million. A summary of certain key terms of the credit facility with Dominion is included in Note 14 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014. At June 30, 2015, $5.9 million was outstanding against the credit facility. No amounts were outstanding at December 31, 2014. Outstanding borrowings are presented within current liabilities as such amounts could become payable on demand after a 90-day termination notice provided by either party. No such notice has been provided through the date of this filing. Interest charges related to Dominion Midstream's borrowings against the facility were less than $0.1 million for the three and six months ended June 30, 2015.

Income Taxes

Prior to the Offering, Cove Point participated in Dominion's intercompany tax sharing agreement as described in Note 15 to the Consolidated Financial Statements in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014. Cove Point's participation in this tax sharing agreement was terminated in 2014 in connection with the Offering.

At the time of the Offering, Cove Point settled net income taxes payable and deferred income taxes to Dominion of $147.9 million through equity contributions from Dominion. Prior to the Offering, Cove Point settled net income taxes payable to Dominion of $1.2 million through equity contributions from Dominion during the year ended December 31, 2014.

DCGT participated in Dominion's intercompany tax sharing agreement from February 1, 2015 through March 31, 2015. DCGT's participation in this tax sharing agreement was subsequently terminated in connection with the DCGT Acquisition. At the time of the DCGT Acquisition, DCGT settled income taxes payable and net deferred income taxes of $13.4 million through an equity transaction with Dominion.

Natural Gas Imbalances

Dominion Midstream maintains natural gas imbalances with affiliates. The imbalances with affiliates are provided below:

	June 30, 2015		December 31, 2014
(millions)
Imbalances payable to affiliates	$	3.4	$	2.5

Right of First Offer

In connection with the Offering, Dominion Midstream entered into a right of first offer agreement with Dominion as described in Dominion Midstream's Annual Report on Form 10-K for the year ended December 31, 2014. There have been no changes to this agreement.

Contributions from Dominion

During the second quarter of 2015, Dominion contributed $271.8 million to Cove Point to fund capital expenditures related to the Liquefaction Project. In July 2015, Dominion made additional contributions of $110.2 million to Cove Point to fund capital expenditures related to the Liquefaction Project. In February 2015, Dominion contributed $1.3 million in cash to DCGT to fund operations.

Transaction and transition costs incurred by the DCGT Predecessor were attributed to Dominion Midstream and expensed in Operations and maintenance expense in the Consolidated Income Statement. At the time of the DCGT Acquisition, Dominion Midstream settled amounts payable to Dominion of $1.0 million through equity contributions from Dominion.

Subsequent to the DCGT Acquisition, Dominion allocated transaction and transition costs of $1.0 million to Dominion Midstream, of which Dominion did not seek reimbursement for $0.7 million as described further in Note 2.

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Net Income Per Limited Partner Unit (Tables)

6 Months Ended

Jun. 30, 2015

Earnings Per Share [Abstract]

Schedule of Calculation of Earnings per Unit

The calculation of earnings per limited partner unit is as follows:

	Three Months Ended June 30, 2015			Six Months Ended June 30, 2015
(millions)
Net income attributable to partners	$	17.6		$	29.4
Less: General partner allocation(1)	(0.7		)	(0.7		)
Distributions declared on:
Incentive distribution holder rights(2)	—			—
Common units(3)	6.9			13.4
Subordinated units(3)	6.0			11.6
Total distributions declared	12.9			25.0
Undistributed earnings	$	5.4		$	5.1

(1) See Note 2 for further information.

(2) Dominion is a non-economic general partner that holds all of the IDRs.

(3) On July 17, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1875 per unit, totaling $12.9 million, for the three months ended June 30, 2015. This distribution will be paid on August 14, 2015 to unitholders of record on August 4, 2015. The amount of distributions declared shown above is based on the units outstanding at June 30, 2015.

On April 22, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1750 per unit, totaling $12.1 million, for the three months ended March 31, 2015. This distribution was paid on May 15, 2015 to unitholders of record on May 5, 2015.

