Document_and_Entity_Informatio
Document and Entity Information Document (USD $) | 12 Months Ended | |
Dec. 31, 2013 | Feb. 26, 2014 | |
Entity Information [Line Items] | ' | ' |
Entity Registrant Name | 'Transcontinental Gas Pipe Line Company, LLC | ' |
Entity Central Index Key | '0000099250 | ' |
Document Type | '10-K | ' |
Document Period End Date | 31-Dec-13 | ' |
Amendment Flag | 'false | ' |
Document Fiscal Year Focus | '2013 | ' |
Document Fiscal Period Focus | 'FY | ' |
Current Fiscal Year End Date | '--12-31 | ' |
Entity Filer Category | 'Non-accelerated Filer | ' |
Entity Common Stock, Shares Outstanding | ' | 0 |
Entity Well-known Seasoned Issuer | 'No | ' |
Entity Voluntary Filers | 'No | ' |
Entity Current Reporting Status | 'Yes | ' |
Entity Public Float | ' | $0 |
Consolidated_Statement_of_Comp
Consolidated Statement of Comprehensive Income (USD $) | 12 Months Ended | ||
In Thousands, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Operating Revenues: | ' | ' | ' |
Natural gas sales | $113,488 | $65,120 | $108,359 |
Natural gas transportation | 1,094,807 | 1,022,990 | 983,554 |
Natural gas storage | 143,047 | 140,390 | 142,556 |
Other | 4,990 | 5,601 | 8,045 |
Total operating revenues | 1,356,332 | 1,234,101 | 1,242,514 |
Operating Costs and Expenses: | ' | ' | ' |
Cost of natural gas sales | 113,488 | 65,120 | 108,359 |
Cost of natural gas transportation | 24,936 | 31,815 | 35,674 |
Operation and maintenance | 264,631 | 299,734 | 281,496 |
Administrative and general | 182,352 | 174,610 | 148,113 |
Depreciation and amortization | 265,273 | 266,445 | 259,660 |
Taxes - other than income taxes | 43,898 | 45,086 | 41,673 |
Other expense, net | 32,606 | 21,230 | 12,988 |
Total operating costs and expenses | 927,184 | 904,040 | 887,963 |
Operating Income | 429,148 | 330,061 | 354,551 |
Other (Income) and Other Expenses: | ' | ' | ' |
Interest expense - affiliate | 190 | 309 | 262 |
Interest expense - other | 84,000 | 88,766 | 94,920 |
Interest income - affiliate | -45 | -35 | -29 |
Interest income - other | -2,068 | -2,351 | -2,119 |
Allowance for equity and borrowed funds used during construction (AFUDC) | -18,595 | -19,257 | -15,339 |
Equity in earnings of unconsolidated affiliates | -5,678 | -7,458 | -5,164 |
Miscellaneous other (income) expenses, net | -2,682 | -2,379 | 2,362 |
Total other (income) and other expenses | 55,122 | 57,595 | 74,893 |
Net Income | 374,026 | 272,466 | 279,658 |
Other comprehensive income (loss): | ' | ' | ' |
Equity interest in unrealized gain (loss) on interest rate hedges (includes $330, $220, and $170 for the years ended December 31, 2013, 2012, and 2011, respectively, of accumulated other comprehensive income reclassification for realized losses on interest rate hedges) | 464 | -376 | -519 |
Comprehensive Income | $374,490 | $272,090 | $279,139 |
Consolidated_Statement_of_Comp1
Consolidated Statement of Comprehensive Income (Parenthetical) (USD $) | 12 Months Ended | ||
In Thousands, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Income Statement [Abstract] | ' | ' | ' |
Accumulated other comprehensive income reclassification for realized losses on interest rate hedges | $330 | $220 | $170 |
Consolidated_Balance_Sheet
Consolidated Balance Sheet (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Thousands, unless otherwise specified | ||
Current Assets: | ' | ' |
Cash | $113 | $185 |
Receivables: | ' | ' |
Trade | 137,808 | 116,847 |
Affiliates | 2,601 | 2,656 |
Advances to affiliate | 526,380 | 312,165 |
Other | 10,364 | 8,928 |
Transportation and exchange gas receivables | 6,757 | 2,876 |
Inventories: | ' | ' |
Gas in storage, at original cost | 790 | 812 |
Gas in storage, LIFO | 1,056 | 0 |
Gas available for customer nomination, at average cost | 8,553 | 8,600 |
Material and supplies, at lower of average cost or market | 37,133 | 36,506 |
Regulatory assets | 37,520 | 36,706 |
Other | 13,451 | 14,342 |
Total current assets | 782,526 | 540,623 |
Investments, at cost plus equity in undistributed earnings | 50,262 | 55,603 |
Property, Plant and Equipment: | ' | ' |
Natural gas transmission plant | 8,867,626 | 8,506,189 |
Less-Accumulated depreciation and amortization | 3,090,234 | 2,954,276 |
Total property, plant and equipment, net | 5,777,392 | 5,551,913 |
Other Assets: | ' | ' |
Regulatory assets | 256,612 | 214,912 |
Other | 57,785 | 47,764 |
Total other assets | 314,397 | 262,676 |
Total assets | 6,924,577 | 6,410,815 |
Payables: | ' | ' |
Trade | 106,096 | 107,795 |
Affiliates | 28,268 | 32,006 |
Cash overdrafts | 8,539 | 11,512 |
Transportation and exchange gas payables | 3,599 | 3,513 |
Reserve for rate refunds | 98,217 | 0 |
Accrued liabilities: | ' | ' |
Property and other taxes | 14,180 | 13,326 |
Interest | 19,894 | 20,784 |
Regulatory liabilities | 18,014 | 14,624 |
Customer advances | 17,811 | 11,020 |
Asset retirement obligations | 35,902 | 43,472 |
Other | 47,462 | 36,107 |
Total current liabilities | 397,982 | 294,159 |
Long-Term Debt | 1,428,355 | 1,428,323 |
Other Long-Term Liabilities: | ' | ' |
Asset retirement obligations | 238,085 | 253,398 |
Regulatory liabilities | 269,563 | 232,888 |
Other | 5,307 | 5,339 |
Total other long-term liabilities | 512,955 | 491,625 |
Contingent Liabilities and Commitments (Note 2) | ' | ' |
Owner's Equity: | ' | ' |
Member's capital | 2,257,499 | 1,993,412 |
Retained earnings | 2,328,044 | 2,204,018 |
Accumulated other comprehensive income (loss) | -258 | -722 |
Total owner's equity | 4,585,285 | 4,196,708 |
Total liabilities and owner's equity | $6,924,577 | $6,410,815 |
Consolidated_Statement_of_Owne
Consolidated Statement of Owner's Equity Consolidated Statement of Owner's Equity (USD $) | Total | Member's Capital | Retained Earnings | Accumulated Other Comprehensive Income (Loss) |
In Thousands | ||||
Balance at beginning of period at Dec. 31, 2010 | ' | $1,727,434 | $2,117,153 | $173 |
Cash contributions from parent | 115,000 | 115,000 | ' | ' |
Non-cash contributions from parent | ' | 0 | ' | ' |
Non-cash return of capital | ' | -546 | ' | ' |
Net income | 279,658 | ' | 279,658 | ' |
Cash distributions to parent | -219,000 | ' | -219,000 | ' |
Equity interest in unrealized gain (loss) on interest rate hedge | -519 | ' | ' | -519 |
Balance at end of period at Dec. 31, 2011 | 4,019,353 | 1,841,888 | 2,177,811 | -346 |
Cash contributions from parent | 150,000 | 150,000 | ' | ' |
Non-cash contributions from parent | ' | 1,524 | ' | ' |
Non-cash return of capital | ' | 0 | ' | ' |
Net income | 272,466 | ' | 272,466 | ' |
Cash distributions to parent | -246,259 | ' | -246,259 | ' |
Equity interest in unrealized gain (loss) on interest rate hedge | -376 | ' | ' | -376 |
Balance at end of period at Dec. 31, 2012 | 4,196,708 | 1,993,412 | 2,204,018 | -722 |
Cash contributions from parent | 264,000 | 264,000 | ' | ' |
Non-cash contributions from parent | ' | 87 | ' | ' |
Non-cash return of capital | ' | 0 | ' | ' |
Net income | 374,026 | ' | 374,026 | ' |
Cash distributions to parent | -250,000 | ' | -250,000 | ' |
Equity interest in unrealized gain (loss) on interest rate hedge | 464 | ' | ' | 464 |
Balance at end of period at Dec. 31, 2013 | $4,585,285 | $2,257,499 | $2,328,044 | ($258) |
Consolidated_Statement_of_Cash
Consolidated Statement of Cash Flows (USD $) | 12 Months Ended | ||
In Thousands, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Cash flows from operating activities: | ' | ' | ' |
Net income | $374,026 | $272,466 | $279,658 |
Adjustments to reconcile net income to net cash provided by operating activities: | ' | ' | ' |
Depreciation and amortization | 263,949 | 266,981 | 260,069 |
Allowance for equity funds used during construction (equity AFUDC) | -13,299 | -13,222 | -10,588 |
Changes in operating assets and liabilities: | ' | ' | ' |
Receivables - affiliates | 55 | 3,247 | -982 |
Receivables - trade and other | -21,772 | -4,186 | -11,155 |
Transportation and exchange gas receivable | -3,881 | 2,038 | -2,497 |
Regulatory assets - current | 28,536 | 1,171 | 10,567 |
Regulatory assets - non-current | 21,910 | -5,980 | -8,698 |
Inventories | 232 | 673 | 50,295 |
Payables - affiliates | -3,738 | 15,069 | -1,832 |
Payables - trade | -26,463 | 3,727 | 14,577 |
Accrued liabilities | 28,322 | 8,256 | 27,775 |
Asset retirement obligations | 13,105 | 35,195 | -6,964 |
Asset retirement obligation - removal costs | -26,919 | -41,052 | -43,666 |
Reserve for rate refunds | 98,217 | 0 | 0 |
Other, net | 10,731 | -2,934 | 15,085 |
Net cash provided by operating activities | 743,011 | 541,449 | 571,644 |
Cash flows from financing activities: | ' | ' | ' |
Additions to long-term debt | 0 | 398,804 | 372,518 |
Retirement of long-term debt | 0 | -325,000 | -300,000 |
Debt issue costs | 0 | -4,403 | -3,846 |
Cash distributions to parent | -250,000 | -246,259 | -219,000 |
Cash contributions from parent | 264,000 | 150,000 | 115,000 |
Other, net | -3,034 | -3,333 | -4,681 |
Net cash provided by (used in) financing activities | 10,966 | -30,191 | -40,009 |
Cash flows from investing activities: | ' | ' | ' |
Property, plant and equipment additions, net of equity AFUDC | -526,916 | -475,450 | -385,671 |
Disposal of property, plant and equipment, net | -3,621 | 7,157 | 2,698 |
Advances to affiliate, net | -214,215 | -58,554 | -144,773 |
Return of capital from unconsolidated affiliates | 1,438 | 11,327 | 1,925 |
Contributions to unconsolidated affiliates | 0 | -5,806 | -14,834 |
Purchase of ARO Trust investments | -58,242 | -34,430 | -41,310 |
Proceeds from sale of ARO Trust investments | 45,607 | 43,205 | 56,576 |
Other, net | 1,900 | 1,314 | -6,230 |
Net cash used in investing activities | -754,049 | -511,237 | -531,619 |
Increase (decrease) in cash | -72 | 21 | 16 |
Cash at beginning of period | 185 | 164 | 148 |
Cash at end of period | 113 | 185 | 164 |
Increase to property, plant and equipment | -558,201 | -466,115 | -386,462 |
Changes in related accounts payable and accrued liabilities | 31,285 | -9,335 | 791 |
Property, plant and equipment additions, net of equity AFUDC | -526,916 | -475,450 | -385,671 |
Supplemental Cash Flow Elements [Abstract] | ' | ' | ' |
Interest (exclusive of amount capitalized) | 76,803 | 86,586 | 88,357 |
Income taxes | $116 | $254 | $728 |
Summary_of_Significant_Account
Summary of Significant Accounting Policies (Notes) | 12 Months Ended | ||||
Dec. 31, 2013 | |||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ' | ||||
Summary of Significant Accounting Policies | ' | ||||
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES. | |||||
Corporate Structure and Control. | |||||
In this report, Transco (which includes Transcontinental Gas Pipe Line Company, LLC and unless the context otherwise requires, all of our majority-owned subsidiaries) is at times referred to in the first person as “we,” “us” or “our.” | |||||
Transco is owned, through Williams Partners Operating LLC (WPO), by Williams Partners L.P. (WPZ), a publicly traded Delaware limited partnership, which is consolidated by The Williams Companies, Inc. (Williams). At December 31, 2013, Williams holds an approximate 64 percent interest in WPZ, comprised of an approximate 62 percent limited partner interest and all of WPZ’s 2 percent general partner interest. | |||||
Transco is a single member limited liability company, and as such, single member losses are limited to the amount of their investment. | |||||
Related Party Transaction. | |||||
A member of Williams' Board of Directors, who was elected in 2013, is also the current chairman, president, and chief executive officer of an energy services company that is a customer of ours. We recorded $130.7 million in operating revenues in the Consolidated Statement of Comprehensive Income from this company for transportation and storage of natural gas for the year ended December 31, 2013. This board member does not have any material interest in any transactions between the energy services company and us and he had no role in any such transactions. | |||||
Nature of Operations. | |||||
We are an interstate natural gas transmission company that owns a natural gas pipeline system extending from Texas, Louisiana, Mississippi and the Gulf of Mexico through Alabama, Georgia, South Carolina, North Carolina, Virginia, Maryland, Delaware, Pennsylvania and New Jersey to the New York City metropolitan area. The system serves customers in Texas and the 12 southeast and Atlantic seaboard states mentioned above, including major metropolitan areas in Georgia, Washington D.C., Maryland, North Carolina, New York, New Jersey and Pennsylvania. | |||||
Regulatory Accounting. | |||||
We are regulated by the Federal Energy Regulatory Commission (FERC). The Accounting Standards Codification (ASC) Regulated Operations (Topic 980), provides that rate-regulated public utilities account for and report regulatory assets and liabilities consistent with the economic effect of the way in which regulators establish rates if the rates established are designed to recover the costs of providing the regulated service and if the competitive environment makes it probable that such rates can be charged and collected. Accounting for businesses that are regulated and apply the provisions of Topic 980 can differ from the accounting requirements for non-regulated businesses. Transactions that are recorded differently as a result of regulatory accounting requirements include the capitalization of an equity return component on regulated capital projects, capitalization of other project costs, retirements of general plant assets, employee related benefits, environmental costs, negative salvage, asset retirement obligations, and other costs and taxes included in, or expected to be included in, future rates. As a rate-regulated entity, our management has determined that it is appropriate to apply the accounting prescribed by Topic 980 and, accordingly, the accompanying consolidated financial statements include the effects of the types of transactions described above that result from regulatory accounting requirements. | |||||
Basis of Presentation. | |||||
Williams’ acquisition of Transco Energy Company and its subsidiaries, including us, in 1995 was accounted for using the purchase method of accounting. Accordingly, an allocation of the purchase price was assigned to our assets and liabilities based on their estimated fair values. The purchase price allocation to us primarily consisted of a $1.5 billion allocation to property, plant and equipment and adjustments to deferred taxes based upon the book basis of the net assets recorded as a result of the acquisition. The amount allocated to property, plant and equipment is being depreciated on a straight-line basis over 40 years, the estimated useful lives of these assets at the date of acquisition, at approximately $35 million per year. At December 31, 2013, the remaining property, plant and equipment allocation was approximately $0.7 billion. Current FERC policy does not permit us to recover through rates amounts in excess of original cost. | |||||
We are a participant in WPZ’s cash management program. We make advances to and receive advances from WPZ. The advances are represented by demand notes. The interest rate on these intercompany demand notes is based upon the daily overnight investment rate paid on WPZ’s excess cash at the end of each month. | |||||
Certain prior period amounts reported within Total operating costs and expenses in the Consolidated Statement of Comprehensive Income have been reclassified to conform to the current presentation. The effect of the correction increased Operation and maintenance costs $7.1 million and $6.8 million for the years ended December 31, 2012 and 2011, respectively, for the reclassification from Taxes-other than income taxes with no net impact on Total operating costs and expenses, Operating Income and Net Income. | |||||
