UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark one)
For the quarterly period ended June 30, 2014
or
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
120 Tredegar Street
Richmond, Virginia 23219
(804) 819-2000
State or other jurisdiction of incorporation or organization of the registrants: Virginia
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.
Dominion Resources, Inc. Yes x No ¨ Virginia Electric and Power Company Yes x No ¨
Dominion Gas Holdings, LLC Yes ¨ No x
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).
Dominion Gas Holdings, LLC 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.
Dominion Resources, Inc.
Virginia Electric and Power Company
Dominion Gas Holdings, LLC
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Dominion Resources, Inc. Yes ¨ No x Virginia Electric and Power Company Yes ¨ No x
At June 30, 2014, the latest practicable date for determination, Dominion Resources, Inc. had 582,667,882 shares of common stock outstanding and Virginia Electric and Power Company had 274,723 shares of common stock outstanding. Dominion Resources, Inc. is the sole holder of Virginia Electric and Power Company’s common stock. Dominion Resources, Inc. holds all of the membership interests of Dominion Gas Holdings, LLC.
This combined Form 10-Q represents separate filings by Dominion Resources, Inc., Virginia Electric and Power Company and Dominion Gas Holdings, LLC. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Virginia Electric and Power Company and Dominion Gas Holdings, LLC make no representations as to the information relating to Dominion Resources, Inc.’s other operations.
DOMINION GAS HOLDINGS, LLC MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION H(1)(a) AND (b) OF FORM 10-Q AND IS FILING THIS FORM 10-Q UNDER THE REDUCED DISCLOSURE FORMAT.
COMBINED INDEX
Glossary of Terms
Item 1.
Financial Statements
Item 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Item 3.
Quantitative and Qualitative Disclosures About Market Risk
Item 4.
Controls and Procedures
Legal Proceedings
Item 1A.
Risk Factors
Unregistered Sales of Equity Securities and Use of Proceeds
Item 6.
Exhibits
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GLOSSARY OF TERMS
The following abbreviations or acronyms used in this Form 10-Q are defined below:
Abbreviation or Acronym
Definition
2013 Equity Units
Dominion's 2013 Series A Equity Units and 2013 Series B Equity Units issued in June 2013
2014 Equity Units
Dominion's 2014 Series A Equity Units issued in July 2014
AFUDC
Allowance for funds used during construction
AMR
Automated meter reading program deployed by East Ohio
AOCI
Accumulated other comprehensive income (loss)
AROs
Asset retirement obligations
ARP
Acid Rain Program, a market-based initiative for emissions allowance trading, established pursuant to Title IV of the CAA
ASLB
Atomic Safety and Licensing Board
ATEX line
Appalachia to Texas Express ethane line
BACT
Best available control technology
bcf
Billion cubic feet
Bear Garden
A 590 MW combined cycle, natural gas-fired power station in Buckingham County, Virginia
Blue Racer
Blue Racer Midstream, LLC, a joint venture with Caiman
BOD
Board of Directors
BP
BP Wind Energy North America Inc.
Brayton Point
Brayton Point power station
BREDL
Blue Ridge Environmental Defense League
Brunswick County
A 1,358 MW combined cycle, natural gas-fired power station under construction in Brunswick County, Virginia
CAA
Clean Air Act
Caiman
Caiman Energy II, LLC
CAIR
Clean Air Interstate Rule
CEO
Chief Executive Officer
CERCLA
Comprehensive Environmental Response, Compensation and Liability Act of 1980, also known as Superfund
CFO
Chief Financial Officer
CO2
Carbon dioxide
COL
Combined Construction Permit and Operating License
Companies
Dominion, Virginia Power and Dominion Gas, collectively
Cooling degree days
Units measuring the extent to which the average daily temperature is greater than 65 degrees Fahrenheit, calculated as the difference between 65 degrees and the average temperature for that day
Corporate Unit
A stock purchase contract and 1/20 interest in a RSN issued by Dominion
Cove Point
Dominion Cove Point LNG, LP
Cove Point LNG Facility
An LNG import/regasification and storage facility located on the Chesapeake Bay in Lusby, Maryland
CPCN
Certificate of Public Convenience and Necessity
CSAPR
Cross State Air Pollution Rule
CWA
Clean Water Act
D.C.
District of Columbia
DEI
Dominion Energy, Inc.
DOE
Department of Energy
Dominion
The legal entity, Dominion Resources, Inc., one or more of its consolidated subsidiaries (other than Virginia Power and Dominion Gas) or operating segments or the entirety of Dominion Resources, Inc. and its consolidated subsidiaries
Dominion Gas
The legal entity, Dominion Gas Holdings, LLC, one or more of its consolidated subsidiaries or operating segment, or the entirety of Dominion Gas Holdings, LLC and its consolidated subsidiaries
Dominion Gas 2013 Senior Notes
The $400 million 2013 Series A 1.05% Senior Notes due 2016, $400 million 2013 Series B 3.55% Senior Notes due 2023 and $400 million 2013 Series C 4.80% Senior Notes due 2043
Dominion Iroquois
Dominion Iroquois, Inc., which holds a 24.72% general partnership interest in Iroquois
Dominion NGL Pipelines, LLC
The initial owner of the 58-mile G-150 pipeline project, which is designed to transport approximately 27,000 barrels per day of NGLs from Natrium to an interconnect with the ATEX line of Enterprise near Follansbee, West Virginia
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DRS
Dominion Resources Services, Inc.
DSM
Demand-side management
Dth
Dekatherm
DTI
Dominion Transmission, Inc.
DVP
Dominion Virginia Power operating segment
East Ohio
The East Ohio Gas Company, doing business as Dominion East Ohio
Elwood
Elwood power station
Energy Capital Partners
A private equity firm with offices in Short Hills, New Jersey and San Diego, California
Enterprise
Enterprise Product Partners, L.P.
EPA
Environmental Protection Agency
EPC
Engineering, procurement and construction
EPS
Earnings per share
ESBWR
General Electric-Hitachi's Economic Simplified Boiling Water Reactor
FERC
Federal Energy Regulatory Commission
Flex MMP Stock
Virginia Power's Flexible Money Market Cumulative Preferred Stock 2002 Series A
Fowler Ridge
A wind-turbine facility joint venture between Dominion and BP in Benton County, Indiana
FTRs
Financial transmission rights
GAAP
U.S. generally accepted accounting principles
Gal
Gallon
GHG
Greenhouse gas
Heating degree days
Units measuring the extent to which the average daily temperature is less than 65 degrees Fahrenheit, calculated as the difference between 65 degrees and the average temperature for that day
House Bill 95
Ohio utility reform legislation effective September 2011
Illinois Gas Contracts
A Dominion Retail natural gas book of business consisting of residential and commercial customers in Illinois
INPO
Institute of Nuclear Power Operations
IRCA
Intercompany revolving credit agreement
Iroquois
Iroquois Gas Transmission System L.P.
ISO
Independent system operator
ISO-NE
ISO New England
June 2009 hybrids
2009 Series A Enhanced Junior Subordinated Notes due 2064, subject to extensions to no later than 2079
Kewaunee
Kewaunee nuclear power station
Kincaid
Kincaid power station
kV
Kilovolt
Line TL-404
An approximately 26-mile, 24- and 30- inch gas gathering pipeline that extends from Wetzel County, West Virginia to Monroe County, Ohio
LNG
Liquefied natural gas
Maryland Commission
Public Service Commission of Maryland
MD&A
MGD
Million gallons a day
Millstone
Millstone nuclear power station
MISO
Midcontinent Independent Transmission System Operator, Inc.
MLP
Master limited partnership
Moody’s
Moody’s Investors Service
MW
Megawatt
MWh
Megawatt hour
Natrium
A natural gas and fractionation facility located in Natrium, West Virginia, owned by Blue Racer
NCEMC
North Carolina Electric Membership Corporation
NedPower
A wind-turbine facility joint venture between Dominion and Shell in Grant County, West Virginia
NGLs
Natural gas liquids
North Anna
North Anna nuclear power station
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North Carolina Commission
North Carolina Utilities Commission
Northern System
Collection of approximately 131 miles of various diameter natural gas pipelines in Ohio
NOx
Nitrogen oxide
NPDES
National Pollutant Discharge Elimination System
NRC
Nuclear Regulatory Commission
NSPS
New Source Performance Standards
NYSE
New York Stock Exchange
ODEC
Old Dominion Electric Cooperative
Ohio Commission
Public Utilities Commission of Ohio
Order 1000
Order issued by FERC adopting new requirements for electric transmission planning, cost allocation and development
PIPP
Percentage of Income Payment Plan
PIR
Pipeline Infrastructure Replacement program deployed by East Ohio
PJM
PJM Interconnection, L.L.C.
ppb
Parts-per-billion
PSD
Prevention of Significant Deterioration
RCC
Replacement Capital Covenant
Rider B
A rate adjustment clause associated with the recovery of costs related to the conversion of three of Virginia Power’s coal-fired power stations to biomass
Rider BW
A rate adjustment clause associated with the recovery of costs related to Brunswick County
Rider R
A rate adjustment clause associated with the recovery of costs related to Bear Garden
Rider S
A rate adjustment clause associated with the recovery of costs related to the Virginia City Hybrid Energy Center
Rider T1
A rate adjustment clause to recover the difference between revenues produced from transmission rates included in base rates, and the new total revenue requirement developed annually for the rate years effective September 1
Rider W
A rate adjustment clause associated with the recovery of costs related to Warren County
Riders C1A and C2A
Rate adjustment clauses associated with the recovery of costs related to certain DSM programs approved in DSM cases
ROE
Return on equity
RSN
Remarketable subordinated note
RTO
Regional transmission organization
SEC
Securities and Exchange Commission
Shell
Shell WindEnergy, Inc.
SO2
Sulfur dioxide
Standard & Poor’s
Standard & Poor’s Ratings Services, a division of McGraw Hill Financial, Inc.
Surry
Surry nuclear power station
U.S.
United States of America
UAO
Unilateral Administrative Order
UEX Rider
Uncollectible Expense Rider deployed by East Ohio
VEBA
Voluntary Employees' Beneficiary Association
VIE
Variable interest entity
Virginia City Hybrid Energy Center
A 600 MW baseload carbon-capture compatible, clean coal powered electric generation facility in Wise County, Virginia
Virginia Commission
Virginia State Corporation Commission
Virginia Power
The legal entity, Virginia Electric and Power Company, one or more of its consolidated subsidiaries or operating segments or the entirety of Virginia Power and its consolidated subsidiaries
Warren County
A 1,329 MW combined-cycle, natural gas-fired power station under construction in Warren County, Virginia
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PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
DOMINION RESOURCES, INC.
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
Operating Revenue
Operating Expenses
Electric fuel and other energy-related purchases
Purchased electric capacity
Purchased gas
Other operations and maintenance
Depreciation, depletion and amortization
Other taxes
Total operating expenses
Income from operations
Other income
Interest and related charges
Income from continuing operations including noncontrolling interests before income tax expense
Income tax expense
Income from continuing operations including noncontrolling interests
Loss from discontinued operations(1)
Net Income Including Noncontrolling Interests
Noncontrolling Interests
Net Income Attributable to Dominion
Amounts Attributable to Dominion:
Income from continuing operations, net of tax
Loss from discontinued operations, net of tax
Net income attributable to Dominion
Earnings Per Common Share-Basic
Income from continuing operations
Loss from discontinued operations
Earnings Per Common Share-Diluted
Dividends declared per common share
The accompanying notes are an integral part of Dominion’s Consolidated Financial Statements.
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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
Net income including noncontrolling interests
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities(1)
Changes in unrealized net gains on investment securities(2)
Changes in unrecognized pension and other postretirement benefit costs(3)
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities(4)
Net realized gains on investment securities(5)
Net pension and other postretirement benefit costs(6)
Changes in other comprehensive income (loss) from equity method investees(7)
Total other comprehensive income (loss)
Comprehensive income including noncontrolling interests
Comprehensive income attributable to noncontrolling interests
Comprehensive income attributable to Dominion
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CONSOLIDATED BALANCE SHEETS
ASSETS
Current Assets
Cash and cash equivalents
Customer receivables (less allowance for doubtful accounts of $23 and $25)
Other receivables (less allowance for doubtful accounts of $3 and $4)
Inventories
Prepayments
Other
Total current assets
Investments
Nuclear decommissioning trust funds
Investment in equity method affiliates
Total investments
Property, Plant and Equipment
Property, plant and equipment
Accumulated depreciation, depletion and amortization
Total property, plant and equipment, net
Deferred Charges and Other Assets
Goodwill
Regulatory assets
Total deferred charges and other assets
Total assets
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CONSOLIDATED BALANCE SHEETS—(Continued)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current Liabilities
Securities due within one year
Short-term debt
Accounts payable
Derivative liabilities
Total current liabilities
Long-Term Debt
Long-term debt
Junior subordinated notes
Remarketable subordinated notes
Total long-term debt
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits
Regulatory liabilities
Total deferred credits and other liabilities
Total liabilities
Commitments and Contingencies (see Note 15)
Subsidiary Preferred Stock Not Subject to Mandatory Redemption
Common Shareholders’ Equity
Common stock – no par(2)
Retained earnings
Accumulated other comprehensive loss
Total common shareholders’ equity
Total liabilities and shareholders’ equity
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CONSOLIDATED STATEMENTS OF CASH FLOWS
Six Months Ended June 30,
Operating Activities
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)
Gains on the sale of assets
Charges associated with North Anna and offshore wind legislation
Other adjustments
Changes in:
Accounts receivable
Deferred fuel and purchased gas costs, net
Accrued interest, payroll and taxes
Margin deposit assets and liabilities
Other operating assets and liabilities
Net cash provided by operating activities
Investing Activities
Plant construction and other property additions (including nuclear fuel)
Acquisition of solar development projects
Proceeds from sales of securities
Purchases of securities
Proceeds from the sale of assets to Blue Racer
Proceeds from the sale of electric retail energy marketing business
Restricted cash equivalents
Net cash used in investing activities
Financing Activities
Issuance (repayment) of short-term debt, net
Issuance of long-term debt
Repayment of long-term debt, including redemption premiums
Repayment of junior subordinated notes
Subsidiary preferred stock redemption
Issuance of common stock
Common dividend payments
Subsidiary preferred dividend payments
Net cash provided by financing activities
Increase (decrease) in cash and cash equivalents
Cash and cash equivalents at beginning of period
Cash and cash equivalents at end of period
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures
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VIRGINIA ELECTRIC AND POWER COMPANY
Operating Revenue(1)
Electric fuel and other energy-related purchases(1)
Other operations and maintenance:
Affiliated suppliers
Depreciation and amortization
Income before income tax expense
Net Income
Preferred dividends
Balance available for common stock
The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.