Basic and diluted net income per limited partner unit
Three Months Ended June 30, 2015	Common Units		Subordinated Units		General Partner			Total
(millions, except for weighted average units and per unit data)
General partner allocation	$	—	$	—	$	(0.7	)	$	(0.7	)
Distributions declared	6.9		6.0		—			12.9
Undistributed earnings	2.9		2.5		—			5.4
Net income attributable to partners	$	9.8	$	8.5	$	(0.7	)	$	17.6
Weighted average units outstanding	37,092,305		31,972,789
Net income per limited partner unit	$	0.26	$	0.26

Basic and diluted net income per limited partner unit
Six Months Ended June 30, 2015	Common Units		Subordinated Units		General Partner			Total
(millions, except for weighted average units and per unit data)
General partner allocation	$	—	$	—	$	(0.7	)	$	(0.7	)
Distributions declared	13.4		11.6		—			25.0
Undistributed earnings	2.6		2.5		—			5.1
Net income attributable to partners	$	16.0	$	14.1	$	(0.7	)	$	29.4
Weighted average units outstanding	34,550,329		31,972,789
Net income per limited partner unit	$	0.47	$	0.44

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Regulatory Matters (Narrative) (Details) - FERC - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2014	Jun. 30, 2013
Edgemoor Project
Public Utilities, General Disclosures [Line Items]
Amount of project		$ 35
Columbia to Eastover Project
Public Utilities, General Disclosures [Line Items]
Amount of project	$ 35

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Operating Revenue (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Public Utilities, General Disclosures [Line Items]
Gas transportation and storage		$ 78.9		$ 153.6
Other		26.5		30.2
Total operating revenue	[1]	$ 105.4		$ 183.8
Predecessor
Public Utilities, General Disclosures [Line Items]
Gas transportation and storage			$ 64.9		$ 130.5
Other			46.3		49.6
Total operating revenue	[1]		$ 111.2		$ 180.1

[1] See Note 15 for amounts attributable to related parties.

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Consolidated Statement of Equity and Partners' Capital - 6 months ended Jun. 30, 2015 - USD ($) $ in Millions	Total	DCGT	DCGT Dominion	DCGT Predecessor Equity	DCGT Predecessor Equity DCGT	DCGT Predecessor Equity DCGT Dominion	Common Unitholders and Subordinated Unitholder Common Units Common Unitholders Public	Common Unitholders and Subordinated Unitholder Common Units Common Unitholder and Subordinated Unitholder- Dominion	Common Unitholders and Subordinated Unitholder Common Units Common Unitholder and Subordinated Unitholder- Dominion DCGT	Common Unitholders and Subordinated Unitholder Subordinated Units Common Unitholder and Subordinated Unitholder- Dominion	General Partner Dominion (non-economic interest) General Partner Dominion (non-economic interest)	General Partner Dominion (non-economic interest) General Partner Dominion (non-economic interest) DCGT	Total Dominion Midstream Partners, LP Partners' Equity and Capital	Total Dominion Midstream Partners, LP Partners' Equity and Capital DCGT	Total Dominion Midstream Partners, LP Partners' Equity and Capital DCGT Dominion	Noncontrolling interest
Balance at Dec. 31, 2014	$ 2,150.8			$ 0.0			$ 395.4	$ 213.7		$ 466.2	$ 0.0		$ 1,075.3			$ 1,075.5
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income including noncontrolling interest	87.7						8.8	7.4		13.9	(0.7)		29.4			58.3
DCGT Acquisition:
Record Dominion's net investment in DCGT		$ 0.0	$ 497.0		$ (501.6)	$ 497.0						$ 501.6		$ 0.0	$ 497.0
Net income attributable to DCGT Predecessor	(2.3)		2.3			2.3									2.3
Contribution from Dominion to DCGT prior to DCGT Acquisition	272.5		2.3			2.3					0.7		0.7		2.3	271.8
Allocation of DCGT Predecessor investment		0.0	497.0		$ (501.6)	497.0						501.6		0.0	497.0
Settlement of net current and deferred income tax assets		(13.4)										(13.4)		(13.4)
Consideration provided to Dominion for DCGT Acquisition		$ (300.8)							$ 200.0			$ (500.8)		$ (300.8)
Equity contributions from Dominion	272.5		$ 2.3			$ 2.3					0.7		0.7		$ 2.3	271.8
Distributions	(21.0)						(6.3)	(4.6)		(10.1)			(21.0)
Unit awards (net of unearned compensation)	0.1						0.1						0.1
Balance at Jun. 30, 2015	$ 2,677.5			$ 0.0			$ 398.0	$ 416.5		$ 470.0	$ (12.6)		$ 1,271.9			$ 1,405.6