Principles of Consolidation. | |||||
The consolidated financial statements include our accounts and the accounts of the subsidiaries we control. Companies in which we and our subsidiaries own 20 percent to 50 percent of the voting common stock or otherwise exercise significant influence over operating and financial policies of the company are accounted for under the equity method. The equity method investments as of December 31, 2013 and December 31, 2012 consist of Cardinal Pipeline Company, LLC (Cardinal) with ownership interest of approximately 45 percent and Pine Needle LNG Company, LLC (Pine Needle) with ownership interest of 35 percent. We received distributions associated with our equity method investments totaling $11.5 million, $14.3 million, and $6.2 million in 2013, 2012 and 2011, respectively. Included in the distributions are $1.4 million return of capital from Pine Needle in 2013 and $11.3 million return of capital from Cardinal in 2012. We made capital contributions to Cardinal related to Cardinal’s expansion project totaling $5.8 million in 2012. | |||||
Use of Estimates. | |||||
The preparation of financial statements in conformity with U.S. generally accepted accounting principles (GAAP) requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. Estimates and assumptions which, in the opinion of management, are significant to the underlying amounts included in the financial statements and for which it would be reasonably possible that future events or information could change those estimates include: 1) revenues subject to refund; 2) litigation-related contingencies; 3) environmental remediation obligations; 4) impairment assessments of long-lived assets; 5) depreciation; and 6) asset retirement obligations. | |||||
Revenue Recognition. | |||||
Revenues for transportation of gas under long-term firm agreements are recognized considering separately the reservation and commodity charges. Reservation revenues are recognized monthly over the term of the agreement regardless of the volume of natural gas transported. Commodity revenues from both firm and interruptible transportation are recognized in the period transportation services are provided based on volumes of natural gas physically delivered at the agreed upon delivery point. Revenues for the storage of gas under firm agreements are recognized considering separately the reservation, capacity, and injection and withdrawal charges. Reservation and capacity revenues are recognized monthly over the term of the agreement regardless of the volume of storage service actually utilized. Injection and withdrawal revenues are recognized in the period when volumes of natural gas are physically injected into or withdrawn from storage. | |||||
In the course of providing transportation services to customers, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. The resulting imbalances are primarily settled through the purchase and sale of gas with our customers under terms provided for in our FERC tariff. Revenue is recognized from the sale of gas upon settlement of the transportation and exchange imbalances (See Gas Imbalances in this Note). | |||||
As a result of the ratemaking process, certain revenues collected by us may be subject to refunds upon the issuance of final orders by the FERC in pending rate proceedings. We record estimates of rate refund liabilities considering our and other third-party regulatory proceedings, advice of counsel and other risks. | |||||
Environmental Matters. | |||||
We are subject to federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on their economic benefit and potential for rate recovery. We believe that any expenditures required to meet applicable environmental laws and regulations are prudently incurred in the ordinary course of business and such expenditures would be permitted to be recovered through rates. | |||||
Property, Plant and Equipment. | |||||
Property, plant and equipment is recorded at cost. The carrying values of these assets are also based on estimates, assumptions and judgments relative to capitalized costs, useful lives and salvage values. These estimates, assumptions and judgments reflect FERC regulations, as well as historical experience and expectations regarding future industry conditions and operations. We account for repair and maintenance costs under the guidance of FERC regulations. The FERC identifies installation, construction and replacement costs that are to be capitalized. All other costs are expensed as incurred. Gains or losses from the ordinary sale or retirement of property, plant and equipment are credited or charged to accumulated depreciation; certain other gains or losses are recorded in operating income. | |||||
We provide for depreciation under the composite (group) method at straight-line FERC prescribed rates that are applied to the cost of the group for transmission facilities, production and gathering facilities and storage facilities. Under this method, assets with similar lives and characteristics are grouped and depreciated as one asset. Included in our depreciation rates is a negative salvage component (net cost of removal) that we currently collect in rates. Our depreciation rates are subject to change each time we file a general rate case with the FERC. Depreciation rates used for major regulated gas plant facilities at December 31, 2013, 2012 and 2011 are as follows: | |||||
Category of Property | 2013 (1) | 2012-2011 | |||
Gathering facilities | 1.35% - 2.50% | 0.18% - 1.66% | |||
Storage facilities | 2.10% - 2.25% | 2.10% - 3.70% | |||
Onshore transmission facilities | 2.61% - 5.00% | 2.79% - 5.71% | |||
Offshore transmission facilities | 1.20% - 1.20% | 1.01% - 1.01% | |||
(1) Changes in depreciation rates in 2013 due to placing into effect, subject to refund, the rates in Docket No. RP12-993 on March 1, 2013. | |||||
We record a liability and increase the basis in the underlying asset for the present value of each expected future asset retirement obligation (ARO) at the time the liability is initially incurred, typically when the asset is acquired or constructed. Measurements of AROs include, as a component of future expected costs, an estimate of the price that a third party would demand, and could expect to receive, for bearing the uncertainties inherent in the obligations, sometimes referred to as a market-risk premium. The ARO asset is depreciated in a manner consistent with the expected timing of the future abandonment of the underlying physical assets. We measure changes in the liability due to passage of time by applying an interest method of allocation. The depreciation of the ARO asset and accretion of the ARO liability are recognized as an increase to a regulatory asset, as management expects to recover such amounts in future rates. The regulatory asset is amortized commensurate with our collection of these costs in rates. | |||||
Impairment of Long-lived Assets. | |||||
We evaluate the long lived assets of identifiable business activities for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. When an indicator of impairment has occurred we compare our management’s estimate of undiscounted future cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred. We apply a probability-weighted approach to consider the likelihood of different cash flow assumptions and possible outcomes including selling in the near term or holding for the remaining estimated useful life. If an impairment of the carrying value has occurred, we determine the amount of the impairment recognized in the financial statements by estimating the fair value of the assets and recording a loss for the amount that the carrying value exceeds the estimated fair value. | |||||
For assets identified to be disposed of in the future and considered held for sale in accordance with the ASC Property, Plant, and Equipment (Topic 360), we compare the carrying value to the estimated fair value less the cost to sell to determine if recognition of an impairment is required. Until the assets are disposed of, the estimated fair value, which includes estimated cash flows from operations until the assumed date of sale, is recalculated when related events or circumstances change. | |||||
Judgments and assumptions are inherent in our management’s estimate of undiscounted future cash flows used to determine recoverability of an asset and the estimate of an asset’s fair value used to calculate the amount of impairment to recognize. The use of alternate judgments and/or assumptions could result in the recognition of different levels of impairment charges in the financial statements. | |||||
Allowance for Funds Used During Construction. | |||||
Allowance for funds used during construction (AFUDC) represents the estimated cost of borrowed and equity funds applicable to utility plant in process of construction and are included as a cost of property, plant and equipment because it constitutes an actual cost of construction under established regulatory practices. The FERC has prescribed a formula to be used in computing separate allowances for borrowed and equity AFUDC. The allowance for borrowed funds used during construction was $5.3 million, $6.0 million and $4.7 million, for 2013, 2012 and 2011, respectively. The allowance for equity funds was $13.3 million, $13.2 million, and $10.6 million, for 2013, 2012 and 2011, respectively. | |||||
Income Taxes. | |||||
We generally are not a taxable entity for federal or state and local income tax purposes. The tax on net income is generally borne by unitholders of our ultimate parent, WPZ. Net income for financial statement purposes may differ significantly from taxable income of WPZ’s unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under the WPZ partnership agreement. The aggregated difference in the basis of our assets for financial and tax reporting purposes cannot be readily determined because information regarding each of WPZ’s unitholder’s tax attributes in WPZ is not available to us. | |||||
Accounts Receivable and Allowance for Doubtful Receivables. | |||||
Accounts receivable are stated at the historical carrying amount net of reserves or write-offs. Our credit risk exposure in the event of nonperformance by the other parties is limited to the face value of the receivables. We perform ongoing credit evaluations of our customers’ financial condition and require collateral from our customers, if necessary. Due to our customer base, we have not historically experienced recurring credit losses in connection with our receivables. Receivables determined to be uncollectible are reserved or written off in the period of determination. | |||||
Gas Imbalances. | |||||
In the course of providing transportation services to customers, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. Additionally, we transport gas on various pipeline systems which may deliver different quantities of gas on behalf of us than the quantities of gas received from us. These transactions result in gas transportation and exchange imbalance receivables and payables which are recovered or repaid in cash or through the receipt or delivery of gas in the future and are recorded in the accompanying Consolidated Balance Sheet. Settlement of imbalances requires agreement between the pipelines and shippers as to allocations of volumes to specific transportation contracts and timing of delivery of gas based on operational conditions. Our tariff includes a method whereby most transportation imbalances are settled on a monthly basis. Each month a portion of the imbalances are not identified to specific parties and remain unsettled. These are generally identified to specific parties and settled in subsequent periods. We believe that amounts that remain unidentified to specific parties and unsettled at year end are valid balances that will be settled with no material adverse effect upon our financial position, results of operations or cash flows. Management has implemented a policy of continuing to carry any unidentified transportation and exchange imbalances on the books for a three-year period. At the end of the three year period a final assessment will be made of their continued validity. Absent a valid reason for maintaining the imbalance, any remaining balance will be recognized in income. Certain imbalances are being recovered or repaid in cash or through the receipt or delivery of gas upon agreement of the parties as to the allocation of the gas volumes, and as permitted by pipeline operating conditions. These imbalances have been classified as current assets and current liabilities at December 31, 2013 and 2012. We utilize the average cost method of accounting for gas imbalances. | |||||
Deferred Cash Out. | |||||
Most transportation imbalances are settled in cash on a monthly basis (cash out). We are required by our tariff to refund revenues received from the cash out of transportation imbalances in excess of costs incurred during the annual August through July reporting period. Revenues received in excess of costs incurred are deferred until refunded in accordance with the tariff. | |||||
Gas Inventory. | |||||
We utilize the last-in, first-out (LIFO) method of accounting for inventory gas in storage. If inventories valued using the LIFO cost method were valued at current replacement cost, the amounts would increase by $1.3 million at December 31, 2013. At December 31, 2012, physical withdrawals from the Eminence Storage facility exceeded the customer nominations for withdrawals, resulting in a liability. The basis for determining current cost at the end of each year is the December monthly average gas price delivered to pipelines in Texas and Louisiana. We utilize the average cost method of accounting for gas available for customer nomination. Liquefied natural gas in storage is valued at original cost. | |||||
Materials and Supplies Inventory. | |||||
All inventories are stated at lower of average cost or market. We perform an annual review of Materials and Supplies inventories, including a quarterly analysis of parts that may no longer be useful due to planned replacements of compressor engines and other components on our system. Based on this assessment, we record a reserve for the value of the inventory which can no longer be used for maintenance and repairs on our pipeline. There was a minimal reserve at December 31, 2013 and at December 31, 2012. | |||||
Contingent Liabilities. | |||||
We record liabilities for estimated loss contingencies, including environmental matters, when we assess that a loss is probable and the amount of the loss can be reasonably estimated. These liabilities are calculated based upon our assumptions and estimates with respect to the likelihood or amount of loss and upon advice of legal counsel, engineers, or other third parties regarding the probable outcomes of the matters. These calculations are made without consideration of any potential recovery from third-parties. We recognize insurance recoveries or reimbursements from others when realizable. Revisions to these liabilities are generally reflected in income when new or different facts or information become known or circumstances change that affect the previous assumptions or estimates. | |||||
Pension and Other Postretirement Benefits. | |||||
We do not have employees. Certain of the costs charged to us by Williams associated with employees who directly support us include costs related to Williams’ pension and other postretirement benefit plans. (See Note 6.) Although the underlying benefit plans of Williams are single-employer plans, we follow multiemployer plan accounting whereby the amount charged to us and thus paid by us, is based on our share of net periodic benefit cost. | |||||