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Three Months Ended
June 30,
Six Months Ended
Net income
Changes in unrealized net gains on nuclear decommissioning trust funds(2)
Net derivative gains-hedging activities(3)
Net realized gains on nuclear decommissioning trust funds(4)
Other comprehensive income
Comprehensive income
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Customer receivables (less allowance for doubtful accounts of $12 and $11)
Other receivables (less allowance for doubtful accounts of $2 at both dates)
Inventories (average cost method)
Accumulated depreciation and amortization
Intangible assets, net
Other(2)
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LIABILITIES AND SHAREHOLDER’S EQUITY
Payables to affiliates
Affiliated current borrowings
Preferred Stock Not Subject to Mandatory Redemption
Common Shareholder’s Equity
Common stock – no par(3)
Other paid-in capital
Accumulated other comprehensive income
Total common shareholder’s equity
Total liabilities and shareholder’s equity
PAGE 14
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)
Deferred fuel expenses
Plant construction and other property additions
Purchases of nuclear fuel
Issuance of short-term debt, net
Repayment of affiliated current borrowings, net
Repayment of long-term debt
Preferred stock redemption
Preferred dividend payments
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DOMINION GAS HOLDINGS, LLC
Purchased gas(1)
Other energy-related purchases
Interest and related charges(1)
Income from operations before income taxes
The accompanying notes are an integral part of Dominion Gas’ Consolidated Financial Statements.
PAGE 16
Changes in net unrecognized pension and other postretirement benefit costs(2)
Net derivative losses-hedging activities(3)
Net pension and other postretirement benefit costs(4)
Other comprehensive income (loss)
PAGE 17
Customer receivables (less allowance for doubtful accounts of $4 and $5)(2)
Affiliated receivables
Pension and other postretirement benefit assets(2)
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LIABILITIES AND EQUITY
Equity
Membership interests
Total equity
Total liabilities and equity
PAGE 19
Gains on sales of assets to an affiliate
Deferred purchased gas costs, net
Proceeds from sale of assets to an affiliate
Issuance (repayment) of affiliated current borrowings, net
Distribution payments
Net cash provided by (used in) financing activities
Increase in cash and cash equivalents
Significant noncash investing and financing activities:
Extinguishment of affiliated current borrowings in exchange for assets sold to affiliate
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Nature of Operations
Dominion, headquartered in Richmond, Virginia, is one of the nation’s largest producers and transporters of energy. Dominion’s operations are conducted through various subsidiaries, including Virginia Power and Dominion Gas. Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina. Dominion Gas is a holding company that conducts business activities through a regulated interstate natural gas transmission pipeline and underground storage system in the Northeast, mid-Atlantic and Midwest states, regulated gas transportation and distribution operations in Ohio, and gas gathering and processing activities primarily in West Virginia, Ohio and Pennsylvania. Dominion Gas' wholly-owned subsidiaries are DTI, East Ohio and Dominion Iroquois.
Note 2. Significant Accounting Policies
As permitted by the rules and regulations of the SEC, the Companies’ accompanying unaudited Consolidated Financial Statements contain certain condensed financial information and 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’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, Dominion’s and Virginia Power’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014 and Exhibits 99.11(b) and 99.11(c) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014.
In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of June 30, 2014, their results of operations for the three and six months ended June 30, 2014 and 2013, and their cash flows for the six months ended June 30, 2014 and 2013. Such adjustments are normal and recurring in nature unless otherwise noted.
The Companies make certain estimates and assumptions in preparing their 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 Companies’ accompanying unaudited Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts and those of their respective majority-owned subsidiaries and those VIEs where Dominion has been determined to be the primary beneficiary.
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, electric fuel and other energy-related purchases, purchased gas expenses and other factors.
Certain amounts in the Companies' 2013 Consolidated Financial Statements and Notes have been reclassified to conform to the 2014 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows.
Amounts disclosed for Dominion are inclusive of Virginia Power and/or Dominion Gas, where applicable.
Note 3. Acquisitions and Dispositions
Acquisition of Solar Development Projects
In March 2014, Dominion completed the acquisition of 100% of the equity interests of six solar development projects in California from Recurrent Energy Development Holdings, LLC for approximately $50 million. The projects are expected to cost approximately $450 million once constructed, including the initial acquisition cost. Upon completion, the facilities are expected to generate approximately 139 MW and will provide Dominion with a large utility-scale solar presence in the California market and significantly increase its solar generation portfolio.
In May 2014, Dominion completed the acquisition of 100% of the equity interests of two solar development projects in Tennessee from Strata Solar Development, LLC for $2 million. The projects are expected to cost approximately $70 million once constructed, including the initial acquisition cost. Upon completion, the facilities are expected to generate approximately 32 MW.
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The purchase price for each of these acquisitions was allocated to Property, Plant and Equipment.
In May 2014, Dominion entered into an agreement to acquire 100% of the equity interests of a solar project in California from EDF Renewable Development, Inc. for approximately $70 million. The acquisition is expected to close later this year prior to the project commencing operations. The project is expected to cost approximately $75 million once constructed, including the initial acquisition cost. Upon completion, the facilities are expected to generate approximately 20 MW.
Long-term power purchase, interconnection, EPC and operation and maintenance agreements have been executed for each of the acquired projects. Construction of the projects has commenced and all of the solar facilities are expected to enter commercial operations in late 2014. Dominion expects to claim federal investment tax credits on the projects.
Sale of Electric Retail Energy Marketing Business
In March 2014, Dominion completed the sale of its electric retail energy marketing business. The proceeds were approximately $187 million, net of transaction costs. The sale resulted in a gain, subject to post-closing adjustments, of approximately $100 million ($57 million after-tax) net of a $31 million write-off of goodwill, and is included in other operations and maintenance expense in Dominion's Consolidated Statements of Income. The sale of the electric retail energy marketing business did not qualify for discontinued operations classification.
Sale of Illinois Gas Contracts
In June 2013, Dominion completed the sale of Illinois Gas Contracts. The sales price was approximately $32 million, subject to post-closing adjustments. The sale resulted in a gain of approximately $29 million ($18 million after-tax) net of a $3 million write-off of goodwill, and is included in other operations and maintenance expense in Dominion’s Consolidated Statements of Income. The sale of Illinois Gas Contracts did not qualify for discontinued operations classification.
Sale of Brayton Point, Kincaid and Equity Method Investment in Elwood
In March 2013, Dominion entered into an agreement with Energy Capital Partners to sell Brayton Point, Kincaid, and its equity method investment in Elwood. In August 2013, Dominion completed the sale and received proceeds of approximately $465 million, net of transaction costs.
In the first and second quarters of 2013, Brayton Point’s and Kincaid’s assets and liabilities to be disposed of were classified as held for sale and adjusted to their estimated fair value less cost to sell, resulting in impairment charges totaling $48 million ($28 million after-tax) for the six month period ended June 30, 2013, including $11 million ($6 million after-tax) for the three month period ended June 30, 2013, which are included in discontinued operations in Dominion’s Consolidated Statements of Income. Dominion used the market approach to estimate the fair value of Brayton Point’s and Kincaid’s long-lived assets. These were considered Level 2 fair value measurements given that they were based on the agreed-upon sales price.
Dominion's 50% interest in Elwood was an equity method investment and therefore, in accordance with applicable accounting guidance, the carrying amount of this investment was not classified as held for sale nor were the equity earnings from this investment reported as discontinued operations.
The following table presents selected information regarding the results of operations of Brayton Point and Kincaid, which are reported as discontinued operations in Dominion’s Consolidated Statements of Income:
Operating revenue
Income before income taxes(1)
Assignment of Marcellus Acreage
In December 2013, DTI closed on agreements with two natural gas producers to convey approximately 100,000 acres of Marcellus Shale development rights underneath several of its natural gas storage fields. The agreements provide for payments to DTI, subject to customary adjustments, of approximately $200 million over a period of nine years, and an overriding royalty
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interest in gas produced from the acreage. During the six months ended June 30, 2014, DTI received $16 million in additional cash proceeds resulting from post-closing adjustments. At June 30, 2014, deferred revenue totaled approximately $91 million, which is expected to be recognized over a period of approximately nine years.
Dominion and Dominion Gas
See Note 10 for a discussion of transactions related to Blue Racer.
Note 4. Operating Revenue
The Companies’ operating revenue consists of the following:
Electric sales:
Regulated
Nonregulated
Gas sales:
Gas transportation and storage
Total operating revenue
Regulated electric sales
NGL revenue
Note 5. Income Taxes
For continuing operations, including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to the Companies' effective income tax rate as follows:
U.S. statutory rate
Increases (reductions) resulting from:
State taxes, net of federal benefit
Investment and production tax credits
Valuation allowances
Other, net
Effective tax rate
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In 2014, there have been no material changes in the Companies’ unrecognized tax benefits or expectations regarding possible changes that could reasonably occur during the next twelve months. See Note 5 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 5 in Exhibit 99.11(b) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014 for a discussion of these unrecognized tax benefits.
Note 6. Earnings Per Share
The following table presents the calculation of Dominion’s basic and diluted EPS:
Average shares of common stock outstanding – Basic
Net effect of dilutive securities(1)
Average shares of common stock outstanding – Diluted
Earnings Per Common Share – Basic
Earnings Per Common Share – Diluted
There were no potentially dilutive securities excluded from the calculation of diluted EPS for the three and six months ended June 30, 2014. The 2013 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three and six months ended June 30, 2013. See Note 17 to the Consolidated Financial Statements in Dominion's and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 for more information.
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Note 7. Accumulated Other Comprehensive Income
The following table presents Dominion’s changes in AOCI by component, net of tax:
Three Months Ended June 30, 2014
Beginning balance
Other comprehensive income before reclassifications: gains (losses)
Amounts reclassified from accumulated other comprehensive income(1): (gains) losses
Net current-period other comprehensive income (loss)
Ending balance
Three Months Ended June 30, 2013
Six Months Ended June 30, 2014
Six Months Ended June 30, 2013
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The following table presents Dominion’s reclassifications out of AOCI by component:
Details about AOCI components
Affected line item in the Consolidated Statements of Income
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts
Interest rate contracts
Tax
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities
Impairment
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs
Actuarial (gains) losses
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PAGE 27
The following table presents Dominion Gas’ changes in AOCI by component, net of tax:
Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)
Net current-period other comprehensive income
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The following table presents Dominion Gas' reclassifications out of AOCI by component:
Note 8. Fair Value Measurements
The Companies' fair value measurements are made in accordance with the policies discussed in Note 6 to the Consolidated Financial Statements in Dominion's and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 6 in Exhibit 99.11(b) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014. See Note 9 in this report for further information about their derivatives and hedge accounting activities.
The Companies enter into certain physical and financial forwards, futures, options and swaps, which are considered Level 3 as they have one or more inputs that are not observable and are significant to the valuation. The discounted cash flow method is used to value Level 3 physical and financial forwards and futures contracts. An option model is used to value Level 3 physical and financial options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on
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forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices, and volumes. For Level 3 fair value measurements, forward market prices and implied price volatilities are considered unobservable. The unobservable inputs are developed and substantiated using historical information, available market data, third-party data, and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third-party pricing sources.
The following table presents the Companies' quantitative information about Level 3 fair value measurements at June 30, 2014. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility.
Assets:
Physical and Financial Forwards and Futures:
Natural Gas(2)
FTRs(3)
NGLs (4)
Physical and Financial Options:
Natural Gas
Liabilities:
NGLs(4)
Sensitivity of the fair value measurements to changes in the significant unobservable inputs is as follows:
Significant Unobservable Inputs
Market Price
Price Volatility
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Non-recurring Fair Value Measurements
See Note 3 for non-recurring fair value measurements related to Brayton Point and Kincaid.
In June 2013, Dominion Gas purchased certain natural gas infrastructure facilities that were previously leased from third parties. The purchase price was based on terms in the lease, which exceeded current market pricing. As a result of the purchase price and expected losses, Dominion Gas recorded an impairment charge of $49 million ($29 million after-tax) in other operations and maintenance expense in its Consolidated Statements of Income, to write down the long-lived assets to their estimated fair values of less than $1 million. As management was not aware of any recent market transactions for comparable assets with sufficient transparency to develop a market approach to fair value, Dominion Gas used the income approach (discounted cash flows) to estimate the fair value of the assets in this impairment test. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs, including estimates of future production and other commodity prices.
Also in June 2013, Dominion Gas recorded an impairment charge of $6 million ($4 million after-tax) in other operations and maintenance expense in its Consolidated Statements of Income, to write off previously capitalized costs following the cancellation of two development projects.
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Recurring Fair Value Measurements
The following table presents Dominion’s assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions:
At June 30, 2014
Derivatives:
Commodity
Interest rate
Investments(1):
Equity securities:
U.S.:
Large cap
Non-U.S.:
Fixed income:
Corporate debt instruments
U.S. Treasury securities and agency debentures
State and municipal
Cash equivalents and other
At December 31, 2013
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The following table presents the net change in Dominion's assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:
Total realized and unrealized gains (losses):
Included in earnings
Included in other comprehensive income (loss)
Included in regulatory assets/liabilities
Settlements
Transfers out of Level 3
The amount of gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date
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The following table presents Dominion’s classification of gains and losses included in earnings in the Level 3 fair value category:
Total gains (losses) included in earnings
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date
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The following table presents Virginia Power’s assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions:
U.S. Large cap
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The following table presents the net change in Virginia Power’s assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:
The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases in Virginia Power’s Consolidated Statements of Income for the three and six months ended June 30, 2014 and 2013. There were no unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the three and six months ended June 30, 2014 and 2013.