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Net Income Per Limited Partner Unit

6 Months Ended

Jun. 30, 2015

Earnings Per Share [Abstract]

Net Income Per Unit

Net Income Per Limited Partner Unit

Net income per limited partner unit applicable to common and subordinated units is computed by dividing the respective limited partners’ interest in net income attributable to Dominion Midstream, after deducting any incentive distributions, by the weighted average number of common units and subordinated units outstanding. Because Dominion Midstream has more than one class of participating securities, the two-class method is used when calculating the net income per unit applicable to limited partners. The classes of participating securities include common units, subordinated units, and IDRs.

Dominion Midstream’s net income is allocated to the limited partners in accordance with their respective partnership percentages, after giving effect to priority income allocations for incentive distributions, if any, to Dominion, the holder of the IDRs, pursuant to the partnership agreement. The distributions are declared and paid following the close of each quarter. Earnings in excess of distributions are allocated to the limited partners based on their respective ownership interests. Payments made to Dominion Midstream's unitholders are determined in relation to actual distributions declared and are not based on the net income allocations used in the calculation of earnings per limited partner unit.

Net income per limited partner unit is only calculated for the periods subsequent to the Offering as no units were outstanding prior to October 20, 2014. Diluted net income per limited partner unit is the same as basic net income per limited partner unit as there were no potentially dilutive common or subordinated units outstanding as of June 30, 2015.

The calculation of earnings per limited partner unit is as follows:

	Three Months Ended June 30, 2015			Six Months Ended June 30, 2015
(millions)
Net income attributable to partners	$	17.6		$	29.4
Less: General partner allocation(1)	(0.7		)	(0.7		)
Distributions declared on:
Incentive distribution holder rights(2)	—			—
Common units(3)	6.9			13.4
Subordinated units(3)	6.0			11.6
Total distributions declared	12.9			25.0
Undistributed earnings	$	5.4		$	5.1

(1) See Note 2 for further information.

(2) Dominion is a non-economic general partner that holds all of the IDRs.

(3) On July 17, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1875 per unit, totaling $12.9 million, for the three months ended June 30, 2015. This distribution will be paid on August 14, 2015 to unitholders of record on August 4, 2015. The amount of distributions declared shown above is based on the units outstanding at June 30, 2015.

On April 22, 2015, the Board of Directors of our general partner declared a quarterly cash distribution of $0.1750 per unit, totaling $12.1 million, for the three months ended March 31, 2015. This distribution was paid on May 15, 2015 to unitholders of record on May 5, 2015.

Basic and diluted net income per limited partner unit
Three Months Ended June 30, 2015	Common Units		Subordinated Units		General Partner			Total
(millions, except for weighted average units and per unit data)
General partner allocation	$	—	$	—	$	(0.7	)	$	(0.7	)
Distributions declared	6.9		6.0		—			12.9
Undistributed earnings	2.9		2.5		—			5.4
Net income attributable to partners	$	9.8	$	8.5	$	(0.7	)	$	17.6
Weighted average units outstanding	37,092,305		31,972,789
Net income per limited partner unit	$	0.26	$	0.26

Basic and diluted net income per limited partner unit
Six Months Ended June 30, 2015	Common Units		Subordinated Units		General Partner			Total
(millions, except for weighted average units and per unit data)
General partner allocation	$	—	$	—	$	(0.7	)	$	(0.7	)
Distributions declared	13.4		11.6		—			25.0
Undistributed earnings	2.6		2.5		—			5.1
Net income attributable to partners	$	16.0	$	14.1	$	(0.7	)	$	29.4
Weighted average units outstanding	34,550,329		31,972,789
Net income per limited partner unit	$	0.47	$	0.44

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Unit Activity (Tables)

6 Months Ended

Jun. 30, 2015

Equity [Abstract]

Schedule of Capital Units

Activity in the number of units was as follows:

	Common
	Public	Dominion	Subordinated	General Partner	Total
				(non-economic interest)
Balance at December 31, 2014	20,127,322	11,847,789	31,972,789	—	63,947,900
Unit-based compensation	5,055	—	—	—	5,055
Units issued in connection with the DCGT Acquisition	—	5,112,139	—	—	5,112,139
Balance at June 30, 2015	20,132,377	16,959,928	31,972,789	—	69,065,094