Cash Flows from Operating Activities and Cash Equivalents. | |||||
We use the indirect method to report cash flows from operating activities, which requires adjustments to net income to reconcile to net cash flows provided by operating activities. We include short-term, highly-liquid investments that have an original maturity of three months or less as cash equivalents. |
Contingent_Liabilities_and_Com
Contingent Liabilities and Commitments (Notes) | 12 Months Ended |
Dec. 31, 2013 | |
Commitments and Contingencies Disclosure [Abstract] | ' |
Contingent Liabilities and Commitments | ' |
CONTINGENT LIABILITIES AND COMMITMENTS. | |
Rate Matters. | |
General rate case (Docket No. RP12-993) On August 31, 2012, we submitted to the FERC a general rate filing principally designed to recover increased costs and to comply with the terms of the settlement in our Docket No. RP06-569 rate proceeding (see below) which required us to file a rate case no later than August 31, 2012. On September 28, 2012, the FERC issued an order accepting our filing subject to the outcome of a hearing. The rates for certain services that were proposed as overall rate decreases became effective October 1, 2012, without suspension. The increased rates became effective March 1, 2013, subject to refund and the outcome of the hearing. On August 27, 2013, after reaching an agreement in principle with the participants, we filed a stipulation and agreement (Agreement) proposing to resolve all issues in this proceeding without the need for a hearing. On December 6, 2013, the FERC issued an order approving the Agreement without modifications. Pursuant to its terms, the Agreement will become effective March 1, 2014. We have provided a reserve for rate refunds which we believe is adequate for required refunds as of December 31, 2013, under the Agreement. Refunds will be made on or before April 30, 2014. | |
General rate case (Docket No. RP06-569) On August 31, 2006, we submitted to the FERC a general rate filing principally designed to recover increased costs. The rates became effective March 1, 2007, subject to refund and the outcome of a hearing. All issues in this proceeding except one have been resolved by settlement. | |
The one issue reserved for litigation or further settlement relates to our proposal to change the design of the rates for service under one of our storage rate schedules, which was implemented subject to refund on March 1, 2007. A hearing on that issue was held before a FERC Administrative Law Judge (ALJ) in July 2008. In November 2008, the ALJ issued an initial decision in which he determined that our proposed incremental rate design is unjust and unreasonable. On January 21, 2010, the FERC reversed the ALJ’s initial decision, and approved our proposed incremental rate design. Certain parties sought rehearing of the FERC’s order and, on April 2, 2012, the FERC denied the rehearing request. On June 1, 2012, one of the parties filed an appeal in the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit). On February 21, 2014, the D.C. Circuit issued an opinion that vacated and remanded the FERC's order because the FERC did not adequately support its conclusions. We intend to continue to pursue approval of our proposed rate design. If we are unsuccessful, we believe any refunds would not be material to our results of operations. | |
Environmental Matters. | |
We have had studies underway to test some of our facilities for the presence of toxic and hazardous substances to determine to what extent, if any, remediation may be necessary. We have responded to data requests from the U.S. Environmental Protection Agency (EPA) and state agencies regarding such potential contamination of certain of our sites. On the basis of the findings to date, we estimate that environmental assessment and remediation costs under various federal and state statutes will total approximately $6 million to $8 million (including both expense and capital expenditures), measured on an undiscounted basis, and will be spent over the next three to five years. This estimate depends on a number of assumptions concerning the scope of remediation that will be required at certain locations and the cost of the remedial measures. We are conducting environmental assessments and implementing a variety of remedial measures that may result in increases or decreases in the total estimated costs. At December 31, 2013, we had a balance of approximately $4.1 million for the expense portion of these estimated costs recorded in current liabilities ($2.3 million) and other long-term liabilities ($1.8 million) in the accompanying Consolidated Balance Sheet. At December 31, 2012, we had a balance of approximately $3.3 million for the expense portion of these estimated costs recorded in current liabilities ($1.1 million) and other long-term liabilities ($2.2 million) in the accompanying Consolidated Balance Sheet. | |
Although we discontinued the use of lubricating oils containing polychlorinated biphenyls (PCBs) in the 1970s, we have discovered residual PCB contamination in equipment and soils at certain gas compressor station sites. We have worked closely with the EPA and state regulatory authorities regarding PCB issues, and we have a program to assess and remediate such conditions where they exist. In addition, we commenced negotiations with certain environmental authorities and other parties concerning investigative and remedial actions relative to potential mercury contamination at certain gas metering sites. All such costs are included in the $6 million to $8 million range discussed above. | |
We have been identified as a potentially responsible party (PRP) at various Superfund and state waste disposal sites. Based on present volumetric estimates and other factors, our estimated aggregate exposure for remediation of these sites is less than $0.5 million. The estimated remediation costs for all of these sites are included in the $6 million to $8 million range discussed above. Liability under the Comprehensive Environmental Response, Compensation and Liability Act and applicable state law can be joint and several with other PRPs. Although volumetric allocation is a factor in assessing liability, it is not necessarily determinative; thus, the ultimate liability could be substantially greater than the amounts described above. | |
In March 2008, the EPA promulgated a new, lower National Ambient Air Quality Standard (NAAQS) for ground-level ozone. However, in September 2009, the EPA announced it would reconsider the 2008 NAAQS for ground level ozone to ensure that the standards were clearly grounded in science, and were protective of both public health and the environment. As a result, the EPA delayed designation of new eight-hour ozone non-attainment areas under the 2008 standards until the reconsideration is complete. In January 2010, the EPA proposed to further reduce the ground-level ozone NAAQS from the March 2008 levels. In September 2011, the EPA announced that it was proceeding with required actions to implement the 2008 ozone standard and area designations. In May 2012, the EPA completed designation of new eight-hour ozone non-attainment areas. Several Transco facilities are located in 2008 ozone non-attainment areas; however, each facility has been previously subjected to federal and/or state emission control requirements implemented to address preceding ozone standards. To date, no new federal or state actions have been proposed to mandate additional emission controls at these facilities. At this time, it is unknown whether future federal or state regulatory actions associated with implementation of the 2008 ozone standard will impact our operations and increase the cost of additions to property, plant and equipment. Until any additional federal or state regulatory actions are proposed, we are unable to estimate the cost of additions that may be required to meet this new regulation. | |
Additionally, in August 2010, the EPA promulgated National Emission Standards for Hazardous Air Pollutants (NESHAP) regulations that will impact our operations. All capital expenditures related to compliance with these hazardous air pollutant regulations were completed, and affected facilities were in compliance by the October 2013 regulatory deadline. | |
On January 22, 2010, the EPA set a new one-hour nitrogen dioxide (NO2) NAAQS. The effective date of the new NO2 standard was April 12, 2010. On January 20, 2012, the EPA determined pursuant to available information that no area in the country is violating the 2010 NO2 NAAQS and thus designated all areas of the country as “unclassifiable/attainment.” Also, at that time, the EPA noted its plan to deploy an expanded NO2 monitoring network beginning in 2013. However, on October 5, 2012, the EPA proposed a graduated implementation of the monitoring network between January 1, 2014 and January 1, 2017. Once three years of data is collected from the new monitoring network, the EPA will reassess attainment status with the one-hour NO2 NAAQS. Until that time, the EPA or states may require ambient air quality modeling on a case by case basis to demonstrate compliance with the NO2 standard. Because we are unable to predict the outcome of the EPA’s or states’ future assessment using the new monitoring network, we are unable to estimate the cost of additions that may be required to meet this regulation. | |
We consider prudently incurred environmental assessment and remediation costs and the costs associated with compliance with environmental standards to be recoverable through rates. To date, we have been permitted recovery of environmental costs, and it is our intent to continue seeking recovery of such costs through future rate filings. As a result, as estimated costs of environmental assessment and remediation are incurred, they are recorded as regulatory assets in the Consolidated Balance Sheet until collected through rates. At December 31, 2013, we had a balance of approximately $1.8 million of uncollected environmental related regulatory assets recorded in current assets ($1.2 million) and other assets ($0.6 million) in the accompanying Consolidated Balance Sheet. We had no uncollected environmental related regulatory assets at December 31, 2012. | |
By letter dated September 20, 2007, the EPA required us to provide information regarding natural gas compressor stations in the states of Mississippi and Alabama as part of the EPA’s investigation of our compliance with the Federal Clean Air Act (Act). By January 2008, we responded with the requested information. By Notices of Violation (NOVs) dated March 28, 2008, the EPA found us to be in violation of the requirements of the Act with respect to these compressor stations. We met with the EPA in May 2008 to discuss the allegations contained in the NOVs; in June 2008, we submitted to the EPA a written response denying the allegations. The EPA has requested additional information pertaining to these compressor stations and in May 2011, we submitted information in response to the EPA’s latest request. In August, 2010, the EPA requested, and we provided, similar information for a compressor station in Maryland. Since 2011, we have not received any additional requests from the EPA for information related to these facilities. | |
Other Matters. | |
Various other proceedings are pending against us and are considered incidental to our operations. | |
Summary. | |
We estimate that for all matters for which we are able to reasonably estimate a range of loss, including those noted above and others that are not individually significant, our aggregate reasonably possible losses beyond amounts accrued for all of our contingent liabilities are immaterial to our expected future annual results of operations, liquidity and financial position. These calculations have been made without consideration of any potential recovery from third parties. We have disclosed all significant matters for which we are unable to reasonably estimate a range of possible loss. | |
Other Commitments. | |
Commitments for construction We have commitments for construction and acquisition of property, plant and equipment of approximately $368 million at December 31, 2013. |
Debt_Financing_Arrangements_an
Debt, Financing Arrangements and Leases (Notes) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Debt Disclosure [Abstract] | ' | ||||||||
Debt, Financing Arrangements and Leases | ' | ||||||||
DEBT, FINANCING ARRANGEMENTS AND LEASES. | |||||||||
Long-Term Debt. | |||||||||
At December 31, 2013 and 2012, long-term debt issues were outstanding as follows (in thousands): | |||||||||
2013 | 2012 | ||||||||
Debentures: | |||||||||
7.08% due 2026 | $ | 7,500 | $ | 7,500 | |||||
7.25% due 2026 | 200,000 | 200,000 | |||||||
Total debentures | 207,500 | 207,500 | |||||||
Notes: | |||||||||
6.4% due 2016 | 200,000 | 200,000 | |||||||
6.05% due 2018 | 250,000 | 250,000 | |||||||
5.4% due 2041 | 375,000 | 375,000 | |||||||
4.45% due 2042 | 400,000 | 400,000 | |||||||
Total notes | 1,225,000 | 1,225,000 | |||||||
Total long-term debt issues | 1,432,500 | 1,432,500 | |||||||
Unamortized debt premium and discount | (4,145 | ) | (4,177 | ) | |||||
Total long-term debt, less current maturities | $ | 1,428,355 | $ | 1,428,323 | |||||
Aggregate minimum maturities (face value) applicable to long-term debt outstanding at December 31, 2013, for the next five years, are as follows (in thousands): | |||||||||
2016: 6.4% Notes | $200,000 | ||||||||
2018: 6.05% Notes | $250,000 | ||||||||
There are no maturities applicable to long-term debt outstanding for the years 2014, 2015, and 2017. | |||||||||
No property is pledged as collateral under any of our long-term debt issues. | |||||||||
Restrictive Debt Covenants. | |||||||||
At December 31, 2013, none of our debt instruments restrict the amount of distributions to our parent. Our debt agreements contain restrictions on our ability to incur secured debt beyond certain levels. | |||||||||
Credit Facility. | |||||||||
On July 31, 2013, WPZ amended its $2.4 billion credit facility to increase the aggregate commitments to $2.5 billion and extend the maturity date to July 31, 2018. The amended credit facility may also, under certain conditions, be increased up to an additional $500 million. Total letter of credit capacity available to WPZ under the credit facility is $1.3 billion. At December 31, 2013, no letters of credit have been issued and no loans are outstanding under our credit facility. We may borrow up to $500 million under the amended credit facility to the extent not otherwise utilized by WPZ and Northwest Pipeline LLC. At December 31, 2013, the full $500 million under the credit facility was available to us. | |||||||||
Under the credit facility, WPZ is required to maintain a ratio of debt to EBITDA (each as defined in the credit facility) that must be no greater than 5.0 to 1.0. For the fiscal quarter and the two following fiscal quarters in which one or more acquisitions for a total aggregate purchase price equal to or greater than $50 million has been executed, WPZ is required to maintain a ratio of debt to EBITDA of no greater than 5.5 to 1.00. In addition, the ratio of debt to capitalization (defined as net worth plus debt) must be no greater than 65 percent for us and our consolidated subsidiaries. At December 31, 2013, we are in compliance with these financial covenants. | |||||||||