The following table presents Dominion Gas’ assets and liabilities for commodity and interest rate derivatives that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions:
Total Assets
The following table presents the net change in Dominion Gas’ assets and liabilities for derivatives measured at fair value on a recurring basis and included in the Level 3 fair value category:
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The gains and losses included in earnings in the Level 3 fair value category were classified in operating revenue in Dominion Gas' Consolidated Statements of Income for the three and six months ended June 30, 2014 and 2013. There were no unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the three and six months ended June 30, 2014 and 2013.
Fair Value of Financial Instruments
Substantially all of the Companies' financial instruments are recorded at fair value, with the exception of the instruments described below, which are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of cash and cash equivalents, customer and other receivables, short-term debt, affiliated current borrowings, payables to affiliates and accounts payable are representative of fair value because of the short-term nature of these instruments. For the Companies' financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:
Long-term debt, including securities due within one year(2)
Junior subordinated notes(3)
Remarketable subordinated notes(3)
Subsidiary preferred stock(4)
Long-term debt, including securities due within one year(3)
Preferred stock(4)
Long-term debt(3)
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Note 9. Derivatives and Hedge Accounting Activities
The Companies’ accounting policies and objectives and strategies for using derivative instruments are discussed in Note 2 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 2 in Exhibit 99.11(b) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014. See Note 8 in this report for further information about fair value measurements and associated valuation methods for derivatives.
Derivative assets and liabilities are presented gross on the Companies’ Consolidated Balance Sheets. Dominion’s and Virginia Power’s derivative contracts include both over-the-counter transactions and those that are executed on an exchange or other trading platform (exchange contracts) and centrally cleared. Dominion Gas’ derivative contracts consist of over-the-counter transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Exchange contracts utilize a financial intermediary, exchange, or clearinghouse to enter, execute, or clear the transactions. Certain over-the-counter and exchange contracts contain contractual rights of setoff through master netting arrangements, derivative clearing agreements, and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency, or other conditions.
In general, most over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral for over-the-counter and exchange contracts include cash, letters of credit, and in some cases other forms of security, none of which are subject to restrictions. Cash collateral is used in the table below to offset derivative assets and liabilities. Certain accounts receivable and accounts payable recognized on the Companies’ Consolidated Balance Sheets, as well as letters of credit and other forms of security, all of which are not included in the tables below, are subject to offset under master netting or similar arrangements and would reduce the net exposure.
Balance Sheet Presentation
The tables below present Dominion’s derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
Interest rate contracts:
Over-the-counter
Commodity contracts:
Exchange
Total derivatives, subject to a master netting or similar arrangement
Total derivatives, not subject to a master netting or similar arrangement
Total
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(millions)
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Volumes
The following table presents the volume of Dominion’s derivative activity as of June 30, 2014. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.
Natural Gas (bcf):
Fixed price(1)
Basis
Electricity (MWh):
Fixed price
Capacity (MW)
Liquids (Gal)(2)
Ineffectiveness and AOCI
For the three and six months ended June 30, 2014 and 2013, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness were not material. Amounts excluded from the assessment of effectiveness include gains or losses attributable to changes in the time value of options and changes in the differences between spot prices and forward prices.
The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion’s Consolidated Balance Sheet at June 30, 2014:
Commodities:
Gas
Electricity
The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., anticipated sales) in earnings, thereby achieving the realization of prices contemplated by the underlying risk management strategies and will vary from the expected amounts presented above as a result of changes in market prices and interest rates.
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Fair Value and Gains and Losses on Derivative Instruments
The following table presents the fair values of Dominion’s derivatives and where they are presented in its Consolidated Balance Sheets:
June 30, 2014
Total current derivative assets(1)
Noncurrent Assets
Total noncurrent derivative assets(2)
Total derivative assets
LIABILITIES
Total current derivative liabilities
Noncurrent Liabilities
Interest Rate
Total noncurrent derivative liabilities(3)
Total derivative liabilities
December 31, 2013
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The following tables present the gains and losses on Dominion's derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:
Derivatives in cash flow hedging relationships
Derivative Type and Location of Gains (Losses)
Commodity:
Total commodity
Interest rate(3)
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Derivatives not designated as hedging instruments
The tables below present Virginia Power’s derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
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The following table presents the volume of Virginia Power’s derivative activity as of June 30, 2014. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.
Ineffectiveness
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The following table presents the fair values of Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets:
Total current derivative liabilities(2)
Total noncurrent derivatives liabilities (3)
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The following tables present the gains and losses on Virginia Power’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:
Commodity(2)
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The tables below present Dominion Gas' derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting.
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The following table presents the volume of Dominion Gas’ derivative activity as of June 30, 2014. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.
NGLs (Gal)
For the three and six months ended June 30, 2014 and 2013, gains or losses on hedging instruments determined to be ineffective were not material.
The following table presents selected information related to losses on cash flow hedges included in AOCI in Dominion Gas' Consolidated Balance Sheet at June 30, 2014:
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The following tables present the fair values of Dominion Gas’ commodity and interest rate derivatives and where they are presented in its Consolidated Balance Sheets:
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The following table presents the gains and losses on Dominion Gas’ derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:
Interest rate(2)
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Note 10. Investments
Equity and Debt Securities
Rabbi Trust Securities
Marketable equity and debt securities and cash equivalents held in Dominion’s rabbi trusts and classified as trading totaled $109 million and $107 million at June 30, 2014 and December 31, 2013, respectively. Cost method investments held in Dominion’s rabbi trusts totaled $8 million and $10 million at June 30, 2014 and December 31, 2013, respectively.
Decommissioning Trust Securities
Dominion holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Dominion’s decommissioning trust funds are summarized below:
Marketable equity securities:
Marketable debt securities:
Corporate bonds
Cost method investments
Cash equivalents and other(2)
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The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2014 by contractual maturity is as follows:
Due in one year or less
Due after one year through five years
Due after five years through ten years
Due after ten years
Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.
Proceeds from sales
Realized gains(1)
Realized losses(1)
Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds for Dominion were not material for the three and six months ended June 30, 2014 and 2013.
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Virginia Power holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Virginia Power’s decommissioning trust funds are summarized below:
The fair value of Virginia Power’s marketable debt securities at June 30, 2014 by contractual maturity is as follows:
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Presented below is selected information regarding Virginia Power’s marketable equity and debt securities.
Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds for Virginia Power were not material for the three and six months ended June 30, 2014 and 2013.
Equity Method Investment
Dominion Gas accounts for the following investment under the equity method of accounting:
Company
Dominion Gas’ equity earnings on this investment totaled $13 million for both the six months ended June 30, 2014 and 2013. Dominion Gas received distributions from this investment of $5 million for both the six months ended June 30, 2014 and 2013. As of June 30, 2014 and December 31, 2013, the carrying amount of Dominion Gas' investment exceeded its share of underlying equity in net assets by approximately $9 million and $8 million, respectively. The differences reflect equity method goodwill and are not being amortized.
In December 2012, Dominion formed Blue Racer with Caiman to provide midstream services to natural gas producers operating in the Utica Shale region in Ohio and portions of Pennsylvania. Blue Racer is an equal partnership between Dominion and Caiman, with Dominion contributing midstream assets and Caiman contributing private equity capital. In June 2014, Blue Racer achieved equalization.
In March 2013, Dominion Gas sold Line TL-404 to an affiliate, that subsequently sold Line TL-404 to Blue Racer for cash proceeds of approximately $47 million. The sale resulted in a gain of approximately $25 million ($14 million after-tax) net of a $2 million write-off of goodwill, and is included in other operations and maintenance expense in both Dominion Gas' and Dominion’s Consolidated Statement of Income.
Dominion NGL Pipelines, LLC was contributed in January 2014 by Dominion to Blue Racer, prior to commencement of service, resulting in an increased equity method investment of $155 million, including $6 million of goodwill allocated from Dominion's goodwill balance to its equity method investment in Blue Racer.
In March 2014, Dominion Gas sold the Northern System to an affiliate, that subsequently sold the Northern System to Blue Racer for consideration of approximately $84 million. Dominion’ Gas’ consideration consisted of $17 million in cash proceeds and the extinguishment of affiliated current borrowings of $67 million and Dominion’s consideration consisted of cash proceeds of approximately $84 million. The sale resulted in a gain of approximately $59 million ($35 million after-tax for Dominion Gas and $34 million after-tax for Dominion) net of a $3 million write-off of goodwill, and is included in other operations and maintenance expense in both Dominion Gas’ and Dominion’s Consolidated Statement of Income.
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Note 11. Regulatory Assets and Liabilities
Regulatory assets and liabilities include the following:
Regulatory assets:
Deferred cost of fuel used in electric generation(1)
Deferred rate adjustment clause costs(2)
Deferred nuclear refueling outage costs(3)
Unrecovered gas cost(4)
Derivatives(5)
Regulatory assets-current(6)
Unrecognized pension and other postretirement benefit costs(7)
Income taxes recoverable through future rates(8)
Regulatory assets-non-current
Total regulatory assets
Regulatory liabilities:
PIPP(9)
Regulatory liabilities-current(10)
Provision for future cost of removal and AROs(11)
Decommissioning trust(12)
Regulatory liabilities-non-current
Total regulatory liabilities
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Provision for future cost of removal(11)
Unrecovered gas costs(4)
Bad debt tracker(13)
Other postretirement benefit costs(14)
Regulatory liabilities-non-current(15)
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At June 30, 2014, approximately $136 million of Dominion’s, $107 million of Virginia Power’s and $18 million of Dominion Gas’ regulatory assets represented past expenditures on which they do not currently earn a return. These expenditures are expected to be recovered within the next year.
Note 12. Regulatory Matters
Regulatory Matters Involving Potential Loss Contingencies
As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For matters for which the Companies cannot estimate a range of possible loss, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters for which the Companies are 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. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations.
FERC - Electric
Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Dominion’s merchant generators sell electricity in the state of Georgia and in the PJM, MISO and ISO-NE regions under Dominion’s market-based sales tariffs authorized by FERC. Virginia Power purchases and, under its FERC market-based rate authority, sells electricity in the wholesale market. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power’s service territory. Any such sales would be voluntary.
Rates
In April 2008, FERC granted an application for Virginia Power’s electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE of 11.4%, effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its growing investment in electric transmission infrastructure.
In March 2010, ODEC and NCEMC filed a complaint with FERC against Virginia Power claiming that approximately $223 million in transmission costs related to specific projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power’s transmission formula rate. In October 2010, FERC issued an order dismissing the complaint in part and established hearings and settlement procedures on the remaining part of the complaint. In February 2012, Virginia Power submitted to FERC a settlement agreement to resolve all issues set for hearing. The settlement was accepted by FERC in May 2012 and provides for payment by Virginia Power to the transmission customer parties collectively of $250,000 per year for ten years and resolves all matters other than allocation of the incremental cost of certain underground transmission facilities.
In March 2014, FERC issued an order excluding from Virginia Power’s transmission rates for wholesale transmission customers located outside Virginia the incremental costs of undergrounding certain transmission line projects. FERC found it is not just and reasonable for non-Virginia wholesale transmission customers to be allocated the incremental costs of undergrounding the facilities because the projects are a direct result of Virginia legislation and Virginia Commission pilot programs intended to benefit the citizens of Virginia. The order is retroactively effective as of March 2010 and will cause the reallocation of the costs charged to wholesale transmission customers with loads outside Virginia to wholesale transmission customers with loads in Virginia. FERC determined that there was not sufficient evidence on the record to determine the magnitude of the underground increment and ordered a hearing to determine the appropriate amount of undergrounding cost to
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be allocated to each wholesale transmission customer in Virginia. The hearing has been held in abeyance pending the outcome of an ongoing settlement proceeding, as ordered by FERC. While Virginia Power cannot predict the outcome of the hearing and settlement proceedings, it is not expected to have a material effect on results of operations.
Other Regulatory Matters
Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 13 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, Note 12 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014, Note 12 in Exhibit 99.11(b) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014 and Note 11 in Exhibit 99.11(c) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014.
Virginia Regulation
Virginia Fuel Expenses
In May 2014, Virginia Power submitted its annual fuel factor filing to the Virginia Commission to recover an estimated $1.9 billion in Virginia jurisdictional projected fuel expense for the rate year beginning July 1, 2014. Virginia Power also offered to defer recovery of 50% of its total estimated $268 million jurisdictional deferred fuel balance to the 2015-2016 fuel year, thereby recovering $134 million of its jurisdictional deferred fuel balance for the rate year beginning July 1, 2014. In May 2014, the Virginia Commission issued an order approving the increased fuel rate on an interim basis effective July 1, 2014. This case is pending.
Rate Adjustment Clauses
Below are developments to significant riders associated with various Virginia Power projects:
Electric Transmission Projects
In April 2014, the Virginia Commission issued an order granting Virginia Power a CPCN to rebuild within existing rights-of-way its 500-kV Loudoun-Pleasant View transmission line in Loudoun County at an estimated cost of approximately $31 million.
North Anna COL
Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna. If Virginia Power decides to build a new unit, it must first receive a COL from the NRC, approval of the Virginia Commission and certain environmental permits and other approvals. In April 2013, Virginia Power decided to replace the reactor design previously selected for a potential unit with ESBWR technology. Virginia Power filed the first of its two-part amendment to the COL application with the NRC in July 2013 to reflect the ESBWR technology and filed the second part of the amendment in December 2013. The COL is expected in 2016. Virginia Power has not yet committed to building a new nuclear unit at North Anna.
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In February 2014, BREDL filed a petition with the NRC seeking to stay final decision making in the COL proceeding until a rulemaking petition filed by a number of environmental groups several weeks earlier is resolved. The suspension request and underlying petition for rulemaking are based on analyses of the consequences of a spent fuel pool fire, but none of the analyses relates specifically to the ESBWR design. The NRC denied the petition in July 2014. Substantially identical suspension petitions and contentions were filed by various intervenor groups in other licensing proceedings pending before the NRC. In March 2014, BREDL filed a motion to reopen the COL proceeding on seismic issues under a previous ruling of the ASLB. No other issues were raised by BREDL in its filing. In June 2014, the ASLB denied BREDL’s motion to reopen the COL proceeding. BREDL did not appeal the ASLB’s decision, and under a previous ruling of the NRC, the contested portion of the COL proceeding remains terminated.