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Acquisition (Schedule of Consolidated Statement of Income) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Business Acquisition [Line Items]
Operating revenue	[1]	$ 105.4		$ 183.8
Purchased gas	[1]	25.5		29.4
Other operations and maintenance:
Affiliated suppliers		6.4		11.2
Other		9.6		18.1
Depreciation and amortization		9.9		20.5
Other taxes		6.8		12.7
Total operating expenses		58.2		91.9
Income from operations		47.2		91.9
Other income		0.2		0.4
Interest and related charges	[1]	0.2		0.2
Income from operations including noncontrolling interest before income taxes		47.2		92.1
Income tax expense		0.0		2.1
Net income including noncontrolling interest and DCGT Predecessor		47.2		90.0
Less: Net income attributable to DCGT Predecessor		0.0		2.3
Net income including noncontrolling interest		47.2		87.7
Less: Net income attributable to noncontrolling interest		29.6		58.3
Net income attributable to partners		$ 17.6		29.4
Dominion Midstream
Business Acquisition [Line Items]
Operating revenue				172.6
Purchased gas				29.4
Other operations and maintenance:
Affiliated suppliers				8.7
Other				15.8
Depreciation and amortization				19.2
Other taxes				11.9
Total operating expenses				85.0
Income from operations				87.6
Other income				0.3
Interest and related charges				0.2
Income from operations including noncontrolling interest before income taxes				87.7
Income tax expense				0.0
Net income including noncontrolling interest and DCGT Predecessor				87.7
Less: Net income attributable to DCGT Predecessor				0.0
Net income including noncontrolling interest				87.7
Less: Net income attributable to noncontrolling interest				58.3
Net income attributable to partners				29.4
Predecessor
Business Acquisition [Line Items]
Operating revenue	[1]		$ 111.2		$ 180.1
Purchased gas	[1]		47.8		53.1
Other operations and maintenance:
Affiliated suppliers			1.9		3.9
Other			8.9		17.3
Depreciation and amortization			7.9		15.7
Other taxes			5.5		11.1
Total operating expenses			72.0		101.1
Income from operations			39.2		79.0
Other income			0.0		0.0
Interest and related charges	[1]		0.0		0.0
Income from operations including noncontrolling interest before income taxes			39.2		79.0
Income tax expense			15.0		30.2
Net income including noncontrolling interest and DCGT Predecessor			$ 24.2		$ 48.8
Predecessor | DCGT
Business Acquisition [Line Items]
Operating revenue				11.2
Purchased gas				0.0
Other operations and maintenance:
Affiliated suppliers				2.5
Other				2.3
Depreciation and amortization				1.3
Other taxes				0.8
Total operating expenses				6.9
Income from operations				4.3
Other income				0.1
Interest and related charges				0.0
Income from operations including noncontrolling interest before income taxes				4.4
Income tax expense				2.1
Net income including noncontrolling interest and DCGT Predecessor				2.3
Less: Net income attributable to DCGT Predecessor				2.3
Net income including noncontrolling interest				0.0
Less: Net income attributable to noncontrolling interest				0.0
Net income attributable to partners				$ 0.0

[1] See Note 15 for amounts attributable to related parties.

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Credit Risk

6 Months Ended

Jun. 30, 2015

Risks and Uncertainties [Abstract]

Credit Risk

Credit Risk

Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition. In addition, counterparties may make available collateral, including letters of credit, payment guarantees, or cash deposits.

Dominion Midstream provides service to approximately seventy customers, including the Storage Customers, marketers or end users and the Import Shippers. The two largest customers comprised approximately 71% of the total transportation and storage revenues for each of the three and six months ended June 30, 2015, with Dominion Midstream's largest customer representing approximately 56% and 57% of such amounts in each period, respectively.

For each of the three and six months ended June 30, 2014, Cove Point's three largest customers comprised approximately 87% of the total transportation and storage revenues, with Cove Point's largest customer representing approximately 68% of such amounts in each period.

Dominion Midstream maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends and other information. At June 30, 2015, the provision for credit losses was less than $0.1 million. Management believes, based on credit policies and the June 30, 2015 provision for credit losses, that it is unlikely that a material adverse effect on financial position, results of operations or cash flows would occur as a result of counterparty nonperformance.