Each time funds are borrowed, the applicable borrower may choose from two methods of calculating interest: a fluctuating base rate equal to Citibank N.A.’s alternate base rate plus an applicable margin, or a periodic fixed rate equal to London Interbank Offered Rate (LIBOR) plus an applicable margin. The applicable borrower is required to pay a commitment fee (currently 0.20 percent) based on the unused portion of the credit facility. The applicable margin and the commitment fee are determined for each borrower by reference to a pricing schedule based on such borrower’s senior unsecured long-term debt ratings. The credit facility contains various covenants that limit, among other things, a borrower’s and its respective material subsidiaries’ ability to grant certain liens supporting indebtedness, a borrower’s ability to merge or consolidate, sell all or substantially all of its assets, enter into certain affiliate transactions, make certain distributions during an event of default, make investments, and allow any material change in the nature of its business. | |||||||||
If an event of default with respect to a borrower occurs under the credit facility, the lenders will be able to terminate the commitments for all borrowers and accelerate the maturity of any loans of the defaulting borrower under the credit facility agreement and exercise other rights and remedies. | |||||||||
WPZ participates in a commercial paper program and WPZ management considers amounts outstanding under this program to be a reduction of available capacity under the credit facility. The program allows a maximum outstanding amount at any time of $2 billion of unsecured commercial paper notes. At December 31, 2013, WPZ had $225 million in outstanding commercial paper. | |||||||||
Issuance and Retirement of Long-Term Debt. | |||||||||
On July 13, 2012, we issued $400 million aggregate principal amount of 4.45 percent senior unsecured notes due 2042 (4.45 percent Notes) to certain institutional investors pursuant to certain exemptions from registration under the Securities Act of 1933, as amended. Interest is payable on February 1 and August 1 of each year, beginning February 1, 2013. A portion of these proceeds was used to repay our $325 million 8.875 percent notes that matured on July 15, 2012. We used the remainder for general corporate purposes, including the funding of capital expenditures. | |||||||||
As part of the new issuance, we entered into a registration rights agreement with the initial purchasers of the 4.45 percent Notes. An offer to exchange these unregistered notes for substantially identical new notes that are registered under the Securities Act of 1933, as amended, was commenced in November 2012 and completed in December 2012. | |||||||||
Lease Obligations. | |||||||||
The future minimum lease payments under our various operating leases are as follows (in thousands): | |||||||||
2014 | $ | 10,154 | |||||||
2015 | 10,025 | ||||||||
2016 | 10,025 | ||||||||
2017 | 9,971 | ||||||||
2018 | 9,956 | ||||||||
Thereafter | 22,401 | ||||||||
Total net minimum obligations | $ | 72,532 | |||||||
Our lease expense was $11.4 million in 2013, $10.9 million in 2012, and $9.1 million in 2011. |
Investments_Notes
Investments (Notes) | 12 Months Ended | ||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||
Investments, Debt and Equity Securities [Abstract] | ' | ||||||||||||||||
Investments | ' | ||||||||||||||||
INVESTMENTS. | |||||||||||||||||
Available-for-Sale Investments. | |||||||||||||||||
We are entitled to collect in rates the amounts necessary to fund our asset retirement obligations (ARO). We deposit monthly, into an external trust account, the revenues specifically designated for ARO. We established the ARO trust account (ARO Trust) on June 30, 2008. The ARO Trust carries a moderate risk portfolio. We measure the financial instruments held in our ARO Trust at fair value. However, in accordance with the ASC Topic 980, Regulated Operations, both realized and unrealized gains and losses of the ARO Trust are recorded as regulatory assets or liabilities. | |||||||||||||||||
Effective March 1, 2013, based on the Agreement in Docket No. RP12-993, the annual funding obligation is approximately $36.4 million, with installments paid monthly. | |||||||||||||||||
Investments in available-for-sale securities within the ARO Trust at fair value were as follows (in millions): | |||||||||||||||||
31-Dec-13 | 31-Dec-12 | ||||||||||||||||
Amortized | Fair | Amortized | Fair | ||||||||||||||
Cost Basis | Value | Cost Basis | Value | ||||||||||||||
Cash and Money Market Funds | $ | 6.5 | $ | 6.5 | $ | 1.3 | $ | 1.3 | |||||||||
U.S. Equity Funds | 8 | 11.1 | 5.4 | 7.4 | |||||||||||||
International Equity Funds | 4.2 | 4.9 | 3.4 | 3.8 | |||||||||||||
Municipal Bond Funds | 10.2 | 10.2 | 4.9 | 5.3 | |||||||||||||
Total | $ | 28.9 | $ | 32.7 | $ | 15 | $ | 17.8 | |||||||||
Fair_Value_Measurements_Notes
Fair Value Measurements (Notes) | 12 Months Ended | ||||||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||||||
Fair Value Disclosures [Abstract] | ' | ||||||||||||||||||||
Fair Value Measurements | ' | ||||||||||||||||||||
FAIR VALUE MEASUREMENTS. | |||||||||||||||||||||
The following table presents, by level within the fair value hierarchy, certain of our financial assets and liabilities. | |||||||||||||||||||||
Fair Value Measurements Using | |||||||||||||||||||||
Carrying | Fair | Quoted | Significant | Significant | |||||||||||||||||
Amount | Value | Prices In | Other | Unobservable | |||||||||||||||||
Active | Observable | Inputs | |||||||||||||||||||
Markets for | Inputs | (Level 3) | |||||||||||||||||||
Identical | (Level 2) | ||||||||||||||||||||
Assets | |||||||||||||||||||||
(Level 1) | |||||||||||||||||||||
(Millions) | |||||||||||||||||||||
Assets (liabilities) at December 31, 2013: | |||||||||||||||||||||
Measured on a recurring basis: | |||||||||||||||||||||
ARO Trust investments | $ | 32.7 | $ | 32.7 | $ | 32.7 | $ | — | $ | — | |||||||||||
Additional disclosures: | |||||||||||||||||||||
Notes receivable | 6.3 | 6.3 | — | 6.3 | — | ||||||||||||||||
Long-term debt | (1,428.4 | ) | (1,512.9 | ) | — | (1,512.9 | ) | — | |||||||||||||
Assets (liabilities) at December 31, 2012: | |||||||||||||||||||||
Measured on a recurring basis: | |||||||||||||||||||||
ARO Trust investments | $ | 17.8 | $ | 17.8 | $ | 17.8 | $ | — | $ | — | |||||||||||
Additional disclosures: | |||||||||||||||||||||
Notes receivable | 8.2 | 8.2 | — | 8.2 | — | ||||||||||||||||
Long-term debt, including current portion | (1,428.3 | ) | (1,704.5 | ) | — | (1,704.5 | ) | — | |||||||||||||
Fair Value of Methods. | |||||||||||||||||||||
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value: | |||||||||||||||||||||
Cash and short-term financial assets (advances to affiliates) that have variable interest rates - The carrying amount is a reasonable estimate of fair value due to the short maturity of those instruments. | |||||||||||||||||||||
ARO Trust investments - We deposit a portion of our collected rates, pursuant to the Docket No. RP06-569 rate case settlement, into the ARO Trust which is specifically designated to fund future asset retirement obligations. The ARO Trust invests in a portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market, are classified as available-for-sale, and are reported in Other Assets-Other in the Consolidated Balance Sheet. However, both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities. See Note 4 for more information regarding the ARO Trust. | |||||||||||||||||||||
Notes receivable - The disclosed fair value of our notes receivable is determined by an income approach which considers the underlying contract amounts and our assessment of our ability to recover these amounts. The current portion is reported in Trade and other receivables, and the noncurrent portion is reported in Other Assets-Other in the Consolidated Balance Sheet. | |||||||||||||||||||||
Long-term debt - The disclosed fair value of our long-term debt is determined by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments. | |||||||||||||||||||||
Reclassifications of fair value between Level 1, Level 2, and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. No transfers between Level 1 and Level 2 occurred during the year ended December 31, 2013 or 2012. |
Benefit_Plans_Notes
Benefit Plans (Notes) | 12 Months Ended |
Dec. 31, 2013 | |
Text Block [Abstract] | ' |
Benefit Plans | ' |
BENEFIT PLANS. | |
Certain of the benefit costs charged to us by Williams associated with employees who directly support us are described below. Additionally, allocated corporate expenses from Williams to us also include amounts related to these same employee benefits, which are not included in the amounts presented below. | |
Pension and Other Postretirement Benefit Plans. | |
Williams has noncontributory defined benefit pension plans (Williams Pension Plan, Williams Inactive Employees Pension Plan and The Williams Companies Retirement Restoration Plan) that provide pension benefits for its eligible employees. Pension cost charged to us by Williams was $22.3 million, $20.3 million and $16.4 million for 2013, 2012, and 2011, respectively. | |
Williams provides certain retiree health care and life insurance benefits for eligible participants that generally were employed by Williams on or before December 31, 1991 or December 31, 1995, if they were employees or retirees of Transco Energy Company and its subsidiaries. We recognized other postretirement benefit income of $4.2 million and $3.0 million for 2013 and 2011, respectively, and cost of $2.5 million for 2012. | |
We have been allowed by rate case settlements to collect or refund in future rates any differences between the actuarially determined costs and amounts currently being recovered in rates related to other postretirement benefits. Any differences between the annual actuarially determined cost and amounts currently being recovered in rates are recorded as an adjustment to expense and collected or refunded through future rate adjustments. The amounts of other postretirement benefits costs deferred as a regulatory liability at December 31, 2013 is $25.3 million and is comprised of $6.6 million being deferred for future rate treatment and $18.7 million being amortized over approximately an 8 year period per Docket No. RP12-993. At December 31, 2012, the amount of other postretirement benefit costs deferred consisted of a regulatory liability of $24.7 million deferred for future rate treatment, and a regulatory asset of $4.6 million which was being amortized over a 10 year period per Docket No. RP06-569. Effective March 1, 2013, the residual regulatory asset balance from the prior rate filing was netted against the accumulated regulatory liability. | |
Defined Contribution Plan. | |
Williams charged us compensation expense of $6.0 million in 2013, $7.2 million in 2012, and $6.9 million in 2011 for Williams’ company matching contributions to this plan. | |
Employee Stock-Based Compensation Plan Information. | |
The Williams Companies, Inc. 2007 Incentive Plan, as amended and restated on February 23, 2010, (Plan) was approved by stockholders on May 20, 2010. The Plan provides for Williams’ common stock based awards to both employees and non-management directors. The Plan permits the granting of various types of awards including, but not limited to, restricted stock units and stock options. Awards may be granted for no consideration other than prior and future services or based on certain financial performance targets achieved. | |
Williams currently bills us directly for compensation expense related to stock-based compensation awards based on the fair value of the awards. We are also billed for our proportionate share of Williams’ and other affiliates’ stock-based compensation expense through various allocation processes. | |
Total stock-based compensation expense for the years ended December 31, 2013, 2012 and 2011 was $3.0 million, $2.8 million and $2.4 million, respectively, excluding amounts allocated from WPZ and Williams. |
Transactions_with_Major_Custom
Transactions with Major Customers and Affiliates (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Transactions with Major Customers and Affiliates [Abstract] | ' | |||||||||||
Transactions with Major Customers and Affiliates | ' | |||||||||||
TRANSACTIONS WITH MAJOR CUSTOMERS AND AFFILIATES. | ||||||||||||
Major Customers. | ||||||||||||
Operating revenues received from our two major customers in 2013, 2012 and 2011 are as follows (in millions): | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Public Service Enterprise Group | $ | 130.7 | $ | 127.4 | $ | 136.7 | ||||||
National Grid | 88.5 | 93.5 | 98.2 | |||||||||
Affiliates. | ||||||||||||
We are a participant in WPZ’s cash management program, and we make advances to and receive advances from WPZ. At December 31, 2013 and 2012, our advances to WPZ totaled approximately $526.4 million and $312.2 million, respectively. These advances are represented by demand notes and are classified as Current Assets in the accompanying Consolidated Balance Sheet. Advances are stated at the historical carrying amounts. Interest income is recognized when chargeable and collectability is reasonably assured. The interest rate on these intercompany demand notes is based upon the daily overnight investment rate paid on WPZ’s excess cash at the end of each month. At December 31, 2013, the interest rate was 0.01 percent. | ||||||||||||
On December 31, 2011, Williams completed the spin-off of its former exploration and production business, WPX, by means of a special stock dividend to its shareholders. Included in our operating revenues and cost of sales listed below for the year 2011 are amounts related to activity with WPX. | ||||||||||||
Included in Operating Revenues in the accompanying Consolidated Statement of Comprehensive Income for 2013, 2012 and 2011 are revenues received from affiliates of $16.3 million, $17.0 million, and $18.5 million, respectively. The rates charged to provide sales and services to affiliates are the same as those that are charged to similarly-situated nonaffiliated customers. | ||||||||||||
Included in Cost of natural gas sales in the accompanying Consolidated Statement of Comprehensive Income for 2013, 2012 and 2011 is purchased gas cost from affiliates of $6.9 million, $3.9 million, and $8.8 million, respectively. All gas purchases are made at market or contract prices. | ||||||||||||
We have no employees. Services necessary to operate our business are provided to us by Williams and certain affiliates of Williams. We reimburse Williams and its affiliates for all direct and indirect expenses incurred or payments made (including salary, bonus, incentive compensation and benefits) in connection with these services. Employees of Williams also provide general, administrative and management services to us, and we are charged for certain administrative expenses incurred by Williams. These charges are either directly identifiable or allocated to our assets. Direct charges are for goods and services provided by Williams at our request. Allocated charges are based on a three-factor formula, which considers revenues; property, plant and equipment; and payroll. In management’s estimation, the allocation methodologies used are reasonable and result in a reasonable allocation to us of our costs of doing business incurred by Williams. We were billed $310.3 million, $320.1 million, and $278.6 million during 2013, 2012 and 2011, respectively, for these services. Such expenses are primarily included in Administrative and general and Operation and maintenance expenses in the accompanying Consolidated Statement of Comprehensive Income. | ||||||||||||