North Anna and Offshore Wind Legislation
In April 2014 legislation was enacted in Virginia that permits Virginia Power to recover 70% of the costs previously deferred or capitalized related to the development of a third nuclear unit located at North Anna and offshore wind facilities through December 31, 2013 as part of the 2013 and 2014 base rates. Virginia Power has deferred or capitalized costs totaling approximately $577 million for these projects as of December 31, 2013, substantially all of which relate to North Anna. For the 70% portion of these previously deferred or capitalized costs allocable to customers in Virginia, Virginia Power will recognize such amounts that are now recoverable in 2013 and 2014 base rates as charges against net income beginning in the second quarter of 2014 and for the remainder of the year. In the second quarter of 2014, Virginia Power recognized a $287 million ($191 million after-tax) charge against income representing the cumulative recovery of costs from January 2013 through June 2014 and will recognize additional charges of approximately $87 million ($57 million after-tax) ratably during the remainder of 2014. The remaining deferred or capitalized costs, as well as costs incurred after December 31, 2013, continue to be eligible for inclusion in a future rate adjustment clause.
North Carolina Regulation
In December 2012, the North Carolina Commission approved a $36 million increase in Virginia Power’s annual non-fuel base revenues based on an authorized ROE of 10.2%, and a $14 million decrease in annual base fuel revenues for a combined total base revenue increase of $22 million. These rate changes became effective on January 1, 2013 and were appealed to the North Carolina Supreme Court by multiple parties. In June 2014, the Supreme Court of North Carolina issued an opinion reversing the portion of the North Carolina Commission’s December 2012 order from Virginia Power’s 2012 base rate case approving a 10.2% ROE for Virginia Power, and remanding the case to the North Carolina Commission for additional findings of fact in light of a 2013 opinion issued after the North Carolina Commission’s order. This case is pending.
Ohio Regulation
PIR Program
In 2008, East Ohio began PIR, aimed at replacing more than 20% of its pipeline. In May 2014, PIR cost recovery rates became effective as approved by the Ohio Commission in April 2014. The approval includes a revenue requirement of $89 million, which represents an approximately $22 million increase over the previous year.
AMR Program
In 2007, East Ohio began installing automated meter reading technology for its 1.2 million customers in Ohio. In May 2014, AMR cost recovery rates became effective as approved by the Ohio Commission in April 2014. The approval includes a revenue requirement of $8 million, which represents an approximately $3 million increase over the previous year.
Ohio enacted utility reform legislation under House Bill 95, which became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date cost levels when filing rate cases. It also allows gas companies to seek approval of capital expenditure plans under which gas companies can recognize carrying costs on associated capital investments placed in service and can defer the carrying costs plus depreciation and property tax expenses for recovery from ratepayers in the future.
In July 2014, the Ohio Commission approved East Ohio’s application requesting authority to implement a capital expenditure program for 2014 capital expenditures totaling $110 million.
PIPP Plus Program
Under the Ohio PIPP Plus Program, eligible customers can make reduced payments based on their ability to pay their bill. The difference between the customer’s total bill and the PIPP payment plan amount is deferred and collected under the PIPP Rider in accordance with the rules of the Ohio Commission. In July 2014, East Ohio’s annual update of the PIPP Rider was automatically approved by the Ohio Commission after a 45-day waiting period from the date of the filing. The increased rider rate reflects the refund over the next year of an over-recovery of accumulated arrearages of approximately $82 million as of March 31, 2014, net of projected deferred program costs of approximately $96 million for the period from April 2014 through June 2015.
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East Ohio has approval for a UEX Rider through which it recovers the bad debt expense of most customers not participating in the PIPP Plus Program. The UEX Rider is adjusted annually to achieve dollar for dollar recovery of East Ohio’s actual write-offs of uncollectible amounts. In July 2014, the Ohio Commission approved a decrease to East Ohio’s UEX Rider, which reflects the elimination of the over-recovered balance of accumulated bad debt expense of approximately $8 million as of March 31, 2014, and recovery of prospective bad debt expense projected to total approximately $25 million for the twelve-month period from April 2014 to March 2015.
Note 13. Variable Interest Entities
As discussed in Note 15 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 14 in Exhibit 99.11(b) to Dominion Gas' Current Report on Form 8-K dated June 26, 2014, certain variable pricing terms in some of the Companies’ contracts cause them to be considered variable interests in the counterparties.
Virginia Power has long-term power and capacity contracts with four non-utility generators with an aggregate summer generation capacity of approximately 870 MW. These contracts contain certain variable pricing mechanisms in the form of partial fuel reimbursement that Virginia Power considers to be variable interests. After an evaluation of the information provided by these entities, Virginia Power was unable to determine whether they were VIEs. However, the information they provided, as well as Virginia Power's knowledge of generation facilities in Virginia, enabled Virginia Power to conclude that, if they were VIEs, it would not be the primary beneficiary. This conclusion reflects Virginia Power's determination that its variable interests do not convey the power to direct the most significant activities that impact the economic performance of the entities during the remaining terms of Virginia Power's contracts and for the years the entities are expected to operate after its contractual relationships expire. The contracts expire at various dates ranging from 2015 to 2021. Virginia Power is not subject to any risk of loss from these potential VIEs other than its remaining purchase commitments which totaled $807 million as of June 30, 2014. Virginia Power paid $55 million and $53 million for electric capacity and $33 million and $26 million for electric energy to these entities in the three months ended June 30, 2014 and 2013, respectively. Virginia Power paid $111 million and $108 million for electric capacity and $87 million and $46 million for electric energy to these entities in the six months ended June 30, 2014 and 2013, respectively.
Virginia Power and Dominion Gas purchased shared services from DRS, an affiliated VIE, of approximately $106 million and and $26 million for the three months ended June 30, 2014, $83 million and $25 million for the three months ended June 30, 2013, $214 million and $52 million for the six months ended June 30, 2014, and $160 million and $51 million for the six months ended June 30, 2013, respectively. Virginia Power and Dominion Gas determined that each is not the most closely associated entity with DRS and therefore neither is the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Virginia Power and Dominion Gas. Virginia Power and Dominion Gas have no obligation to absorb more than their allocated shares of DRS costs.
Note 14. Significant Financing Transactions
Credit Facilities and Short-term Debt
The Companies use short-term debt to fund working capital requirements and as a bridge to long-term debt financings. The levels of borrowing may vary significantly during the course of the year, depending upon the timing and amount of cash requirements not satisfied by cash from operations. In addition, Dominion utilizes cash and letters of credit to fund collateral requirements. Collateral requirements are impacted by commodity prices, hedging levels, Dominion’s credit ratings and the credit quality of its counterparties.
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At June 30, 2014, Dominion’s commercial paper and letters of credit outstanding, as well as its capacity available under credit facilities, were as follows:
Joint revolving credit facility(1)
Joint revolving credit facility(2)
Virginia Power’s short-term financing is supported by two joint revolving credit facilities with Dominion and Dominion Gas. These credit facilities are being used for working capital, as support for the combined commercial paper programs of Dominion and Virginia Power and for other general corporate purposes.
At June 30, 2014, Virginia Power’s share of commercial paper and letters of credit outstanding, as well as its capacity available under its joint credit facilities with Dominion and Dominion Gas were as follows:
In addition to the credit facility commitments mentioned above, Virginia Power also has a $120 million credit facility. In May 2014, this credit facility was amended and restated and the maturity date was extended from September 2018 to April 2019. As of June 30, 2014, this facility supports approximately $119 million of certain variable rate tax-exempt financings of Virginia Power.
Dominion Gas’ short-term financing is supported by the two joint revolving credit facilities discussed above with Dominion and Virginia Power, to which Dominion Gas was added as a borrower in May 2014.
Dominion Gas’ current sub-limit under the $4 billion credit facility is $500 million, all of which is currently available, and can be increased or decreased multiple times per year, up to a maximum of $1 billion. Dominion Gas’ current sub-limit under the $500 million credit facility is $0 and can also be increased or decreased multiple times per year. The maturity date for both facilities is April 2019.
Long-term Debt
In February 2014, Virginia Power issued $350 million of 3.45% senior notes, and $400 million of 4.45% senior notes, that mature in 2024, and 2044, respectively.
In March 2014, Dominion issued $400 million of 1.25% senior notes that mature in 2017.
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In April 2014, Virginia Power redeemed the $10 million 2.5% and the $30 million 2.5% Industrial Development Authority of the Town of Louisa, Virginia Solid Waste and Sewage Disposal Revenue Bonds, Series 1997A and 2000A, that would otherwise have matured in April 2022 and September 2030, respectively.
In June 2014, Dominion Gas commenced an offer to exchange $1.2 billion principal amount of unsecured senior notes that were issued in a private placement in October 2013. The exchange offer satisfies Dominion Gas' obligations under a registration rights agreement entered into in connection with the issuance of the Dominion Gas 2013 Senior Notes. The exchange offer does not represent a new financing transaction and there will be no proceeds to Dominion Gas when the offer settles, which is expected to occur in August 2014.
Convertible Securities
At June 30, 2014, Dominion had $36 million of outstanding contingent convertible senior notes that are convertible by holders into a combination of cash and shares of Dominion’s common stock under certain circumstances. The conversion feature requires that the principal amount of each note be repaid in cash, while amounts payable in excess of the principal amount will be paid in common stock. The conversion rate is subject to adjustment upon certain events such as subdivisions, splits, combinations of common stock or the issuance to all common stock holders of certain common stock rights, warrants or options and certain dividend increases. As of June 30, 2014, the conversion rate had been adjusted, primarily due to individual dividend payments above the level paid at issuance, to 30.1180 shares of common stock per $1,000 principal amount of senior notes, which represents a conversion price of $33.20. If the outstanding notes as of June 30, 2014 were all converted, it would result in the issuance of approximately 550,000 additional shares of common stock.
The senior notes are eligible for conversion during any calendar quarter when the closing price of Dominion’s common stock was equal to or higher than 120% of the conversion price for at least 20 out of the last 30 consecutive trading days of the preceding quarter, the notes are called for redemption by Dominion and upon the occurrence of certain other conditions. During the first and second quarters of 2014, the senior notes were eligible for conversion and approximately $7 million of the notes were converted by holders into $7 million of common stock. The senior notes are eligible for conversion during the third quarter of 2014.
Preferred Stock
In February 2014, Virginia Power provided irrevocable notice to redeem all 1,250,000 outstanding shares of its Flex MMP Stock. In March 2014, Virginia Power redeemed the stock at a price of $100 per share plus accumulated and unpaid dividends at a rate reset in March 2011 of 6.12%. Dividends ceased accumulating on the stock upon payment of the redemption price, thus the rate was not reset in March 2014.
Issuance of Common Stock
Dominion maintains Dominion Direct® and a number of employee savings plans through which contributions may be invested in Dominion’s common stock. These shares may either be newly issued or purchased on the open market with proceeds contributed to these plans. In January 2014, Dominion began purchasing its common stock on the open market for these plans. In April 2014, Dominion began issuing new common shares for these direct stock purchase plans.
Remarketable Subordinated Notes
In July 2014, Dominion issued $1 billion of 2014 Series A 6.375% Equity Units, initially in the form of Corporate Units. The Corporate Units are listed on the NYSE under the symbol DCUC.
Each Corporate Unit consists of a stock purchase contract and 1/20 interest in a RSN issued by Dominion. The stock purchase contracts obligate the holders to purchase shares of Dominion common stock at a future settlement date prior to the relevant RSN maturity date. The purchase price to be paid under the stock purchase contracts is $50 per Corporate Unit and the number of shares to be purchased will be determined under a formula based upon the average closing price of Dominion common stock near the settlement date. The RSNs are pledged as collateral to secure the purchase of common stock under the related stock purchase contracts.
Dominion makes quarterly interest payments on the RSNs and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. Dominion may defer payments on the stock purchase contracts and the RSNs for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, Dominion may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Also, during the deferral period, Dominion may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs.
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Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Dominion will issue between 11.5 million and 14.3 million shares of its common stock in July 2017. A total of 17.75 million shares of Dominion’s common stock has been reserved for issuance in connection with the stock purchase contracts.
Selected information about Dominion’s 2014 Equity Units is presented below:
Issuance Date
7/1/2014
Note 15. Commitments and Contingencies
As a result of issues generated in the ordinary course of business, the Companies are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), 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, and/or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such matters that the Companies 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 the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations for which the Companies are 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. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. 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, involves elements of judgment and significant uncertainties and may not represent the Companies’ 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. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the Companies’ financial position, liquidity or results of operations.
Environmental Matters
The Companies are 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.
Air
The CAA, as amended, is a comprehensive program utilizing a broad range of regulatory tools to protect and preserve the nation’s air quality. At a minimum, 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. Many of the Companies’ facilities are subject to the CAA’s permitting and other requirements.
The EPA established CAIR with the intent to require significant reductions in SO2 and NOX emissions from electric generating facilities. In July 2008, the U.S. Court of Appeals for the D.C. Circuit issued a ruling vacating CAIR. In December 2008, the Court denied rehearing, but also issued a decision to remand CAIR to the EPA. In July 2011, the EPA issued a replacement rule for CAIR, called CSAPR, that required 28 states to reduce power plant emissions that cross state lines. CSAPR established new SO2 and NOx emissions cap and trade programs that were completely independent of the current ARP. Specifically, CSAPR required reductions in SO2 and NOx emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NOx emissions caps, NOx emissions caps during the ozone season (May 1 through September 30) and annual SO2 emission caps with differing requirements for two groups of affected states.
Following numerous petitions by industry participants for review and motions for stay, the U.S. Court of Appeals for the D.C. Circuit issued a ruling in December 2011 to stay CSAPR pending judicial review. A mandate vacating CSAPR was issued in February 2013. In March 2013, the EPA and several environmental groups filed petitions with the U.S. Supreme Court requesting review of the decision to vacate and remand CSAPR. In April 2014, the U.S. Supreme Court issued a decision upholding CSAPR by reversing and remanding the D.C. Circuit’s decision vacating the rule. The decision, however, did not lift the stay of CSAPR, and CAIR continues to remain in effect. In June 2014, the EPA filed a motion asking the U.S. Court of Appeals for the D.C. Circuit to lift the stay of CSAPR. Further, the EPA asked the court to toll the CSAPR compliance deadlines by three years, so that Phase 1 emissions budgets (which would have gone into effect in 2012 and 2013) would apply in 2015 and 2016, and Phase 2 emissions budgets would apply in 2017 and beyond. The cost to comply is not expected to be material. Future outcomes of any additional litigation and/or any action to issue a revised rule could affect the assessment regarding cost of compliance.
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In May 2012, the EPA issued final designations for the 75-ppb ozone air quality standard. A number of the Companies’ facilities are located within areas impacted by this standard. As part of the standard, states will be required to develop and implement plans to address sources emitting pollutants which contribute to the formation of ozone. Until the states have developed implementation plans, Dominion is unable to predict whether or to what extent the new rules will ultimately require additional controls.
In August 2010, the EPA issued revised National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. The rule was amended in March 2011 and January 2013. The rule establishes emission standards for control of hazardous air pollutants for engines at smaller facilities, known as area sources. As a result of these regulations, Dominion Gas installed emissions controls on several compressor engines. Dominion Gas has spent approximately $2 million to date and is evaluating further expenditures. Dominion Gas is unable to estimate the additional potential impacts on results of operations, financial condition and/or cash flows related to this matter.
In August 2012, the EPA issued the first NSPS impacting the natural gas production and gathering sectors and made revisions to the NSPS for natural gas processing and transmission facilities. These rules establish equipment performance specifications and emissions standards for control of volatile organic chemical emissions for natural gas production wells, tanks, pneumatic controllers, and compressors in the upstream sector. Compliance with these rules is required for installations and wells constructed or reconstructed after August 23, 2011. The cost to comply with the NSPS will depend on the number of new wells and new equipment installations subject to the rule; therefore, Dominion Gas is unable to estimate the potential impacts on results of operations, financial condition and/or cash flows related to this matter.
Water
The CWA, as amended, is a comprehensive program utilizing a broad range of regulatory tools including a permit program to authorize and regulate discharges to surface waters with strong enforcement mechanisms. Dominion and Virginia Power must comply with applicable aspects of the CWA program at their operating facilities.
In May 2014, the EPA published final regulations under Section 316(b) of the CWA that govern existing facilities and new units at existing facilities that employ a cooling water intake structure and that have flow levels exceeding a minimum threshold. The rule establishes a national standard for impingement based on seven compliance options, but forgoes the creation of a single technology standard for entrainment. Instead, the EPA has delegated entrainment technology decisions to state regulators. State regulators are to make case-by-case entrainment technology determinations after an examination of five mandatory facility-specific factors, including a social cost-benefit test, and six optional facility-specific factors. The rule governs all electric generating stations with water withdrawals above two MGD, with a heightened entrainment analysis for those facilities over 125 MGD. Dominion and Virginia Power have 14 and 11 facilities, respectively, that may be subject to the final regulations. Dominion anticipates that it will have to install impingement control technologies at many of these stations that have once-through cooling systems. Dominion and Virginia Power are currently evaluating the need or potential for entrainment controls under the final rule as these decisions will be made on a case-by-case basis after a thorough review of detailed biological, technology, cost and benefit studies. While the impacts of this rule could be material to Dominion’s and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory framework in Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts for Virginia Power.
In September 2010, Millstone’s NPDES permit was reissued under the CWA. The conditions of the permit require an evaluation of control technologies that could result in additional expenditures in the future. The report summarizing the results of the evaluation was submitted in August 2012 and is under review by the Connecticut Department of Energy and Environmental Protection. Dominion cannot currently predict the outcome of this review. In October 2010, the permit issuance was appealed to the state court by a private plaintiff. The permit is expected to remain in effect during the appeal. Dominion is currently unable to make an estimate of the potential financial statement impacts related to this matter.
Solid and Hazardous Waste
The CERCLA, as amended, provides for immediate response and removal actions coordinated by the EPA in the event of threatened releases of hazardous substances into the environment and authorizes the U.S. government either to clean up sites at which hazardous substances have created actual or potential environmental hazards or to order persons responsible for the situation to do so. Under the CERCLA, as amended, generators and transporters of hazardous substances, as well as past and present owners and operators of contaminated sites, can be jointly, severally and strictly liable for the cost of cleanup. These potentially responsible parties can be ordered to perform a cleanup, be sued for costs associated with an EPA-directed cleanup, voluntarily settle with the U.S. government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.
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From time to time, Dominion, Virginia Power, or Dominion Gas may be identified as a potentially responsible party to a Superfund site. The EPA (or a state) can either allow such a party to conduct and pay for a remedial investigation, feasibility study and remedial action or conduct the remedial investigation and action itself and then seek reimbursement from the potentially responsible parties. Each party can be held jointly, severally and strictly liable for the cleanup costs. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion, Virginia Power, or Dominion Gas may be responsible for the costs of remedial investigation and actions under the Superfund law or other laws or regulations regarding the remediation of waste. Except as noted below, the Companies do not believe this will have a material effect on results of operations, financial condition and/or cash flows.
In September 2011, the EPA issued a UAO to Virginia Power and 22 other parties, ordering specific remedial action of certain areas at the Ward Transformer Superfund site located in Raleigh, North Carolina. Virginia Power does not believe it is a liable party under CERCLA based on its alleged connection to the site. In November 2011, Virginia Power and a number of other parties notified the EPA that they are declining to undertake the work set forth in the UAO.
The EPA may seek to enforce a UAO in court pursuant to its enforcement authority under CERCLA, and may seek recovery of its costs in undertaking removal or remedial action. If the court determines that a respondent failed to comply with the UAO without sufficient cause, the EPA may also seek civil penalties of up to $37,500 per day for the violation and punitive damages of up to three times the costs incurred by the EPA as a result of the party's failure to comply with the UAO. Virginia Power is currently unable to make an estimate of the potential financial statement impacts related to the Ward Transformer matter.
Dominion has determined that it is associated with 17 former manufactured gas plant sites, three of which pertain to Virginia Power, and 12 of which pertain to Dominion Gas. Studies conducted by other utilities at their former manufactured gas plant sites have indicated that those sites contain coal tar and other potentially harmful materials. None of the former sites with which the Companies are associated is under investigation by any state or federal environmental agency. At one of the former sites, Dominion is conducting a state-approved post-closure groundwater monitoring program and an environmental land use restriction has been recorded. Another site has been accepted into a state-based voluntary remediation program. Virginia Power is currently evaluating the nature and extent of the contamination from this site as well as potential remedial options. Preliminary costs for options under evaluation for the site range from $1 million to $22 million. Due to the uncertainty surrounding the other sites, the Companies are unable to make an estimate of the potential financial statement impacts.
Climate Change Legislation and Regulation
In October 2013, the U.S. Supreme Court granted petitions filed by several industry groups, states, and the U.S. Chamber of Commerce seeking review of the D.C. Circuit Court's June 2012 decision upholding the EPA’s regulation of GHG emissions from stationary sources under the CAA's permitting programs. In June 2014, the U.S. Supreme Court ruled that the EPA lacked the authority under the CAA to require PSD or Title V permits for stationary sources based solely on GHG emissions. However, the Court upheld the EPA’s ability to require BACT for GHG for sources that are otherwise subject to PSD or Title V permitting for conventional pollutants. Due to uncertainty regarding what actions states may take to amend their existing regulations and what action the EPA ultimately takes to address the Court ruling, the Companies cannot predict the impact to operations at this time.
In July 2011, the EPA signed a final rule deferring the need for PSD and Title V permitting for CO2 emissions for biomass projects. This rule temporarily deferred for a period of up to 3 years the consideration of CO2 emissions from biomass projects when determining whether a stationary source meets the PSD and Title V applicability thresholds, including those for the application of BACT. In July 2013, the U.S. Court of Appeals for the D.C. Circuit vacated this rule; however, a mandate making this decision effective has not been issued. Virginia Power converted three coal-fired generating stations, Altavista, Hopewell and Southampton, to biomass during the CO2 deferral period. It is unclear how the court's decision will affect biomass sources that were permitted during the deferral period; however, the expenditures to comply with any new requirements could be material.
Legal Matters
Dominion Gas is the defendant in a number of lawsuits and claims involving unrelated incidents of property damage and personal injury. Due to the uncertainty surrounding these matters, Dominion Gas is unable to make an estimate of the potential financial statement impacts; however, they could have a material impact on results of operations, financial condition and/or cash flows.
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Following the completion of the Appalachian Gateway Project in 2012, DTI received multiple change order requests and other claims for additional payments from a pipeline contractor for the project. In July 2013, DTI filed a complaint in U.S. District Court, Eastern District of Virginia for breach of contract, accounting and declaratory relief. The contractor filed a motion to dismiss, or in the alternative, a motion to transfer venue to Pennsylvania and/or West Virginia, where the pipelines were constructed. DTI filed an opposition to the contractor’s motion in August 2013. In November 2013, the court granted the contractor’s motion on the basis that DTI must first comply with the dispute resolution process. Pursuant to the ruling, DTI intends to mediate the matter. This case is pending. DTI has accrued a liability of approximately $6 million for this matter. Dominion Gas cannot currently estimate additional financial statement impacts, but there could be a material impact to its financial condition and/or cash flows.
In April 2013, Cove Point filed an application with the Maryland Commission for a CPCN to authorize the construction of an electric generating station needed to power the proposed liquefaction equipment. In May 2014, the Maryland Commission granted a CPCN authorizing the construction of such generating station. The CPCN is contingent upon Cove Point receiving FERC approval for the liquefaction project and will obligate Cove Point to make payments over time totaling approximately $48 million to the Maryland Strategic Energy Investments Fund and Maryland low income energy assistance programs. In June 2014, a party filed a notice of petition for judicial review of the CPCN with the Circuit Court for Baltimore City in Maryland. This matter is currently pending.
Nuclear Matters
In March 2011, a magnitude 9.0 earthquake and subsequent tsunami caused significant damage at the Fukushima Daiichi nuclear power station in northeast Japan. These events have resulted in significant nuclear safety reviews required by the NRC and industry groups such as INPO. Like other U.S. nuclear operators, Dominion has been gathering supporting data and participating in industry initiatives focused on the ability to respond to and mitigate the consequences of design-basis and beyond-design-basis events at its stations.
In July 2011, an NRC task force provided initial recommendations based on its review of the Fukushima Daiichi accident and in October 2011, the NRC staff prioritized these recommendations into Tiers 1, 2 and 3, with the Tier 1 recommendations consisting of actions which the staff determined should be started without unnecessary delay. In December 2011, the NRC Commissioners approved the agency staff's prioritization and recommendations, and that same month an appropriations act directed the NRC to require reevaluation of external hazards (not limited to seismic and flooding hazards) as soon as possible.
Based on the prioritized recommendations, in March 2012, the NRC issued orders and information requests requiring specific reviews and actions to all operating reactors, construction permit holders and combined license holders based on the lessons learned from the Fukushima Daiichi event. The orders applicable to Dominion require implementation of safety enhancements related to mitigation strategies to respond to extreme natural events resulting in the loss of power at plants, and enhancing spent fuel pool instrumentation. The orders require prompt implementation of the safety enhancements and completion of implementation within two refueling outages or by December 31, 2016, whichever comes first. Implementation of these enhancements is currently in progress. The information requests issued by the NRC request each reactor to reevaluate the seismic and flooding hazards at their site using present-day methods and information, conduct walkdowns of their facilities to ensure protection against the hazards in their current design basis, and to reevaluate their emergency communications systems and staffing levels. The updated seismic analyses are complete and Dominion and Virginia Power are discussing with the NRC any further actions that will be required for their plants. Dominion and Virginia Power do not currently expect that compliance with the NRC's March 2012 orders and information requests will materially impact their financial position, results of operations or cash flows during the approximately four-year implementation period. The NRC staff is evaluating the implementation of the longer-term Tier 2 and Tier 3 recommendations. Dominion and Virginia Power are currently unable to estimate the potential financial impacts related to compliance with Tier 2 and Tier 3 recommendations.
Spent Nuclear Fuel
Dominion and Virginia Power entered into contracts with the DOE for the disposal of spent nuclear fuel under provisions of the Nuclear Waste Policy Act of 1982. The DOE failed to begin accepting the spent fuel on January 31, 1998, the date provided by the Nuclear Waste Policy Act and by Dominion’s and Virginia Power's contracts with the DOE. Dominion and Virginia Power have previously received damages award payments and settlement payments related to these contracts and have entered into settlement agreements that resolved claims for damages incurred through December 31, 2010, and also provide for periodic payments after that date for damages incurred through December 31, 2013.
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In the second quarter of 2014, the government formally accepted offers of settlement from Virginia Power and Dominion to resolve claims for damages incurred at North Anna and Surry in the amount of approximately $27 million for the period of January 1, 2011 through December 31, 2012 and at Millstone in the amount of approximately $17 million for the period July 1, 2012 through June 30, 2013. Payment is expected by the third quarter of 2014. Dominion expects that the government will formally accept an offer of settlement for resolution of claims incurred at Kewaunee in the amount of approximately $5 million for the period January 1 through December 31, 2013, with payment expected in the third or fourth quarter of 2014.
By mutual agreement of the parties, the settlement agreements are extendable to provide for resolution of damages incurred after 2013. The settlement agreements for the Surry, North Anna and Millstone plants have been extended to provide for periodic payments for damages incurred through December 31, 2016. Possible extension of the Kewaunee settlement agreement is being evaluated.
Dominion and Virginia Power continue to recognize receivables for certain spent nuclear fuel-related costs that they believe are probable of recovery from the DOE. Dominion’s receivables for spent nuclear fuel-related costs totaled $92 million and $79 million at June 30, 2014 and December 31, 2013, respectively. Virginia Power’s receivables for spent nuclear fuel-related costs totaled $60 million and $50 million at June 30, 2014 and December 31, 2013, respectively.