Pursuant to an operating agreement, we serve as contract operator on certain Williams Field Services (WFS) facilities. We recorded reductions in operating expenses for services provided to and reimbursed by WFS of $2.3 million, $4.5 million, and $6.4 million in 2013, 2012 and 2011, respectively, under terms of the operating agreement. In 2013, we received $3.6 million of reimbursements from WFS, related to a capital project. Pursuant to construction agreements, we received pre-payments from WFS of $2.3 million and $4.5 million during 2012 and 2011, respectively, associated with capital projects. We received reimbursements totaling $3.1 million from Williams Gas Processing – Gulf Coast Company, L.P. in 2012 associated with costs related to a transfer and assignment agreement. | ||||||||||||
We made equity distributions of $250 million, $246 million and $219 million during 2013, 2012 and 2011, respectively. In January 2014, an additional distribution of $112 million was declared and paid. | ||||||||||||
During 2013, 2012 and 2011, WPO made contributions totaling $264 million, $150 million and $115 million, respectively, to us to fund a portion of our expenditures for additions to property, plant and equipment. In January 2014, WPO made an additional $54 million contribution. During 2012, we received a non-cash contribution of $1.5 million from WPO. During 2011, we made a non-cash return of capital to WPO of approximately $0.5 million. |
Asset_Retirement_Obligations_N
Asset Retirement Obligations (Notes) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Asset Retirement Obligation Disclosure [Abstract] | ' | ||||||||
Asset Retirement Obligations | ' | ||||||||
ASSET RETIREMENT OBLIGATIONS. | |||||||||
The accrued obligations relate to underground storage caverns, offshore platforms, pipelines, and gas transmission facilities. At the end of the useful life of each respective asset, we are legally obligated to plug storage caverns and remove any related surface equipment, to dismantle offshore platforms, to cap certain gathering pipelines at the wellhead connection and remove any related surface equipment, and to remove certain components of gas transmission facilities from the ground. | |||||||||
During 2013 and 2012, our overall asset retirement obligation changed as follows (in thousands): | |||||||||
2013 | 2012 | ||||||||
Beginning balance | $ | 296,870 | $ | 302,768 | |||||
Accretion | 31,461 | 23,052 | |||||||
New obligations | 2,225 | 2,556 | |||||||
Changes in estimates of existing obligations (1) | (27,628 | ) | 10,895 | ||||||
Property dispositions/obligations settled | (28,941 | ) | (42,401 | ) | |||||
Ending balance | $ | 273,987 | $ | 296,870 | |||||
-1 | The 2013 changes in estimates of existing obligations reflects decreases of $36 million, primarily due to a revision in the estimated remaining life of the assets, which is among several factors considered in the annual review process, including inflation rates, current estimates for removal cost and discount rates. These decreases are partially offset by an increase of $9 million related to changes in the timing and method of abandonment of our Eminence natural gas storage caverns that were associated with a leak in 2010. The 2012 changes in estimates of existing obligations is primarily due to an increase of $13 million related to changes in the timing and method of abandonment of our Eminence natural gas storage caverns that were associated with a leak in 2010. | ||||||||
We are entitled to collect in rates the amounts necessary to fund our ARO. All funds received for such retirements are deposited into an external trust account dedicated to funding our ARO. Under our current rate settlement our annual funding obligation is approximately $36.4 million, with installments to be deposited monthly. |
Regulatory_Assets_and_Liabilit
Regulatory Assets and Liabilities (Notes) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Regulatory Assets and Liabilities Disclosure [Abstract] | ' | ||||||||
Regulatory Assets and Liabilities | ' | ||||||||
REGULATORY ASSETS AND LIABILITIES. | |||||||||
The regulatory assets and regulatory liabilities resulting from our application of the provisions of ASC Topic 980, Regulated Operations, included in the accompanying Consolidated Balance Sheet at December 31, 2013 and December 31, 2012 are as follows (in millions): | |||||||||
Regulatory Assets | 2013 | 2012 | |||||||
Grossed-up deferred taxes on equity funds used during construction | $ | 80.6 | $ | 83.5 | |||||
Asset retirement obligations | 128.5 | 125.1 | |||||||
Asset retirement costs - Eminence | 68.2 | — | |||||||
Deferred taxes | 8.1 | 9.1 | |||||||
Postretirement benefits other than pension | — | 4.6 | |||||||
Fuel cost | 0.7 | 29.3 | |||||||
Other | 8 | — | |||||||
Total Regulatory Assets | $ | 294.1 | $ | 251.6 | |||||
Regulatory Liabilities | 2013 | 2012 | |||||||
Negative salvage | $ | 241.7 | $ | 203.8 | |||||
Deferred cash out | 1.6 | 6.2 | |||||||
Sentinel meter station depreciation | 5 | 3.9 | |||||||
Postretirement benefits other than pension | 25.3 | 24.7 | |||||||
Electric power cost | 13.8 | 7.7 | |||||||
Other | 0.2 | 1.2 | |||||||
Total Regulatory Liabilities | $ | 287.6 | $ | 247.5 | |||||
The significant regulatory assets and liabilities include: | |||||||||
Grossed-up deferred taxes on equity funds used during construction: Regulatory asset balance established to offset the deferred tax for the equity component of the allowance for funds used during the construction of long-lived assets. All amounts were generated during the period that we were a taxable entity. Taxes on capitalized funds used during construction and the offsetting deferred income taxes are included in the rate base and are recovered over the depreciable lives of the long-lived asset to which they relate. | |||||||||
Asset retirement obligations: Regulatory asset balance established to offset depreciation of the ARO asset and changes in the ARO liability due to the passage of time. The regulatory asset is being recovered through our rates, and is being amortized to expense consistent with the amounts collected in rates. | |||||||||
Asset retirement costs - Eminence: Regulatory asset balance associated with the Eminence Storage Field retirement costs. The regulatory asset is being recovered through our rates, and is being amortized to expense consistent with the amounts collected in rates (See Note 10). | |||||||||
Deferred taxes: Regulatory asset balance was established as a result of an increase to rate base deferred taxes due to an increase to the effective state income tax rate. The regulatory asset is being collected from rate payers over the remaining depreciable lives of the long-lived asset to which they relate. | |||||||||
Postretirement benefits: We recover the actuarially determined cost of postretirement benefits through rates that are set through periodic general rate filings. Any difference between the annual actuarially determined cost and the amount recovered in rates is recorded as a regulatory asset or liability to be collected or refunded through future rate adjustments. These amounts are not included in the rate base. | |||||||||
Fuel cost: This amount represents the difference between the gas retained from our customers and the gas consumed in operations. These amounts are not included in the rate base but are expected to be recovered/refunded in subsequent annual fuel tracker filing periods. | |||||||||
Electric power cost: This amount represents the difference between the electric power costs recovered from our customers and the electric power costs incurred in operations. These amounts are not included in the rate base but are expected to be recovered/refunded in subsequent annual electric power tracker filing periods. | |||||||||
Negative salvage: Our rates include a component designed to recover certain future retirement costs for which we are not required to record an asset retirement obligation. We record a regulatory liability representing the cumulative residual amount of recoveries through rates, net of expenditures associated with these retirement costs. | |||||||||
Deferred cash out: This amount represents the deferral of gains or losses on the purchases and sales of gas imbalances with shippers. These amounts are not included in the rate base but are expected to be recovered/refunded in subsequent annual cash out filing periods. | |||||||||
Sentinel meter station depreciation: This amount reflects the incremental depreciation being recorded related to the meter station modifications made for three of the Sentinel shippers. These modifications will be recovered through a surcharge over a defined period of time as stated in the Sentinel FERC order. The incremental depreciation represents the difference between the FERC granted depreciation rate for such facilities in the last rate case as compared to the depreciation rates in the Sentinel order which are based on the contractual terms in the surcharge agreements. The incremental depreciation will be recorded through the end of the contractual term and then will be amortized. |
Other_Notes
Other (Notes) | 12 Months Ended |
Dec. 31, 2013 | |
Other Income and Expenses [Abstract] | ' |
Other | ' |
OTHER. | |
During 2012, we capitalized $8.7 million and $2.4 million, respectively, of project feasibility costs associated with the Rockaway Delivery Lateral Project and the Northeast Connector Project, which had been expensed in prior periods in Other expense, net, upon determining that the projects were probable of development. During 2011, we capitalized $10.1 million of project feasibility costs associated with the Northeast Supply Link Expansion Project, which had been expensed in prior periods in Other expense, net, upon determining that the project was probable of development. These costs will be included in the capital costs of the projects, which we believe are probable of recovery through the projects’ rates. | |
We detected a leak in an underground cavern at our Eminence Storage Field in Mississippi on December 28, 2010. During 2013, 2012 and 2011, we recorded $4.3 million, $2.5 million and $14.6 million, respectively, of charges to Operation and maintenance expenses primarily related to costs to ensure the safety of the surrounding area. | |
Due to the abandonment and retirement of four of the seven caverns at our Eminence Storage Field in 2013 and the expected recovery of such costs in our rates, we have reclassified $92 million of costs related to the Eminence ARO from Total property, plant and equipment, net to Regulatory assets (Eminence abandonment regulatory asset). Included in Other expense, net, for the year 2013, consistent with the Agreement in our Docket No. RP12-993 general rate case proceeding, is a charge of $11.5 million, related to the portion of the Eminence abandonment regulatory asset that will not be recovered in rates. We have also recognized income during 2013 of $16.1 million, related to insurance recoveries associated with this event. |
Summary_of_Significant_Account1
Summary of Significant Accounting Policies (Policies) | 12 Months Ended | ||||
Dec. 31, 2013 | |||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ' | ||||
Regulatory Accounting | ' | ||||
Regulatory Accounting. | |||||
We are regulated by the Federal Energy Regulatory Commission (FERC). The Accounting Standards Codification (ASC) Regulated Operations (Topic 980), provides that rate-regulated public utilities account for and report regulatory assets and liabilities consistent with the economic effect of the way in which regulators establish rates if the rates established are designed to recover the costs of providing the regulated service and if the competitive environment makes it probable that such rates can be charged and collected. Accounting for businesses that are regulated and apply the provisions of Topic 980 can differ from the accounting requirements for non-regulated businesses. Transactions that are recorded differently as a result of regulatory accounting requirements include the capitalization of an equity return component on regulated capital projects, capitalization of other project costs, retirements of general plant assets, employee related benefits, environmental costs, negative salvage, asset retirement obligations, and other costs and taxes included in, or expected to be included in, future rates. As a rate-regulated entity, our management has determined that it is appropriate to apply the accounting prescribed by Topic 980 and, accordingly, the accompanying consolidated financial statements include the effects of the types of transactions described above that result from regulatory accounting requirements. | |||||
Basis of Presentation | ' | ||||
Basis of Presentation. | |||||
Williams’ acquisition of Transco Energy Company and its subsidiaries, including us, in 1995 was accounted for using the purchase method of accounting. Accordingly, an allocation of the purchase price was assigned to our assets and liabilities based on their estimated fair values. The purchase price allocation to us primarily consisted of a $1.5 billion allocation to property, plant and equipment and adjustments to deferred taxes based upon the book basis of the net assets recorded as a result of the acquisition. The amount allocated to property, plant and equipment is being depreciated on a straight-line basis over 40 years, the estimated useful lives of these assets at the date of acquisition, at approximately $35 million per year. At December 31, 2013, the remaining property, plant and equipment allocation was approximately $0.7 billion. Current FERC policy does not permit us to recover through rates amounts in excess of original cost. | |||||
We are a participant in WPZ’s cash management program. We make advances to and receive advances from WPZ. The advances are represented by demand notes. The interest rate on these intercompany demand notes is based upon the daily overnight investment rate paid on WPZ’s excess cash at the end of each month. | |||||
Certain prior period amounts reported within Total operating costs and expenses in the Consolidated Statement of Comprehensive Income have been reclassified to conform to the current presentation. The effect of the correction increased Operation and maintenance costs $7.1 million and $6.8 million for the years ended December 31, 2012 and 2011, respectively, for the reclassification from Taxes-other than income taxes with no net impact on Total operating costs and expenses, Operating Income and Net Income. | |||||
Principles of Consolidation | ' | ||||
Principles of Consolidation. | |||||
The consolidated financial statements include our accounts and the accounts of the subsidiaries we control. Companies in which we and our subsidiaries own 20 percent to 50 percent of the voting common stock or otherwise exercise significant influence over operating and financial policies of the company are accounted for under the equity method. The equity method investments as of December 31, 2013 and December 31, 2012 consist of Cardinal Pipeline Company, LLC (Cardinal) with ownership interest of approximately 45 percent and Pine Needle LNG Company, LLC (Pine Needle) with ownership interest of 35 percent. We received distributions associated with our equity method investments totaling $11.5 million, $14.3 million, and $6.2 million in 2013, 2012 and 2011, respectively. Included in the distributions are $1.4 million return of capital from Pine Needle in 2013 and $11.3 million return of capital from Cardinal in 2012. We made capital contributions to Cardinal related to Cardinal’s expansion project totaling $5.8 million in 2012. | |||||
Use of Estimates | ' | ||||
Use of Estimates. | |||||
The preparation of financial statements in conformity with U.S. generally accepted accounting principles (GAAP) requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. Estimates and assumptions which, in the opinion of management, are significant to the underlying amounts included in the financial statements and for which it would be reasonably possible that future events or information could change those estimates include: 1) revenues subject to refund; 2) litigation-related contingencies; 3) environmental remediation obligations; 4) impairment assessments of long-lived assets; 5) depreciation; and 6) asset retirement obligations. | |||||
Revenue Recognition | ' | ||||
Revenue Recognition. | |||||
Revenues for transportation of gas under long-term firm agreements are recognized considering separately the reservation and commodity charges. Reservation revenues are recognized monthly over the term of the agreement regardless of the volume of natural gas transported. Commodity revenues from both firm and interruptible transportation are recognized in the period transportation services are provided based on volumes of natural gas physically delivered at the agreed upon delivery point. Revenues for the storage of gas under firm agreements are recognized considering separately the reservation, capacity, and injection and withdrawal charges. Reservation and capacity revenues are recognized monthly over the term of the agreement regardless of the volume of storage service actually utilized. Injection and withdrawal revenues are recognized in the period when volumes of natural gas are physically injected into or withdrawn from storage. | |||||
In the course of providing transportation services to customers, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. The resulting imbalances are primarily settled through the purchase and sale of gas with our customers under terms provided for in our FERC tariff. Revenue is recognized from the sale of gas upon settlement of the transportation and exchange imbalances (See Gas Imbalances in this Note). | |||||
As a result of the ratemaking process, certain revenues collected by us may be subject to refunds upon the issuance of final orders by the FERC in pending rate proceedings. We record estimates of rate refund liabilities considering our and other third-party regulatory proceedings, advice of counsel and other risks. | |||||
Environmental Matters | ' | ||||
Environmental Matters. | |||||
We are subject to federal, state, and local environmental laws and regulations. Environmental expenditures are expensed or capitalized depending on their economic benefit and potential for rate recovery. We believe that any expenditures required to meet applicable environmental laws and regulations are prudently incurred in the ordinary course of business and such expenditures would be permitted to be recovered through rates. | |||||
Property, Plant and Equipment | ' | ||||
Property, Plant and Equipment. | |||||
Property, plant and equipment is recorded at cost. The carrying values of these assets are also based on estimates, assumptions and judgments relative to capitalized costs, useful lives and salvage values. These estimates, assumptions and judgments reflect FERC regulations, as well as historical experience and expectations regarding future industry conditions and operations. We account for repair and maintenance costs under the guidance of FERC regulations. The FERC identifies installation, construction and replacement costs that are to be capitalized. All other costs are expensed as incurred. Gains or losses from the ordinary sale or retirement of property, plant and equipment are credited or charged to accumulated depreciation; certain other gains or losses are recorded in operating income. | |||||
We provide for depreciation under the composite (group) method at straight-line FERC prescribed rates that are applied to the cost of the group for transmission facilities, production and gathering facilities and storage facilities. Under this method, assets with similar lives and characteristics are grouped and depreciated as one asset. Included in our depreciation rates is a negative salvage component (net cost of removal) that we currently collect in rates. Our depreciation rates are subject to change each time we file a general rate case with the FERC. Depreciation rates used for major regulated gas plant facilities at December 31, 2013, 2012 and 2011 are as follows: | |||||
Category of Property | 2013 (1) | 2012-2011 | |||
Gathering facilities | 1.35% - 2.50% | 0.18% - 1.66% | |||
Storage facilities | 2.10% - 2.25% | 2.10% - 3.70% | |||
Onshore transmission facilities | 2.61% - 5.00% | 2.79% - 5.71% | |||
Offshore transmission facilities | 1.20% - 1.20% | 1.01% - 1.01% | |||
(1) Changes in depreciation rates in 2013 due to placing into effect, subject to refund, the rates in Docket No. RP12-993 on March 1, 2013. | |||||
We record a liability and increase the basis in the underlying asset for the present value of each expected future asset retirement obligation (ARO) at the time the liability is initially incurred, typically when the asset is acquired or constructed. Measurements of AROs include, as a component of future expected costs, an estimate of the price that a third party would demand, and could expect to receive, for bearing the uncertainties inherent in the obligations, sometimes referred to as a market-risk premium. The ARO asset is depreciated in a manner consistent with the expected timing of the future abandonment of the underlying physical assets. We measure changes in the liability due to passage of time by applying an interest method of allocation. The depreciation of the ARO asset and accretion of the ARO liability are recognized as an increase to a regulatory asset, as management expects to recover such amounts in future rates. The regulatory asset is amortized commensurate with our collection of these costs in rates. | |||||
Impairment of Long-Lived Assets | ' | ||||
Impairment of Long-lived Assets. | |||||
We evaluate the long lived assets of identifiable business activities for impairment when events or changes in circumstances indicate, in our management’s judgment, that the carrying value of such assets may not be recoverable. When an indicator of impairment has occurred we compare our management’s estimate of undiscounted future cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred. We apply a probability-weighted approach to consider the likelihood of different cash flow assumptions and possible outcomes including selling in the near term or holding for the remaining estimated useful life. If an impairment of the carrying value has occurred, we determine the amount of the impairment recognized in the financial statements by estimating the fair value of the assets and recording a loss for the amount that the carrying value exceeds the estimated fair value. | |||||
For assets identified to be disposed of in the future and considered held for sale in accordance with the ASC Property, Plant, and Equipment (Topic 360), we compare the carrying value to the estimated fair value less the cost to sell to determine if recognition of an impairment is required. Until the assets are disposed of, the estimated fair value, which includes estimated cash flows from operations until the assumed date of sale, is recalculated when related events or circumstances change. | |||||
Judgments and assumptions are inherent in our management’s estimate of undiscounted future cash flows used to determine recoverability of an asset and the estimate of an asset’s fair value used to calculate the amount of impairment to recognize. The use of alternate judgments and/or assumptions could result in the recognition of different levels of impairment charges in the financial statements. | |||||
Allowance for Funds Used During Construction | ' | ||||
Allowance for Funds Used During Construction. | |||||
Allowance for funds used during construction (AFUDC) represents the estimated cost of borrowed and equity funds applicable to utility plant in process of construction and are included as a cost of property, plant and equipment because it constitutes an actual cost of construction under established regulatory practices. The FERC has prescribed a formula to be used in computing separate allowances for borrowed and equity AFUDC. The allowance for borrowed funds used during construction was $5.3 million, $6.0 million and $4.7 million, for 2013, 2012 and 2011, respectively. The allowance for equity funds was $13.3 million, $13.2 million, and $10.6 million, for 2013, 2012 and 2011, respectively. | |||||
Income Taxes | ' | ||||
Income Taxes. | |||||
We generally are not a taxable entity for federal or state and local income tax purposes. The tax on net income is generally borne by unitholders of our ultimate parent, WPZ. Net income for financial statement purposes may differ significantly from taxable income of WPZ’s unitholders as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under the WPZ partnership agreement. The aggregated difference in the basis of our assets for financial and tax reporting purposes cannot be readily determined because information regarding each of WPZ’s unitholder’s tax attributes in WPZ is not available to us. | |||||
Accounts Receivable and Allowance for Doubtful Receivables | ' | ||||
Accounts Receivable and Allowance for Doubtful Receivables. | |||||
Accounts receivable are stated at the historical carrying amount net of reserves or write-offs. Our credit risk exposure in the event of nonperformance by the other parties is limited to the face value of the receivables. We perform ongoing credit evaluations of our customers’ financial condition and require collateral from our customers, if necessary. Due to our customer base, we have not historically experienced recurring credit losses in connection with our receivables. Receivables determined to be uncollectible are reserved or written off in the period of determination. | |||||
Gas Imbalances | ' | ||||
Gas Imbalances. | |||||
In the course of providing transportation services to customers, we may receive different quantities of gas from shippers than the quantities delivered on behalf of those shippers. Additionally, we transport gas on various pipeline systems which may deliver different quantities of gas on behalf of us than the quantities of gas received from us. These transactions result in gas transportation and exchange imbalance receivables and payables which are recovered or repaid in cash or through the receipt or delivery of gas in the future and are recorded in the accompanying Consolidated Balance Sheet. Settlement of imbalances requires agreement between the pipelines and shippers as to allocations of volumes to specific transportation contracts and timing of delivery of gas based on operational conditions. Our tariff includes a method whereby most transportation imbalances are settled on a monthly basis. Each month a portion of the imbalances are not identified to specific parties and remain unsettled. These are generally identified to specific parties and settled in subsequent periods. We believe that amounts that remain unidentified to specific parties and unsettled at year end are valid balances that will be settled with no material adverse effect upon our financial position, results of operations or cash flows. Management has implemented a policy of continuing to carry any unidentified transportation and exchange imbalances on the books for a three-year period. At the end of the three year period a final assessment will be made of their continued validity. Absent a valid reason for maintaining the imbalance, any remaining balance will be recognized in income. Certain imbalances are being recovered or repaid in cash or through the receipt or delivery of gas upon agreement of the parties as to the allocation of the gas volumes, and as permitted by pipeline operating conditions. These imbalances have been classified as current assets and current liabilities at December 31, 2013 and 2012. We utilize the average cost method of accounting for gas imbalances. | |||||
Deferred Cash Out. | |||||
Most transportation imbalances are settled in cash on a monthly basis (cash out). We are required by our tariff to refund revenues received from the cash out of transportation imbalances in excess of costs incurred during the annual August through July reporting period. Revenues received in excess of costs incurred are deferred until refunded in accordance with the tariff. | |||||
Inventory | ' | ||||
Gas Inventory. | |||||
We utilize the last-in, first-out (LIFO) method of accounting for inventory gas in storage. If inventories valued using the LIFO cost method were valued at current replacement cost, the amounts would increase by $1.3 million at December 31, 2013. At December 31, 2012, physical withdrawals from the Eminence Storage facility exceeded the customer nominations for withdrawals, resulting in a liability. The basis for determining current cost at the end of each year is the December monthly average gas price delivered to pipelines in Texas and Louisiana. We utilize the average cost method of accounting for gas available for customer nomination. Liquefied natural gas in storage is valued at original cost. | |||||
Materials and Supplies Inventory. | |||||
All inventories are stated at lower of average cost or market. We perform an annual review of Materials and Supplies inventories, including a quarterly analysis of parts that may no longer be useful due to planned replacements of compressor engines and other components on our system. Based on this assessment, we record a reserve for the value of the inventory which can no longer be used for maintenance and repairs on our pipeline. There was a minimal reserve at December 31, 2013 and at December 31, 2012. | |||||
Contingent Liabilities | ' | ||||
Contingent Liabilities. | |||||
We record liabilities for estimated loss contingencies, including environmental matters, when we assess that a loss is probable and the amount of the loss can be reasonably estimated. These liabilities are calculated based upon our assumptions and estimates with respect to the likelihood or amount of loss and upon advice of legal counsel, engineers, or other third parties regarding the probable outcomes of the matters. These calculations are made without consideration of any potential recovery from third-parties. We recognize insurance recoveries or reimbursements from others when realizable. Revisions to these liabilities are generally reflected in income when new or different facts or information become known or circumstances change that affect the previous assumptions or estimates. | |||||
Pension and Other Postretirement Benefits | ' | ||||
Pension and Other Postretirement Benefits. | |||||
We do not have employees. Certain of the costs charged to us by Williams associated with employees who directly support us include costs related to Williams’ pension and other postretirement benefit plans. (See Note 6.) Although the underlying benefit plans of Williams are single-employer plans, we follow multiemployer plan accounting whereby the amount charged to us and thus paid by us, is based on our share of net periodic benefit cost. | |||||
Cash Equivalents | ' | ||||
We include short-term, highly-liquid investments that have an original maturity of three months or less as cash equivalents. |
Fair_Value_Measurements_Polici
Fair Value Measurements (Policies) | 12 Months Ended |
Dec. 31, 2013 | |
Fair Value Disclosures [Abstract] | ' |
Fair Value Measurements | ' |
Fair Value of Methods. | |
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value: | |
Cash and short-term financial assets (advances to affiliates) that have variable interest rates - The carrying amount is a reasonable estimate of fair value due to the short maturity of those instruments. | |