Pursuant to a November 2013 decision of the U.S Court of Appeals for the D.C. Circuit, in January 2014, the Secretary of the DOE sent a recommendation to the U.S. Congress to adjust to zero the current fee of $1 per MWh for electricity paid by civilian nuclear power generators for disposal of spent nuclear fuel. The processes specified in the Nuclear Waste Policy Act for adjustment of the fee have been completed, and as of May 16, 2014, Dominion and Virginia Power are no longer required to pay the waste fee. In 2014, Dominion and Virginia Power recognized fees of $16 million and $10 million, respectively.
Dominion and Virginia Power will continue to manage their spent fuel until it is accepted by the DOE.
Guarantees
At June 30, 2014, Dominion had issued $69 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of June 30, 2014, Dominion’s exposure under these guarantees was $54 million, primarily related to certain reserve requirements associated with non-recourse financing.
In addition to the above guarantees, Dominion and its partners, Shell and BP, may be required to make additional periodic equity contributions to NedPower and Fowler Ridge in connection with certain funding requirements associated with their respective non-recourse financings. As of June 30, 2014, Dominion’s maximum remaining cumulative exposure under these equity funding agreements was $80 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million.
Dominion also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. To the extent that a liability subject to a guarantee has been incurred by one of Dominion’s consolidated subsidiaries, that liability is included in the Consolidated Financial Statements. Dominion is not required to recognize liabilities for guarantees issued on behalf of its subsidiaries unless it becomes probable that it will have to perform under the guarantees. Terms of the guarantees typically end once obligations have been paid. Dominion currently believes it is unlikely that it would be required to perform or otherwise incur any losses associated with guarantees of its subsidiaries’ obligations.
At June 30, 2014, Dominion had issued the following subsidiary guarantees:
Subsidiary debt(2)
Commodity transactions(3)
Nuclear obligations(4)
Cove Point(5)
Solar(6)
Other(7)
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Surety Bonds and Letters of Credit
As of June 30, 2014, Dominion had purchased $129 million of surety bonds, including $60 million at Virginia Power and $31 million at Dominion Gas, and authorized the issuance of letters of credit by financial institutions of $115 million, including $18 million at Virginia Power, to facilitate commercial transactions by its subsidiaries with third parties. Under the terms of surety bonds, the Companies are obligated to indemnify the respective surety bond company for any amounts paid.
Note 16. Credit Risk
The Companies’ accounting policies for credit risk are discussed in Note 23 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 19 in Exhibit 99.11(b) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014.
At June 30, 2014, Dominion’s credit exposure totaled $122 million. Of this amount, investment grade counterparties, including those internally rated, represented 59%. No counterparty exposure exceeded 10% of Dominion’s total exposure.
Credit-Related Contingent Provisions
The majority of Dominion’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion to provide collateral upon the occurrence of specific events, primarily a credit rating downgrade. If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered as of June 30, 2014 and December 31, 2013, Dominion would have been required to post an additional $79 million and $146 million, respectively, of collateral to its counterparties. The collateral that would be required to be posted includes the impacts of any offsetting asset positions and any amounts already posted for derivatives, non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. Dominion had posted approximately $5 million and $76 million in collateral at June 30, 2014 and December 31, 2013, respectively, related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The collateral posted includes any amounts paid related to non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. The aggregate fair value of all derivative instruments with credit-related contingent provisions that are in a liability position and not fully collateralized with cash as of June 30, 2014 and December 31, 2013 was $161 million and $169 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power and Dominion Gas were not material as of June 30, 2014 and December 31, 2013. See Note 9 for further information about derivative instruments.
In the second quarter of 2014, DTI provided service to 234 customers with approximately 94% of its storage and transportation revenue being provided through firm services. The ten largest customers provided approximately 42% of the total storage and transportation revenue and the 30 largest provided approximately 75% of the total storage and transportation revenue. Approximately 97% of the transmission capacity under contract on DTI’s pipeline is subscribed with long-term contracts (two years or greater). The remaining 3% is contracted on a year-to-year basis. Less than 1% of firm transportation capacity is currently unsubscribed. All storage services are subscribed under long-term contracts.
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East Ohio distributes natural gas to residential, commercial and industrial customers in Ohio using rates established by the Ohio Commission. Approximately 98% of East Ohio revenues are derived from its jurisdictional gas services. East Ohio’s bad debt risk is mitigated by the regulatory framework established by the Ohio Commission. See Note 12 for further information about Ohio’s PIPP and UEX Riders that mitigate East Ohio’s overall credit risk.
Note 17. Related Party Transactions
Virginia Power and Dominion Gas engage in related party transactions primarily with other Dominion subsidiaries (affiliates). Virginia Power’s and Dominion Gas’ 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. Virginia Power and Dominion Gas are included in Dominion’s consolidated federal income tax return. A discussion of significant related party transactions follows.
Transactions with Affiliates
Virginia Power transacts with affiliates for certain quantities of natural gas and other commodities in the ordinary course of business. Virginia Power also enters into certain commodity derivative contracts with affiliates. Virginia Power uses these contracts, which are principally comprised of commodity swaps, to manage commodity price risk associated with purchases of natural gas. See Note 9 for more information. As of June 30, 2014 and December 31, 2013, Virginia Power’s derivative assets and liabilities with affiliates were not material. Virginia Power participates in certain Dominion benefit plans. In Virginia Power’s Consolidated Balance Sheets at June 30, 2014 and December 31, 2013, amounts due to Dominion associated with these benefit plans included in other deferred credits and other liabilities were $182 million and $147 million, respectively, and amounts due from Dominion at June 30, 2014 included in other deferred charges and other assets were $16 million.
DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Virginia Power. In addition, Virginia Power provides certain services to affiliates, including charges for facilities and equipment usage.
Presented below are significant transactions with DRS and other affiliates:
Commodity purchases from affiliates
Services provided by affiliates(1)
Services provided to affiliates
Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. There were $97 million in short-term demand note borrowings from Dominion as of December 31, 2013. There were no short-term demand note borrowings as of June 30, 2014. Virginia Power had no outstanding borrowings, net of repayments under the Dominion money pool for its nonregulated subsidiaries as of June 30, 2014 and December 31, 2013. Interest charges related to Virginia Power’s borrowings from Dominion were not material for the three and six months ended June 30, 2014 and 2013.
Dominion Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Gas provides transportation and storage services to affiliates. Dominion Gas also enters into certain other contracts with affiliates, which are presented separately from contracts involving commodities or services. As of June 30, 2014 and December 31 2013, all of Dominion Gas’ commodity derivatives were with affiliates. See Note 9 for more information. Dominion Gas participates in certain Dominion benefit plans as described in Note 18. See Note 10 for information regarding sales of assets to an affiliate.
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Purchases of natural gas and transportation and storage services from affiliates
Sales of natural gas and transportation and storage services to affiliates
DRS and affiliates provide certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to affiliates, including technical services. The costs of these services follow:
Goods and services provided by Dominion Gas to affiliates
Goods and services provided by Dominion Gas to related parties
The following table presents affiliated and related party activity reflected in Dominion Gas’ Consolidated Balance Sheets:
Customer receivables from related parties
Imbalances receivable from affiliates(1)
Imbalances payable to affiliates(2)
Affiliated notes receivable(3)
Dominion Gas’ borrowings under the IRCA with Dominion totaled $1.5 billion as of June 30, 2014 and $1.3 billion as of December 31, 2013. Interest charges related to Dominion Gas’ total borrowings from Dominion were $1 million and $11 million for the three months ended June 30, 2014 and 2013, respectively, and $2 million and $21 million for the six months ended June 30, 2014 and 2013, respectively. Dominion Gas capitalized $5 million and $8 million of interest charges to property, plant and equipment for the three and six months ended June 30, 2013, respectively.
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Note 18. Employee Benefit Plans
The components of Dominion’s provision for net periodic benefit cost (credit) were as follows:
Three Months Ended June 30,
Service cost
Interest cost
Expected return on plan assets
Amortization of prior service cost (credit)
Amortization of net actuarial loss
Settlements and curtailments(1)
Net periodic benefit cost (credit)
Employer Contributions
During the six months ended June 30, 2014, Dominion made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs during the remainder of 2014.
Dominion Gas participates in certain Dominion benefit plans as described in Note 17 in Exhibit 99.11(b) to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014. At June 30, 2014 and December 31, 2013, Dominion Gas’ amounts due from Dominion associated with the Dominion Pension Plan and reflected in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were $595 million and $577 million, respectively. At June 30, 2014 and December 31, 2013, Dominion Gas’ amounts due to Dominion associated with the Dominion Retiree Health and Welfare Plan and reflected in other deferred credits and other liabilities in the Consolidated Balance Sheets were $11 million and $14 million, respectively.
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The components of Dominion Gas’ provision for net periodic benefit credit for employees represented by collective bargaining units were as follows:
Other Postretirement
Benefits
Amortization of prior service credit
Net periodic benefit credit
During the six months ended June 30, 2014, Dominion Gas made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion Gas expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs, for both employees represented by collective bargaining units and employees not represented by collective bargaining units, during the remainder of 2014.
Note 19. Operating Segments
The Companies are organized primarily on the basis of products and services sold in the U.S. A description of the operations included in the Companies’ primary operating segments is as follows:
Primary Operating Segment
Description of Operations
DominionGas
In addition to the operating segments above, the Companies also report a Corporate and Other segment.
The Corporate and Other Segment of Dominion includes its corporate, service company and other functions (including unallocated debt) and the net impact of operations that are discontinued or sold. In addition, Corporate and Other includes specific items attributable to Dominion’s operating segments that are not included in profit measures evaluated by executive management in assessing the segments’ performance or allocating resources among the segments.
In January 2014, Dominion announced it would exit the electric retail energy marketing business. Dominion completed the sale in March 2014. As a result, the earnings impact from the electric retail energy marketing business has been included in the Corporate and Other Segment of Dominion for 2014 first quarter results of operations.
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In the second quarter of 2013, Dominion commenced a repositioning of its producer services business, which aggregates natural gas supply, engages in natural gas trading and marketing activities and natural gas supply management and provides price risk management services to Dominion affiliates. The repositioning was completed in the first quarter of 2014 and resulted in the termination of natural gas trading and certain energy marketing activities. As a result, the earnings impact from natural gas trading and certain energy marketing activities has been included in the Corporate and Other Segment of Dominion for 2014.
In the six months ended June 30, 2014, Dominion reported an after-tax net expense of $430 million for specific items in the Corporate and Other segment, with $402 million of these net expenses attributable to its operating segments. In the six months ended June 30, 2013, Dominion reported an after-tax net expense of $134 million for specific items in the Corporate and Other segment, with $131 million of these net expenses attributable to its operating segments.
The net expense for specific items in 2014 primarily related to the impact of the following items:
The net expense for specific items in 2013 primarily related to the impact of the following items:
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The following table presents segment information pertaining to Dominion’s operations:
Total revenue from external customers
Intersegment revenue
Net income (loss) attributable to Dominion
Intersegment sales and transfers for Dominion are based on contractual arrangements and may result in intersegment profit or loss that is eliminated in consolidation.
The Corporate and Other Segment of Virginia Power primarily includes specific items attributable to its operating segments that are not included in profit measures evaluated by executive management in assessing the segments' performance or allocating resources among the segments.
In the six months ended June 30, 2014, Virginia Power reported an after-tax net expense of $181 million for specific items in the Corporate and Other segment, with $189 million of these net expenses attributable to its operating segments. In the six months ended June 30, 2013, Virginia Power reported an after-tax net expense of $5 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments.
The net expense for specific items in 2014 primarily related to the impact of the following item:
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The following table presents segment information pertaining to Virginia Power’s operations:
Net income (loss)
The Corporate and Other Segment of Dominion Gas primarily includes specific items attributable to Dominion Gas’ operating segment that are not included in profit measures evaluated by executive management in assessing the segment’s performance and the effect of certain items recorded at Dominion Gas as a result of Dominion’s basis in the net assets contributed.
In the six months ended June 30, 2014, Dominion Gas reported no amounts for specific items in the Corporate and Other segment. In the six months ended June 30, 2013, Dominion Gas reported an after-tax net expense of $41 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segment.
The net expenses for specific items in 2013 primarily related to the impact of the following items:
The following table presents segment information pertaining to Dominion Gas’ operations:
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
MD&A discusses Dominion’s and Virginia Power’s results of operations and general financial condition and Dominion Gas’ results of operations. MD&A should be read in conjunction with the Companies’ Consolidated Financial Statements. Dominion Gas meets the conditions to file under the reduced disclosure format, and therefore has omitted certain sections of MD&A.
Contents of MD&A
MD&A consists of the following information:
Forward-Looking Statements
This report contains statements concerning the Companies’ expectations, plans, objectives, future financial performance and other statements that are not historical facts. These statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. 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.
The Companies 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:
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Additionally, other risks that could cause actual results to differ from predicted results are set forth in Item 1A. Risk Factors in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, Exhibit 99.2 to Dominion Gas’ Current Report on Form 8-K dated June 26, 2014, and in Part II. Item 1A. Risk Factors in this report.
The Companies’ forward-looking statements are based on beliefs and assumptions using information available at the time the statements are made. The Companies caution the reader not to place undue reliance on their forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, differ materially from actual results. The Companies undertake no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.
Accounting Matters
Critical Accounting Policies and Estimates
As of June 30, 2014, there have been no significant changes with regard to the critical accounting policies and estimates disclosed in MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013. The policies disclosed included the accounting for regulated operations, AROs, income taxes, derivative contracts and other instruments at fair value, goodwill and long-lived asset impairment testing, employee benefit plans and unbilled revenue.
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Results of Operations
Presented below is a summary of Dominion’s consolidated results:
Second Quarter
Diluted EPS
Year-To-Date
Overview
Second Quarter 2014 vs. 2013
Net income attributable to Dominion decreased 21% primarily due to charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities. See Note 12 for further discussion of this matter. These decreases were partially offset by the absence of losses from discontinued operations related to Brayton Point and Kincaid, and the absence of impairment charges for certain natural gas infrastructure assets.
Year-To-Date 2014 vs. 2013
Net income attributable to Dominion decreased 23% primarily due to charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities, and the repositioning of Dominion’s producer services business which was completed in the first quarter of 2014. These decreases were partially offset by the absence of losses from discontinued operations related to Brayton Point and Kincaid, the impact of higher margins from merchant generation operations, and more favorable weather on electric utility operations.
Analysis of Consolidated Operations
Presented below are selected amounts related to Dominion’s results of operations:
Net revenue
An analysis of Dominion’s results of operations follows:
Net revenueincreased 3%, primarily reflecting:
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These increases were partially offset by:
Other operations and maintenance increased 28%, primarily reflecting:
Interest and related charges increased 12%, primarily due to higher long-term debt interest expense resulting from debt issuances in August and October 2013 and February and March 2014.
Income tax expense decreased 46%, primarily reflecting lower pre-tax income in 2014.
Loss from discontinued operations reflects the sale of Brayton Point and Kincaid in 2013.
Net revenue decreased 8%, primarily reflecting:
These decreases were partially offset by:
Other operations and maintenance increased 1%, primarily reflecting:
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Other income decreased 29%, primarily due to lower realized gains (net of investment income) on nuclear decommissioning trust funds ($26 million), a decrease in the equity component of AFUDC ($23 million) and an increase in donations expense ($9 million), partially offset by higher equity earnings primarily from Blue Racer ($18 million).
Income tax expense decreased 38%, primarily reflecting lower pre-tax income in 2014.
Segment Results of Operations
Segment results include the impact of intersegment revenues and expenses, which may result in intersegment profit and loss. Presented below is a summary of contributions by Dominion’s operating segments to net income attributable to Dominion:
(millions, except EPS)
DVP(1)
Dominion Generation(1)
Dominion Energy
Primary operating segments
Corporate and Other
Consolidated
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Presented below are selected operating statistics related to DVP’s operations:
Electricity delivered (million MWh)
Degree days (electric distribution service area):
Cooling
Heating
Average electric distribution customer accounts (thousands)(1)
Presented below, on an after-tax basis, are the key factors impacting DVP’s net income contribution:
2014 vs. 2013
Increase (Decrease)
Regulated electric sales:
Weather
FERC transmission equity return
Storm damage and service restoration
Share dilution
Change in net income contribution
Dominion Generation
Presented below are selected operating statistics related to Dominion Generation’s operations:
Electricity supplied (million MWh):
Utility
Merchant(1)
Degree days (electric utility service area):
Average retail energy marketing customer accounts (thousands)(2)
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Presented below, on an after-tax basis, are the key factors impacting Dominion Generation’s net income contribution:
Merchant generation margin
PJM ancillary services
Rate adjustment clause equity return
Retail energy marketing operations(1)
Salaries and benefits
Outage costs
Presented below are selected operating statistics related to Dominion Energy’s operations:
Gas distribution throughput (bcf):
Sales
Transportation
Heating degree days (gas distribution service area)
Average gas distribution customer accounts (thousands)(1):
Presented below, on an after-tax basis, are the key factors impacting Dominion Energy’s net income contribution:
Gas distribution margin:
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Presented below are the Corporate and Other segment’s after-tax results:
Specific items attributable to operating segments
Specific items attributable to corporate operations
Total specific items
Other corporate operations
Total net expense
EPS impact
Total Specific Items
Corporate and Other includes specific items that are not included in profit measures evaluated by management in assessing segment performance or in allocating resources among the segments. See Note 19 to the Consolidated Financial Statements in this report for discussion of these items.
Other Corporate Operations
Net expenses decreased primarily reflecting increased investment tax credits in Dominion's 2014 estimated annual effective rate for income taxes.
Presented below is a summary of Virginia Power’s consolidated results:
Net income decreased by 74% primarily due to charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities. See Note 12 for further discussion of this matter.
Net income decreased by 29% primarily due to charges associated with Virginia legislation enacted in April 2014 relating to the development of a third nuclear unit located at North Anna and offshore wind facilities, partially offset by the impact of more favorable weather.
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Presented below are selected amounts related to Virginia Power’s results of operations:
An analysis of Virginia Power’s results of operations follows:
Other operations and maintenance increased 78%, primarily reflecting:
Interest and related chargesincreased 23%, primarily due to higher long-term debt interest expense resulting from debt issuances in August 2013 and February 2014 ($14 million) and a decrease in the debt component of AFUDC ($6 million).
Income tax expense decreased 62%, primarily reflecting lower pre-tax income in 2014.
Net revenue increased 7%, primarily reflecting:
Other operations and maintenanceincreased 45%, primarily reflecting:
Other income decreased 31%, primarily due to a decrease in the equity component of AFUDC.
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Interest and related charges increased 19%, primarily due to higher long-term debt interest expense resulting from debt issuances in August 2013 and February 2014 ($25 million) and a decrease in the debt component of AFUDC ($8 million).
Income tax expense decreased 21%, primarily reflecting lower pre-tax income in 2014.
Presented below is a summary of contributions by Virginia Power’s operating segments to net income:
Presented below are operating statistics related to Virginia Power’s DVP segment:
Presented below, on an after-tax basis, are the key factors impacting Virginia Power’s DVP segment’s net income contribution:
Presented below are operating statistics related to Virginia Power’s Dominion Generation segment:
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Presented below, on an after-tax basis, are the key factors impacting Virginia Power’s Dominion Generation segment’s net income contribution:
Presented below is a summary of Dominion Gas’ consolidated results:
Net income increased by 75% primarily due to the absence of impairment charges for certain natural gas infrastructure assets.
Net income increased by 35% primarily due to the absence of impairment charges for certain natural gas infrastructure assets and increased gains due to the sale of pipeline systems.
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Presented below are selected amounts related to Dominion Gas’ results of operations:
An analysis of Dominion Gas’ results of operations follows:
Other operations and maintenance decreased 39%, primarily reflecting:
Income tax expense increased 88%, primarily reflecting higher pre-tax income in 2014.
Net revenue decreased 5%, primarily reflecting:
Other operations and maintenance decreased 47%, primarily reflecting:
Income tax expense increased 34%, primarily reflecting higher pre-tax income in 2014.
Liquidity and Capital Resources
Dominion and Virginia Power depend on both internal and external sources of liquidity to provide working capital and as a bridge to long-term debt financings. Short-term cash requirements not met by cash provided by operations are generally satisfied with proceeds from short-term borrowings. Long-term cash needs are met through issuances of debt and/or equity securities.
At June 30, 2014, Dominion had $1.3 billion of unused capacity under its credit facilities. At June 30, 2014, Virginia Power’s facility sub-limit was exceeded; however, Virginia Power retained ongoing access to its short-term demand note with Dominion and remained in compliance with its debt covenants. Effective July 10, 2014, Virginia Power increased its sub-limit under the $4 billion credit facility from $1.0 billion to $1.25 billion bringing its total sub-limit to $1.5 billion.
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The sale of the electric retail energy marketing business and completion of the producer services repositioning in 2014 are not expected to have a material negative impact on Dominion’s liquidity.
A summary of Dominion’s cash flows is presented below:
Cash and cash equivalents at January 1
Cash flows provided by (used in):
Operating activities
Investing activities
Financing activities
Net increase (decrease) in cash and cash equivalents
Cash and cash equivalents at June 30
A summary of Virginia Power’s cash flows is presented below:
Operating Cash Flows
Net cash provided by Dominion’s operating activities decreased by $344 million, primarily due to lower deferred fuel cost recoveries in its Virginia jurisdiction, the repositioning of Dominion’s producer services business, and lower margins from nonregulated retail energy marketing operations. The decrease was partially offset by lower net margin collateral requirements, higher margins from merchant generation operations, and the impact of more favorable weather in 2014.
Net cash provided by Virginia Power's operating activities decreased by $206 million, primarily due to lower deferred fuel cost recoveries, partially offset by the impact of more favorable weather in 2014 and net changes in other working capital items.
Dominion believes that its operations provide a stable source of cash flow to contribute to planned levels of capital expenditures and maintain or grow the dividend on common shares. Virginia Power believes that its operations provide a stable source of cash flow to contribute to planned levels of capital expenditures and provide dividends to Dominion.
Dominion’s and Virginia Power’s operations are subject to risks and uncertainties that may negatively impact the timing or amounts of operating cash flows, which are discussed in Item 1A. Risk Factors in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013.
Credit Risk
Dominion’s exposure to potential concentrations of credit risk results primarily from its energy marketing and price risk management activities. Presented below is a summary of Dominion’s credit exposure as of June 30, 2014 for these activities. Gross credit exposure for each counterparty is calculated prior to the application of collateral and represents outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights.
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Investment grade(1)
Non-investment grade(2)
No external ratings:
Internally rated—investment grade(3)
Internally rated—non-investment grade(4)
Investing Cash Flows
Net cash used in Dominion’s investing activities increased by $301 million, primarily due to higher capital expenditures partially offset by higher proceeds from sales of assets.
Net cash used in Virginia Power's investing activities increased by $202 million, primarily due to higher capital expenditures.
Financing Cash Flows and Liquidity
Dominion and Virginia Power rely on capital markets as significant sources of funding for capital requirements not satisfied by cash provided by their operations. As discussed further in Credit Ratings and Debt Covenants in MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, the ability to borrow funds or issue securities and the return demanded by investors are affected by credit ratings. In addition, the raising of external capital is subject to certain regulatory requirements, including registration with the SEC and, in the case of Virginia Power, approval by the Virginia Commission.
Dominion and Virginia Power meet the definition of a well-known seasoned issuer under SEC rules governing the registration, communications and offering processes under the Securities Act of 1933, as amended. The rules provide for a streamlined shelf registration process to provide registrants with timely access to capital. This allows Dominion and Virginia Power to use automatic shelf registration statements to register any offering of securities, other than those for exchange offers or business combination transactions.
In 2014, net cash provided by Dominion’s financing activities increased by $806 million primarily due to higher net debt issuances in 2014 as compared to 2013, mainly as a result of higher capital needs and lower cash flow from operations.
In 2014, net cash provided by Virginia Power's financing activities increased by $464 million, primarily due to higher net debt issuances, mainly as a result of higher capital needs and lower cash flow from operations, partially offset by the redemption of preferred stock in 2014.
See Note 14 to the Consolidated Financial Statements in this report for further information regarding Dominion's and Virginia Power's credit facilities, liquidity and significant financing transactions.
Credit Ratings
Credit ratings are intended to provide banks and capital market participants with a framework for comparing the credit quality of securities and are not a recommendation to buy, sell or hold securities. In the Credit Ratings section of MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, there is a discussion on the use of capital markets by Dominion and Virginia Power as well as the impact of credit ratings on the accessibility and costs of using these markets. As of June 30, 2014, there have been no changes in Dominion's and Virginia Power’s credit ratings.
Debt Covenants
In the Debt Covenants section of MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, there is a discussion on the various covenants present in the enabling agreements underlying Dominion’s and Virginia Power’s debt. As of June 30, 2014, there have been no material changes to debt covenants, nor any events of default under Dominion’s and Virginia Power’s debt covenants.
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In July 2014, Dominion amended the RCC of the June 2009 hybrids to expand the measurement period for consideration of proceeds from the sale of common stock or other equity-like issuances from 180 days to 365 days.
Future Cash Payments for Contractual Obligations and Planned Capital Expenditures
As of June 30, 2014, there have been no material changes outside the ordinary course of business to Dominion’s or Virginia Power’s contractual obligations nor any material changes to planned capital expenditures as disclosed in MD&A in Dominion’s and Virginia Power's Annual Report on Form 10-K for the year ended December 31, 2013.
Use of Off-Balance Sheet Arrangements
As of June 30, 2014, there have been no material changes in the off-balance sheet arrangements disclosed in MD&A in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013.
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 Dominion’s and Virginia Power’s Consolidated Financial Statements that may impact Dominion’s and Virginia Power’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’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Future Issues and Other Matters in MD&A in Dominion’s and Virginia Power’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014.
Dominion and Virginia Power are 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 22 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 15 in this report for additional information on various environmental matters.
In April 2012, the EPA published proposed NSPS for GHG emissions for new electric generating units. This proposed rule set national emission standards for new coal, oil, integrated gasification, and combined cycle units larger than 25 MW. The proposed rule covered CO2 only and does not apply to existing sources. The proposed rule also does not apply to any new or existing biomass units. In June 2013, the President of the U.S. released a Climate Action Plan focusing on ways to meet the national GHG reduction goal of 17% from 2005 levels by 2020. Pursuant to the Presidential Memorandum issued in conjunction with the Climate Action Plan, the EPA withdrew the April 2012 proposal and re-proposed the NSPS standards for new sources on January 8, 2014 and is expected to finalize the rule in early 2015. The Presidential Memorandum also directed the EPA to propose a rule for reconstructed, modified and existing sources of GHG emissions no later than June 2014, and issue a final rule no later than June 2015, to provide guidelines to the states to achieve the required GHG reductions.
In June 2014, the EPA issued proposed guidelines called the “Clean Power Plan” for states to follow in developing plans to reduce CO2 emissions from existing fossil fuel-fired electric generating units. The guidelines use a set of measures for reducing emissions from existing sources that includes efficiency improvements at coal plants, displacing coal-fired generation with increased utilization of natural gas combined cycle units, expanding renewable resources and increasing customer energy efficiency. The proposal would require states to meet state-by-state emission rate or intensity-based CO2 binding goals or limits. The EPA is expected to finalize the guidelines by June 2015. States will then be required to submit plans to the EPA by June 30, 2016 identifying how they will comply with the rule, with possible one- or two-year extensions. Until the state plans are developed and the EPA approves the plans, Dominion and Virginia Power cannot predict the potential financial statement impacts but believes the potential expenditures to comply could be material.