ARO Trust investments - We deposit a portion of our collected rates, pursuant to the Docket No. RP06-569 rate case settlement, into the ARO Trust which is specifically designated to fund future asset retirement obligations. The ARO Trust invests in a portfolio of actively traded mutual funds that are measured at fair value on a recurring basis based on quoted prices in an active market, are classified as available-for-sale, and are reported in Other Assets-Other in the Consolidated Balance Sheet. However, both realized and unrealized gains and losses are ultimately recorded as regulatory assets or liabilities. See Note 4 for more information regarding the ARO Trust. | |
Notes receivable - The disclosed fair value of our notes receivable is determined by an income approach which considers the underlying contract amounts and our assessment of our ability to recover these amounts. The current portion is reported in Trade and other receivables, and the noncurrent portion is reported in Other Assets-Other in the Consolidated Balance Sheet. | |
Long-term debt - The disclosed fair value of our long-term debt is determined by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments. | |
Reclassifications of fair value between Level 1, Level 2, and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. No transfers between Level 1 and Level 2 occurred during the year ended December 31, 2013 or 2012. |
Summary_of_Significant_Account2
Summary of Significant Accounting Policies (Tables) | 12 Months Ended | ||||
Dec. 31, 2013 | |||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ' | ||||
Depreciation rates | ' | ||||
We provide for depreciation under the composite (group) method at straight-line FERC prescribed rates that are applied to the cost of the group for transmission facilities, production and gathering facilities and storage facilities. Under this method, assets with similar lives and characteristics are grouped and depreciated as one asset. Included in our depreciation rates is a negative salvage component (net cost of removal) that we currently collect in rates. Our depreciation rates are subject to change each time we file a general rate case with the FERC. Depreciation rates used for major regulated gas plant facilities at December 31, 2013, 2012 and 2011 are as follows: | |||||
Category of Property | 2013 (1) | 2012-2011 | |||
Gathering facilities | 1.35% - 2.50% | 0.18% - 1.66% | |||
Storage facilities | 2.10% - 2.25% | 2.10% - 3.70% | |||
Onshore transmission facilities | 2.61% - 5.00% | 2.79% - 5.71% | |||
Offshore transmission facilities | 1.20% - 1.20% | 1.01% - 1.01% | |||
(1) Changes in depreciation rates in 2013 due to placing into effect, subject to refund, the rates in Docket No. RP12-993 on March 1, 2013. |
Debt_Financing_Arrangements_an1
Debt, Financing Arrangements and Leases (Tables) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Debt Disclosure [Abstract] | ' | ||||||||
Long-term debt | ' | ||||||||
At December 31, 2013 and 2012, long-term debt issues were outstanding as follows (in thousands): | |||||||||
2013 | 2012 | ||||||||
Debentures: | |||||||||
7.08% due 2026 | $ | 7,500 | $ | 7,500 | |||||
7.25% due 2026 | 200,000 | 200,000 | |||||||
Total debentures | 207,500 | 207,500 | |||||||
Notes: | |||||||||
6.4% due 2016 | 200,000 | 200,000 | |||||||
6.05% due 2018 | 250,000 | 250,000 | |||||||
5.4% due 2041 | 375,000 | 375,000 | |||||||
4.45% due 2042 | 400,000 | 400,000 | |||||||
Total notes | 1,225,000 | 1,225,000 | |||||||
Total long-term debt issues | 1,432,500 | 1,432,500 | |||||||
Unamortized debt premium and discount | (4,145 | ) | (4,177 | ) | |||||
Total long-term debt, less current maturities | $ | 1,428,355 | $ | 1,428,323 | |||||
Maturities of long-term debt | ' | ||||||||
Aggregate minimum maturities (face value) applicable to long-term debt outstanding at December 31, 2013, for the next five years, are as follows (in thousands): | |||||||||
2016: 6.4% Notes | $200,000 | ||||||||
2018: 6.05% Notes | $250,000 | ||||||||
Leases [Abstract] | ' | ||||||||
Future minimum lease payments | ' | ||||||||
The future minimum lease payments under our various operating leases are as follows (in thousands): | |||||||||
2014 | $ | 10,154 | |||||||
2015 | 10,025 | ||||||||
2016 | 10,025 | ||||||||
2017 | 9,971 | ||||||||
2018 | 9,956 | ||||||||
Thereafter | 22,401 | ||||||||
Total net minimum obligations | $ | 72,532 | |||||||
Investments_Tables
Investments (Tables) | 12 Months Ended | ||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||
Investments, Debt and Equity Securities [Abstract] | ' | ||||||||||||||||
Investments | ' | ||||||||||||||||
Investments in available-for-sale securities within the ARO Trust at fair value were as follows (in millions): | |||||||||||||||||
31-Dec-13 | 31-Dec-12 | ||||||||||||||||
Amortized | Fair | Amortized | Fair | ||||||||||||||
Cost Basis | Value | Cost Basis | Value | ||||||||||||||
Cash and Money Market Funds | $ | 6.5 | $ | 6.5 | $ | 1.3 | $ | 1.3 | |||||||||
U.S. Equity Funds | 8 | 11.1 | 5.4 | 7.4 | |||||||||||||
International Equity Funds | 4.2 | 4.9 | 3.4 | 3.8 | |||||||||||||
Municipal Bond Funds | 10.2 | 10.2 | 4.9 | 5.3 | |||||||||||||
Total | $ | 28.9 | $ | 32.7 | $ | 15 | $ | 17.8 | |||||||||
Fair_Value_Measurements_Tables
Fair Value Measurements (Tables) | 12 Months Ended | ||||||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||||||
Fair Value Disclosures [Abstract] | ' | ||||||||||||||||||||
Schedule of fair value, assets and liabilities measured on recurring basis | ' | ||||||||||||||||||||
The following table presents, by level within the fair value hierarchy, certain of our financial assets and liabilities. | |||||||||||||||||||||
Fair Value Measurements Using | |||||||||||||||||||||
Carrying | Fair | Quoted | Significant | Significant | |||||||||||||||||
Amount | Value | Prices In | Other | Unobservable | |||||||||||||||||
Active | Observable | Inputs | |||||||||||||||||||
Markets for | Inputs | (Level 3) | |||||||||||||||||||
Identical | (Level 2) | ||||||||||||||||||||
Assets | |||||||||||||||||||||
(Level 1) | |||||||||||||||||||||
(Millions) | |||||||||||||||||||||
Assets (liabilities) at December 31, 2013: | |||||||||||||||||||||
Measured on a recurring basis: | |||||||||||||||||||||
ARO Trust investments | $ | 32.7 | $ | 32.7 | $ | 32.7 | $ | — | $ | — | |||||||||||
Additional disclosures: | |||||||||||||||||||||
Notes receivable | 6.3 | 6.3 | — | 6.3 | — | ||||||||||||||||
Long-term debt | (1,428.4 | ) | (1,512.9 | ) | — | (1,512.9 | ) | — | |||||||||||||
Assets (liabilities) at December 31, 2012: | |||||||||||||||||||||
Measured on a recurring basis: | |||||||||||||||||||||
ARO Trust investments | $ | 17.8 | $ | 17.8 | $ | 17.8 | $ | — | $ | — | |||||||||||
Additional disclosures: | |||||||||||||||||||||
Notes receivable | 8.2 | 8.2 | — | 8.2 | — | ||||||||||||||||
Long-term debt, including current portion | (1,428.3 | ) | (1,704.5 | ) | — | (1,704.5 | ) | — | |||||||||||||
Transactions_with_Major_Custom1
Transactions with Major Customers and Affiliates (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Transactions with Major Customers and Affiliates [Abstract] | ' | |||||||||||
Schedule of revenue by major customers | ' | |||||||||||
Operating revenues received from our two major customers in 2013, 2012 and 2011 are as follows (in millions): | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Public Service Enterprise Group | $ | 130.7 | $ | 127.4 | $ | 136.7 | ||||||
National Grid | 88.5 | 93.5 | 98.2 | |||||||||
Asset_Retirement_Obligations_T
Asset Retirement Obligations (Tables) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Asset Retirement Obligation Disclosure [Abstract] | ' | ||||||||
Schedule of change in asset retirement obligation | ' | ||||||||
During 2013 and 2012, our overall asset retirement obligation changed as follows (in thousands): | |||||||||
2013 | 2012 | ||||||||
Beginning balance | $ | 296,870 | $ | 302,768 | |||||
Accretion | 31,461 | 23,052 | |||||||
New obligations | 2,225 | 2,556 | |||||||
Changes in estimates of existing obligations (1) | (27,628 | ) | 10,895 | ||||||
Property dispositions/obligations settled | (28,941 | ) | (42,401 | ) | |||||
Ending balance | $ | 273,987 | $ | 296,870 | |||||
-1 | The 2013 changes in estimates of existing obligations reflects decreases of $36 million, primarily due to a revision in the estimated remaining life of the assets, which is among several factors considered in the annual review process, including inflation rates, current estimates for removal cost and discount rates. These decreases are partially offset by an increase of $9 million related to changes in the timing and method of abandonment of our Eminence natural gas storage caverns that were associated with a leak in 2010. The 2012 changes in estimates of existing obligations is primarily due to an increase of $13 million related to changes in the timing and method of abandonment of our Eminence natural gas storage caverns that were associated with a leak in 2010. |
Regulatory_Assets_and_Liabilit1
Regulatory Assets and Liabilities (Tables) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Regulatory Assets and Liabilities Disclosure [Abstract] | ' | ||||||||
Schedule of Regulatory Assets [Table Text Block] | ' | ||||||||
The regulatory assets and regulatory liabilities resulting from our application of the provisions of ASC Topic 980, Regulated Operations, included in the accompanying Consolidated Balance Sheet at December 31, 2013 and December 31, 2012 are as follows (in millions): | |||||||||
Regulatory Assets | 2013 | 2012 | |||||||
Grossed-up deferred taxes on equity funds used during construction | $ | 80.6 | $ | 83.5 | |||||
Asset retirement obligations | 128.5 | 125.1 | |||||||
Asset retirement costs - Eminence | 68.2 | — | |||||||
Deferred taxes | 8.1 | 9.1 | |||||||
Postretirement benefits other than pension | — | 4.6 | |||||||
Fuel cost | 0.7 | 29.3 | |||||||
Other | 8 | — | |||||||
Total Regulatory Assets | $ | 294.1 | $ | 251.6 | |||||
Schedule of Regulatory Liabilities [Table Text Block] | ' | ||||||||
Regulatory Liabilities | 2013 | 2012 | |||||||
Negative salvage | $ | 241.7 | $ | 203.8 | |||||
Deferred cash out | 1.6 | 6.2 | |||||||
Sentinel meter station depreciation | 5 | 3.9 | |||||||
Postretirement benefits other than pension | 25.3 | 24.7 | |||||||
Electric power cost | 13.8 | 7.7 | |||||||
Other | 0.2 | 1.2 | |||||||
Total Regulatory Liabilities | $ | 287.6 | $ | 247.5 | |||||
Summary_of_Significant_Account3
Summary of Significant Accounting Policies (Details) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Corporate Structure and Control | ' | ' | ' |
Parent, total ownership percentage | 64.00% | ' | ' |
Parent, limited partner ownership percentage | 62.00% | ' | ' |
Parent, general partner ownership percentage | 2.00% | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Operating revenues, related party | $16,300,000 | $17,000,000 | $18,500,000 |
Purchase Price Allocation | ' | ' | ' |
Purchase price allocation, gross | 1,500,000,000 | ' | ' |
Purchase price allocation, property, plant and equipment, estimated useful lIfe | '40 years | ' | ' |
Purchase price allocation, depreciation | 35,000,000 | ' | ' |
Purchase price allocation, remaining allocation | 700,000,000 | ' | ' |
Schedule of Equity Method Investments [Line Items] | ' | ' | ' |
Equity method investment, distributions | 11,500,000 | 14,300,000 | 6,200,000 |
Equity method investment, return of capital | 1,438,000 | 11,327,000 | 1,925,000 |
Equity method investment, capital contributions | 0 | 5,806,000 | 14,834,000 |
Capitalized Interest Costs, Including Allowance for Funds Used During Construction [Abstract] | ' | ' | ' |
Allowance for funds used during construction, borrowed | 5,300,000 | 6,000,000 | 4,700,000 |
Allowance for funds used during construction, equity | 13,299,000 | 13,222,000 | 10,588,000 |
Inventory Disclosure [Abstract] | ' | ' | ' |
Excess of replacement cost over LIFO cost | 1,300,000 | ' | ' |
Gathering facilities | Minimum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 1.35% | 0.18% | 0.18% |
Gathering facilities | Maximum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 2.50% | 1.66% | 1.66% |
Storage facilities | Minimum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 2.10% | 2.10% | 2.10% |
Storage facilities | Maximum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 2.25% | 3.70% | 3.70% |
Onshore transmission facilities | Minimum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 2.61% | 2.79% | 2.79% |
Onshore transmission facilities | Maximum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 5.00% | 5.71% | 5.71% |
Offshore transmission facilities | Minimum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 1.20% | 1.01% | 1.01% |
Offshore transmission facilities | Maximum | ' | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' | ' |
Depreciation rates | 1.20% | 1.01% | 1.01% |
Cardinal Pipeline Company, LLC | ' | ' | ' |
Schedule of Equity Method Investments [Line Items] | ' | ' | ' |
Equity method investment, ownership percentage | 45.00% | ' | ' |
Equity method investment, return of capital | ' | 11,300,000 | ' |
Equity method investment, capital contributions | ' | 5,800,000 | ' |
Pine Needle LNG Company, LLC | ' | ' | ' |
Schedule of Equity Method Investments [Line Items] | ' | ' | ' |
Equity method investment, ownership percentage | 35.00% | ' | ' |
Equity method investment, return of capital | 1,400,000 | ' | ' |
Operation and maintenance | ' | ' | ' |
Prior Period Reclassification Adjustment [Line Items] | ' | ' | ' |
Prior period reclassification adjustment | -7,100,000 | -6,800,000 | ' |
Taxes-other than income taxes | ' | ' | ' |
Prior Period Reclassification Adjustment [Line Items] | ' | ' | ' |
Prior period reclassification adjustment | 7,100,000 | 6,800,000 | ' |
Total operating costs and expenses | ' | ' | ' |
Prior Period Reclassification Adjustment [Line Items] | ' | ' | ' |
Prior period reclassification adjustment | 0 | 0 | ' |
Operating Income | ' | ' | ' |
Prior Period Reclassification Adjustment [Line Items] | ' | ' | ' |
Prior period reclassification adjustment | 0 | 0 | ' |
Net Income | ' | ' | ' |
Prior Period Reclassification Adjustment [Line Items] | ' | ' | ' |
Prior period reclassification adjustment | 0 | 0 | ' |
Common management [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Operating revenues, related party | $130,700,000 | ' | ' |
Contingent_Liabilities_and_Com1
Contingent Liabilities and Commitments (Details) (USD $) | 12 Months Ended | |
Dec. 31, 2013 | Dec. 31, 2012 | |
Site Contingency [Line Items] | ' | ' |
Regulatory assets, total | $294,100,000 | $251,600,000 |
Regulatory assets, current | 37,520,000 | 36,706,000 |
Regulatory assets, noncurrent | 256,612,000 | 214,912,000 |
Other Commitments [Abstract] | ' | ' |
Commitments for construction and acquisition of property, plant, and equipment | 368,000,000 | ' |
Environmental assessment and remediation | ' | ' |
Site Contingency [Line Items] | ' | ' |
Environmental assessment and remediation costs, low estimate | 6,000,000 | ' |
Environmental assessment and remediation costs, high estimate | 8,000,000 | ' |
Accrued environmental assessment and remediation costs, total | 4,100,000 | 3,300,000 |
Accrued environmental assessment and remediation costs, current | 2,300,000 | 1,100,000 |
Accrued environmental assessment and remediation costs, noncurrent | 1,800,000 | 2,200,000 |
Regulatory assets, total | 1,800,000 | 0 |
Regulatory assets, current | 1,200,000 | ' |
Regulatory assets, noncurrent | 600,000 | ' |
Environmental assessment and remediation | Minimum | ' | ' |
Site Contingency [Line Items] | ' | ' |
Expected duration of environmental assessment and remediation spending | '3 years | ' |
Environmental assessment and remediation | Maximum | ' | ' |
Site Contingency [Line Items] | ' | ' |
Expected duration of environmental assessment and remediation spending | '5 years | ' |