In June 2014, the EPA published proposed performance standards to address CO2 emissions from modified and reconstructed electric generating units. The proposed standards would only apply to coal- and natural-gas fired boilers and natural gas-fired combined cycle units, constructed for the purpose of supplying more than one-third of their potential output to the grid and which are designed to sell more than 219,000 MWhs in a year (roughly equivalent to 25 MW), that meet certain, specific conditions described in the CAA for being “modified” or “reconstructed.” Modifications undertaken for the primary purpose of installing pollution control technology will not be subject to the proposed standards. Dominion and Virginia Power cannot predict the direct or indirect financial impact of this proposed rule on operations at this time.
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In March 2014, a national Strategy to Reduce Methane Emissions was published as part of the Climate Action Plan. The plan outlines a strategy to further reduce both domestic and international methane emissions from a number of key sources, including the oil and natural gas industry, and outlines the President’s efforts to improve measurement of these emissions. In April 2014, the EPA published five white papers on methane emissions and potential mitigation options related to the oil and gas industry. The EPA is expected to make a decision on whether to regulate methane emissions from the oil and natural gas industry in late 2014. The EPA expects to complete any additional regulations deemed to be necessary by the end of 2016. Dominion currently cannot predict the direct or indirect financial impact on operations from these GHG initiatives, but believes the expenditures to comply with any new requirements could be material.
See Item 3. Legal Proceedings in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013, and Notes 12 and 15 to the Consolidated Financial Statements and Part II, Item 1. Legal Proceedings in Dominion’s and Virginia Power’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014 and in this report for additional information on various legal matters.
Regulatory Matters
See Note 13 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and Note 12 in Dominion’s and Virginia Power’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2014 and in this report for additional information on various regulatory matters.
Dominion is pursuing a liquefaction project at Cove Point, which would enable the facility to liquefy domestically-produced natural gas and export it as LNG.
In April 2013, Cove Point filed with FERC for permission to build liquefaction and other facilities related to the export of natural gas. In May 2014, the FERC staff issued its environmental assessment for the liquefaction project. Based on the analysis in the environmental assessment, the FERC staff determined that with the implementation of appropriate mitigation measures, the liquefaction project can be built and operated safely with no significant impact to the environment. The mitigation measures proposed in the environmental assessment are not final. Until the FERC approves the liquefaction project, the mitigation measures and associated conditions are nonbinding and are subject to change, and the estimated costs and impact of implementing such measures cannot yet be determined. The application is currently pending before the FERC.
Also in April 2013, Cove Point filed an application with the Maryland Commission for a CPCN to authorize the construction of an electric generating station needed to power the proposed liquefaction equipment. In May 2014, the Maryland Commission granted a CPCN authorizing the construction of such generating station. The CPCN is contingent upon Cove Point receiving FERC approval for the liquefaction project and will obligate Cove Point to make payments over time totaling approximately $48 million to the Maryland Strategic Energy Investments Fund and Maryland low income energy assistance programs. In June 2014, a party filed a notice of petition for judicial review of the CPCN with the Circuit Court for Baltimore City in Maryland. This matter is currently pending.
Dominion is party to an agreement with the Sierra Club restricting activities on portions of the Cove Point property. In February 2014, the Maryland Court of Special Appeals affirmed a circuit court’s prior ruling that Cove Point may locate, construct and operate a liquefaction plant at the Cove Point LNG Facility and export LNG from the Cove Point LNG Facility. In April 2014, the Sierra Club petitioned the Maryland Court of Appeals, Maryland's highest court, to review the rulings of the circuit court and the Maryland Court of Special Appeals. In June 2014, the Maryland Court of Appeals declined the appeal petition.
Western Access II Project
During the second quarter of 2014, East Ohio executed a long-term precedent agreement with a customer for 350,000 Dths per day of service to new interconnects with interstate pipelines. This second phase of the Western Access Project will expand the number of interstate pipelines to which East Ohio will deliver processed gas to four. The project is expected to be completed in the fourth quarter of 2015 and cost approximately $130 million.
Monroe-to-Cornwell Project
During the second quarter of 2014, DTI executed a binding precedent agreement with a customer for the Monroe-to-Cornwell Project. The project is expected to cost approximately $70 million and provide 205,000 Dths per day of firm transportation service from Monroe County, Ohio to an interconnect near Cornwell, West Virginia. In 2014, DTI expects to file an application to request FERC authorization to construct and operate the project facilities, which are expected to be in service in the fourth quarter of 2016.
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ITEM 3.
QUANTITATIVE AND QUALITATIVE
DISCLOSURES ABOUT MARKET RISK
The matters discussed in this Item may contain “forward-looking statements” as described in the introductory paragraphs under Part I, Item 2. MD&A in this report. The reader’s attention is directed to those paragraphs for discussion of various risks and uncertainties that may impact the Companies.
Market Risk Sensitive Instruments and Risk Management
The Companies’ financial instruments, commodity contracts and related financial derivative instruments are exposed to potential losses due to adverse changes in commodity prices, interest rates and equity security prices as described below. Commodity price risk is present in Dominion’s and Virginia Power's electric operations and Dominion’s and Dominion Gas’ gas procurement and marketing operations due to the exposure to market shifts in prices received and paid for electricity, natural gas and other commodities. The Companies use commodity derivative contracts to manage price risk exposures for these operations. Interest rate risk is generally related to their outstanding debt and future issuances of debt. In addition, the Companies are exposed to investment price risk through various portfolios of equity and debt securities.
The following sensitivity analysis estimates the potential loss of future earnings or fair value from market risk sensitive instruments over a selected time period due to a 10% unfavorable change in commodity prices or interest rates.
Commodity Price Risk
To manage commodity price risk, Dominion and Virginia Power primarily hold commodity-based financial derivative instruments held for non-trading purposes associated with purchases and sales of electricity, natural gas and other energy-related products and Dominion Gas primarily holds commodity-based financial derivative instruments held for non-trading purposes associated with purchases and sales of natural gas and other energy-related products.
The repositioning of Dominion's producer services business was completed in the first quarter of 2014. This, combined with Dominion's sale of its electric retail energy marketing business, has reduced Dominion's commodity price risk exposure.
The derivatives used to manage commodity price risk are executed within established policies and procedures and may include instruments such as futures, forwards, swaps, options and FTRs that are sensitive to changes in the related commodity prices. For sensitivity analysis purposes, the hypothetical change in market prices of commodity-based financial derivative instruments is determined based on models that consider the market prices of commodities in future periods, the volatility of the market prices in each period, as well as the time value factors of the derivative instruments. Prices and volatility are principally determined based on observable market prices.
A hypothetical 10% unfavorable change in commodity prices of Dominion's non-trading commodity-based financial derivative instruments would have resulted in a decrease in fair value of approximately $152 million and $171 million as of June 30, 2014 and December 31, 2013, respectively.
A hypothetical 10% unfavorable change in commodity prices would not have resulted in a material change in the fair value of Virginia Power's non-trading commodity-based financial derivatives as of June 30, 2014 or December 31, 2013.
A hypothetical 10% unfavorable change in commodity prices of Dominion Gas' non-trading commodity-based financial derivative instruments would have resulted in a decrease in fair value of approximately $7 million and $14 million as of June 30, 2014 and December 31, 2013, respectively. The decline in sensitivity is largely due to decreased commodity derivative activity.
The impact of a change in energy commodity prices on the Companies' non-trading commodity-based financial derivative instruments at a point in time is not necessarily representative of the results that will be realized when the contracts are ultimately settled. Net losses from commodity derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction, such as revenue from physical sales of the commodity.
Interest Rate Risk
The Companies manage their interest rate risk exposure predominantly by maintaining a balance of fixed and variable rate debt. They also enter into interest rate sensitive derivatives, including interest rate swaps and interest rate lock agreements. For variable rate debt and interest rate swaps designated under fair value hedging and outstanding for the Companies, a hypothetical 10% increase in market interest rates would not have resulted in a material change in earnings at June 30, 2014 or December 31, 2013.
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The Companies may also use forward-starting interest rate swaps and interest rate lock agreements as anticipatory hedges.
As of June 30, 2014, Dominion, Virginia Power and Dominion Gas had $2.9 billion, $550 million and $800 million, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of approximately $51 million, $9 million and $25 million, respectively, in the fair value of Dominion's, Virginia Power's and Dominion Gas' interest rate derivatives at June 30, 2014. As of December 31, 2013, Dominion, Virginia Power and Dominion Gas had $1.1 billion, $600 million and $450 million, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of approximately $20 million, $13 million and $8 million, respectively, in the fair value of Dominion's, Virginia Power's and Dominion Gas' interest rate derivatives at December 31, 2013.
The impact of a change in interest rates on the Companies' interest rate-based financial derivative instruments at a point in time is not necessarily representative of the results that will be realized when the contracts are ultimately settled. Net gains and/or losses from interest rate derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction.
Investment Price Risk
Dominion and Virginia Power are subject to investment price risk due to securities held as investments in nuclear decommissioning and rabbi trust funds that are managed by third-party investment managers. These trust funds primarily hold marketable securities that are reported in the Consolidated Balance Sheets at fair value.
Dominion recognized net realized gains (including investment income) on nuclear decommissioning and rabbi trust investments of $71 million, $93 million and $163 million for the six months ended June 30, 2014 and 2013 and for the year ended December 31, 2013, respectively. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Dominion recorded, in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $127 million, $130 million and $417 million for the six months ended June 30, 2014 and 2013 and for the year ended December 31, 2013, respectively.
Virginia Power recognized net realized gains (including investment income) on nuclear decommissioning trust investments of $32 million, $28 million and $52 million for the six months ended June 30, 2014 and 2013 and for the year ended December 31, 2013, respectively. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Virginia Power recorded, in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $61 million, $69 million and $193 million for the six months ended June 30, 2014 and 2013 and for the year ended December 31, 2013, respectively.
Dominion sponsors pension and other postretirement employee benefit plans that hold investments in trusts to fund employee benefit payments. Virginia Power and Dominion Gas employees participate in these plans. Differences between actual and expected returns on plan assets are accumulated and amortized during future periods. As such, any investment-related declines in these trusts will result in future increases in the periodic cost recognized for employee benefit plans and will be included in the determination of the amount of cash to be contributed to the employee benefit plans.
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ITEM 4. CONTROLS AND PROCEDURES
Senior management of each of Dominion, Virginia Power, and Dominion Gas, including Dominion’s, Virginia Power’s, and Dominion Gas’ CEO and CFO, evaluated the effectiveness of each of their respective Company’s disclosure controls and procedures as of the end of the period covered by this report. Based on this evaluation process, each of Dominion’s, Virginia Power’s, and Dominion Gas’ CEO and CFO have concluded that each of their respective Company’s disclosure controls and procedures are effective.
There were no changes in either Dominion’s, Virginia Power’s, or Dominion Gas' internal control over financial reporting that occurred during the last fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Companies’ internal control over financial reporting.
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PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
From time to time, the Companies are alleged to be in violation or in default under orders, statutes, rules or regulations relating to the environment, compliance plans imposed upon or agreed to by the Companies, or permits issued by various local, state and/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, the Companies and their subsidiaries are involved in various legal proceedings.
See the following for discussions on various environmental and other regulatory proceedings to which the Companies are parties:
ITEM 1A. RISK FACTORS
The Companies businesses are influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond the Companies’ control. A number of these risk factors have been identified in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and in Exhibit 99.2 to Dominion Gas' Current Report on Form 8-K dated June 26, 2014, which should be taken into consideration when reviewing the information contained in this report. Other than the risk factor discussed below, there have been no material changes with regard to the risk factors previously disclosed in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2013 and in Exhibit 99.2 to Dominion Gas' Current Report on Form 8-K dated June 26, 2014. 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.
The development, construction and operation of the Cove Point liquefaction project would involve significant risks. As described in greater detail inFuture Issues and Other Matters in Dominion’s Annual Report on Form 10-K for the year ended December 31, 2013, Dominion intends to invest significant financial resources in the liquefaction project, subject to receipt of required regulatory approvals. An inability to obtain financing or otherwise provide liquidity for the project on acceptable terms could negatively affect Dominion’s financial condition, cash flows, the project’s anticipated financial results and/or impair Dominion’s ability to execute the business plan for the project as scheduled.
The project remains subject to FERC approval. Additionally, Dominion must comply with conditions imposed by regulatory approvals. The DOE has authorized Dominion to export LNG to non-free trade agreement countries; however, all DOE export licenses are subject to review and possible withdrawal should the DOE conclude that such export authorization is no longer in the public interest, which could have a material adverse effect on the construction or operation of the facility. In addition, the liquefaction project has been the subject of litigation in the past and could be the subject of litigation in the future. A delay in receipt of project approval, failure to comply with regulatory approval conditions or an adverse ruling in any future litigation could adversely affect Dominion’s ability to execute its business plan.
There is limited recent industry experience in the U.S. regarding the construction or operation of large liquefaction projects. The construction of the facility is expected to take several years, will be confined within a limited geographic area and could be subject to delays, cost overruns, labor disputes and other factors that could cause the total cost of the project to exceed the anticipated amount and adversely affect Dominion’s financial performance and/or impair Dominion’s ability to execute the business plan for the project as scheduled.
There are significant customer risks associated with the project. The terminal service agreements are subject to certain conditions precedent, including receipt of regulatory approvals. Dominion will also be exposed to counterparty credit risk. While the counterparties’ obligations are supported by parental guarantees and letters of credit, there is no assurance that such credit support would be sufficient to satisfy the obligations in the event of a counterparty default. In addition, if a controversy arises under either agreement resulting in a judgment in Dominion’s favor, Dominion may need to seek to enforce a final U.S. court judgment in a foreign tribunal, which could involve a lengthy process.
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Assuming current commodity price trends continue, if Dominion is unable to pursue the liquefaction project, Dominion may not be able to offset the prospective revenue reductions associated with the existing import contracts as described in Future Issues and Other Matters in Dominion’s Annual Report on Form 10-K for the year ended December 31, 2013, which could have a negative impact on its results of operations.
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ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
ISSUER PURCHASES OF EQUITY SECURITIES
Period
4/1/14-4/30/14
$1.18 billion
5/1/14-5/31/14
6/1/14-6/30/14
ITEM 6. EXHIBITS
Exhibit
Description
VirginiaPower
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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.
Registrant
/s/ Michele L. Cardiff
Vice President, Controller and
Chief Accounting Officer
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EXHIBIT INDEX
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