Potentially responsible party at various Superfund and state waste disposal sites | ' | ' |
Site Contingency [Line Items] | ' | ' |
Environmental assessment and remediation costs, high estimate | $500,000 | ' |
Debt_Financing_Arrangements_an2
Debt, Financing Arrangements and Leases (Details) (USD $) | 12 Months Ended | 12 Months Ended | 12 Months Ended | ||||||||||||||||||||||||||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | Dec. 31, 2013 | Jul. 31, 2013 | Dec. 31, 2013 | Jul. 31, 2013 | Dec. 31, 2013 | Jul. 31, 2013 | Jul. 31, 2013 | Dec. 31, 2013 | Jul. 13, 2012 | Jul. 15, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | |
Williams Partners L.P. [Member] | $2.4 billion credit facility [Member] | $2.5 billion credit facility [Member] | $2.5 billion credit facility [Member] | $2.5 billion credit facility [Member] | $2.5 billion credit facility [Member] | $2.5 billion credit facility [Member] | Commercial paper [Member] | 4.45% senior unsecured notes due 2042 [Member] | 8.875% senior unsecured notes due 2012 [Member] | Debentures | Debentures | Debentures | Debentures | Debentures | Debentures | Notes | Notes | Notes | Notes | Notes | Notes | Notes | Notes | Notes | Notes | ||||
Williams Partners L.P. [Member] | Williams Partners L.P. [Member] | Williams Partners L.P. [Member] | Williams Partners L.P. [Member] | Williams Partners L.P. [Member] | 7.08% due 2026 [Member] | 7.08% due 2026 [Member] | 7.25% due 2026 [Member] | 7.25% due 2026 [Member] | 6.4% due 2016 [Member] | 6.4% due 2016 [Member] | 6.05% due 2018 [Member] | 6.05% due 2018 [Member] | 5.4% due 2041 [Member] | 5.4% due 2041 [Member] | 4.45% due 2042 [Member] | 4.45% due 2042 [Member] | |||||||||||||
Letter of credit [Member] | |||||||||||||||||||||||||||||
Debt Instrument [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total long-term debt issues | $1,432,500,000 | $1,432,500,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | $207,500,000 | $207,500,000 | $7,500,000 | $7,500,000 | $200,000,000 | $200,000,000 | $1,225,000,000 | $1,225,000,000 | $200,000,000 | $200,000,000 | $250,000,000 | $250,000,000 | $375,000,000 | $375,000,000 | $400,000,000 | $400,000,000 |
Unamortized debt premium and discount | -4,145,000 | -4,177,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total long-term debt, less current maturities | 1,428,355,000 | 1,428,323,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Debt instrument, face amount | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 400,000,000 | 325,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Debt instrument, interest rate, stated percentage | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 4.45% | 8.88% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Long-term Debt, Fiscal Year Maturity [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2014 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2015 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2016: 6.4% Notes | 200,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2017 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2018: 6.05% Notes | 250,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Line of Credit Facility [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Line of credit facility, maximum borrowing capacity | ' | ' | ' | ' | 2,400,000,000 | ' | 500,000,000 | ' | 2,500,000,000 | 1,300,000,000 | 2,000,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Additional amount by which credit facility can be increased | ' | ' | ' | ' | ' | ' | ' | ' | 500,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Letters of credit outstanding, amount | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Line of credit facility, amount outstanding | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Line of credit facility, remaining borrowing capacity | ' | ' | ' | ' | ' | 500,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Debt to EBITDA, ratio | ' | ' | ' | ' | ' | ' | ' | 5 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Debt to EBITDA, after acquisitions, ratio | ' | ' | ' | ' | ' | ' | ' | 5.5 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Purchase price of acquistions increasing debt to EBITDA ratio, aggregate | ' | ' | ' | ' | ' | ' | ' | 50,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Ratio of indebtedness to net capital | 0.65 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Line of credit facility, unused capacity, commitment fee percentage | ' | ' | ' | ' | ' | 0.20% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Commercial paper | ' | ' | ' | 225,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2014 | 10,154,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2015 | 10,025,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2016 | 10,025,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2017 | 9,971,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
2018 | 9,956,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Thereafter | 22,401,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total net minimum obligations | 72,532,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating leases, rent expense | $11,400,000 | $10,900,000 | $9,100,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Investments_Details
Investments (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Investments, Debt and Equity Securities [Abstract] | ' | ' |
Annual funding obligation | $36.40 | ' |
Schedule of Available-for-sale Securities [Line Items] | ' | ' |
Available-for-sale securities, amortized cost basis | 28.9 | 15 |
Available-for-sale securities, fair value | 32.7 | 17.8 |
Cash And Money Market Funds [Member] | ' | ' |
Schedule of Available-for-sale Securities [Line Items] | ' | ' |
Available-for-sale securities, amortized cost basis | 6.5 | 1.3 |
Available-for-sale securities, fair value | 6.5 | 1.3 |
U.S. Equity Funds [Member] | ' | ' |
Schedule of Available-for-sale Securities [Line Items] | ' | ' |
Available-for-sale securities, amortized cost basis | 8 | 5.4 |
Available-for-sale securities, fair value | 11.1 | 7.4 |
International Equity Funds [Member] | ' | ' |
Schedule of Available-for-sale Securities [Line Items] | ' | ' |
Available-for-sale securities, amortized cost basis | 4.2 | 3.4 |
Available-for-sale securities, fair value | 4.9 | 3.8 |
Municipal Bond Funds [Member] | ' | ' |
Schedule of Available-for-sale Securities [Line Items] | ' | ' |
Available-for-sale securities, amortized cost basis | 10.2 | 4.9 |
Available-for-sale securities, fair value | $10.20 | $5.30 |
Fair_Value_Measurements_Detail
Fair Value Measurements (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ' | ' |
ARO Trust investments | $32,700,000 | $17,800,000 |
Fair Value, Transfers Between Level 1 and Level 2, Description and Policy [Abstract] | ' | ' |
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount | 0 | 0 |
Fair Value, Assets, Level 2 to Level 1 Transfers, Amount | 0 | 0 |
Fair Value, Liabilities, Level 1 to Level 2 Transfers, Amount | 0 | 0 |
Fair Value, Liabilities, Level 2 to Level 1 Transfers, Amount | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | ' | ' |
Additional Fair Value Elements [Abstract] | ' | ' |
Notes Receivable, Fair Value Disclosure | 0 | 0 |
Long-term Debt, Fair Value | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | ' | ' |
Additional Fair Value Elements [Abstract] | ' | ' |
Notes Receivable, Fair Value Disclosure | 6,300,000 | 8,200,000 |
Long-term Debt, Fair Value | -1,512,900,000 | -1,704,500,000 |
Fair Value, Inputs, Level 3 [Member] | ' | ' |
Additional Fair Value Elements [Abstract] | ' | ' |
Notes Receivable, Fair Value Disclosure | 0 | 0 |
Long-term Debt, Fair Value | 0 | 0 |
Reported Value Measurement [Member] | ' | ' |
Additional Fair Value Elements [Abstract] | ' | ' |
Notes Receivable, Fair Value Disclosure | 6,300,000 | 8,200,000 |
Long-term Debt, Fair Value | -1,428,400,000 | -1,428,300,000 |
Estimate of Fair Value Measurement [Member] | ' | ' |
Additional Fair Value Elements [Abstract] | ' | ' |
Notes Receivable, Fair Value Disclosure | 6,300,000 | 8,200,000 |
Long-term Debt, Fair Value | -1,512,900,000 | -1,704,500,000 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ' | ' |
ARO Trust investments | 32,700,000 | 17,800,000 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ' | ' |
ARO Trust investments | 0 | 0 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ' | ' |
ARO Trust investments | 0 | 0 |
Fair Value, Measurements, Recurring [Member] | Reported Value Measurement [Member] | ' | ' |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ' | ' |
ARO Trust investments | 32,700,000 | 17,800,000 |
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value Measurement [Member] | ' | ' |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ' | ' |
ARO Trust investments | $32,700,000 | $17,800,000 |
Benefit_Plans_Details
Benefit Plans (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Pension and Other Postretirement Benefit Expense [Abstract] | ' | ' | ' |
Pension cost | $22.30 | $20.30 | $16.40 |
Other postretirement benefit (income) expense | -4.2 | 2.5 | -3 |
Defined contribution plan, cost recognized | 6 | 7.2 | 6.9 |
Regulatory Assets [Line Items] | ' | ' | ' |
Regulatory assets | 294.1 | 251.6 | ' |
Regulatory Liabilities [Line Items] | ' | ' | ' |
Regulatory liabilities | 287.6 | 247.5 | ' |
Salaries, Wages and Officers' Compensation [Abstract] | ' | ' | ' |
Allocated share-based compensation expense | 3 | 2.8 | 2.4 |
Other postretirement benefits [Member] | ' | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' | ' |
Regulatory liabilities | 25.3 | 24.7 | ' |
Regulatory liability, deferred for future rate treatment | 6.6 | ' | ' |
Regulatory liability, being amortized | 18.7 | ' | ' |
Other postretirement benefits [Member] | ' | ' | ' |
Regulatory Assets [Line Items] | ' | ' | ' |
Regulatory assets | $0 | $4.60 | ' |
Transactions_with_Major_Custom2
Transactions with Major Customers and Affiliates (Details) (USD $) | 1 Months Ended | 12 Months Ended | ||
Jan. 31, 2014 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
employee | ||||
Related Party Transaction [Line Items] | ' | ' | ' | ' |
Advances to affiliate | ' | $526,380,000 | $312,165,000 | ' |
Related party transaction, rate | ' | 0.01% | ' | ' |
Operating revenues, related party | ' | 16,300,000 | 17,000,000 | 18,500,000 |
Purchases, related party | ' | 6,900,000 | 3,900,000 | 8,800,000 |
Entity number of employees | ' | 0 | ' | ' |
Expenses, related party | ' | 310,300,000 | 320,100,000 | 278,600,000 |
Equity distributions | 112,000,000 | 250,000,000 | 246,259,000 | 219,000,000 |
Cash contributions from parent | ' | 264,000,000 | 150,000,000 | 115,000,000 |
Public Service Enterprise Group [Member] | ' | ' | ' | ' |
Revenue, Major Customer [Line Items] | ' | ' | ' | ' |
Operating revenues | ' | 130,700,000 | 127,400,000 | 136,700,000 |
National Grid [Member] | ' | ' | ' | ' |
Revenue, Major Customer [Line Items] | ' | ' | ' | ' |
Operating revenues | ' | 88,500,000 | 93,500,000 | 98,200,000 |
Williams Partners L.P. [Member] | ' | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' | ' |
Advances to affiliate | ' | 526,400,000 | 312,200,000 | ' |
Williams Field Services [Member] | ' | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' | ' |
Expenses, related party | ' | -2,300,000 | -4,500,000 | -6,400,000 |
Reimbursements and pre-payments for capital projects | ' | 3,600,000 | 2,300,000 | 4,500,000 |
Williams Gas Processing - Gulf Coast Company, L.P. [Member] | ' | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' | ' |
Reimbursement | ' | ' | 3,100,000 | ' |
Williams Partners Operating LLC [Member] | ' | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' | ' |
Cash contributions from parent | 54,000,000 | 264,000,000 | 150,000,000 | 115,000,000 |
Non-cash contributions from parent | ' | ' | 1,500,000 | ' |
Non-cash return of capital to parent | ' | ' | ' | $500,000 |
Asset_Retirement_Obligations_D
Asset Retirement Obligations (Details) (USD $) | 12 Months Ended | |
Dec. 31, 2013 | Dec. 31, 2012 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
Beginning balance | $296,870,000 | $302,768,000 |
Accretion | 31,461,000 | 23,052,000 |
New obligations | 2,225,000 | 2,556,000 |
Changes in estimates of existing obligations (1) | -27,628,000 | 10,895,000 |
Property dispositions/obligations settled | -28,941,000 | -42,401,000 |
Ending balance | 273,987,000 | 296,870,000 |
Annual funding obligation | 36,400,000 | ' |
Asset retirement obligation [Member] | ' | ' |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
Changes in estimates of existing obligations (1) | -36,000,000 | ' |
Eminence natural gas storage caverns [Member] | ' | ' |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
Changes in estimates of existing obligations (1) | 9,000,000 | 13,000,000 |
External ARO trust [Member] | ' | ' |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
Annual funding obligation | $36,400,000 | ' |
Regulatory_Assets_and_Liabilit2
Regulatory Assets and Liabilities (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | $294.10 | $251.60 |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 287.6 | 247.5 |
Negative salvage | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 241.7 | 203.8 |
Deferred cash out | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 1.6 | 6.2 |
Sentinel meter station depreciation | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 5 | 3.9 |
Postretirement benefits other than pension | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 25.3 | 24.7 |
Electric power cost | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 13.8 | 7.7 |
Other | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory liabilities | 0.2 | 1.2 |
Grossed-up deferred taxes on equity funds used during construction | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | 80.6 | 83.5 |
Asset retirement obligations | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | 128.5 | 125.1 |
Asset retirement costs - Eminence | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | 68.2 | 0 |
Deferred taxes | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | 8.1 | 9.1 |
Postretirement benefits other than pension | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | 0 | 4.6 |
Fuel cost | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | 0.7 | 29.3 |
Other | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory assets | $8 | $0 |
Other_Details
Other (Details) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Property, Plant and Equipment [Line Items] | ' | ' | ' |
Total property, plant and equipment, net | $5,777,392,000 | $5,551,913,000 | ' |
Other expense, net | -32,606,000 | -21,230,000 | -12,988,000 |
Operation and maintenance | 264,631,000 | 299,734,000 | 281,496,000 |
Regulatory assets | 294,100,000 | 251,600,000 | ' |
Rockaway Delivery Lateral Project [Member] | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' |
Total property, plant and equipment, net | ' | 8,700,000 | ' |
Other expense, net | ' | 8,700,000 | ' |
Northeast Connector Project [Member] | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' |
Total property, plant and equipment, net | ' | 2,400,000 | ' |
Other expense, net | ' | 2,400,000 | ' |
Northeast Supply Link Expansion Project [Member] | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' |
Total property, plant and equipment, net | ' | ' | 10,100,000 |
Other expense, net | ' | ' | 10,100,000 |
Eminence Storage Field [Member] | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' |
Total property, plant and equipment, net | -92,000,000 | ' | ' |
Other expense, net | -11,500,000 | ' | ' |
Operation and maintenance | 4,300,000 | 2,500,000 | 14,600,000 |
Regulatory assets | 92,000,000 | ' | ' |
Insurance recoveries | $16,100,000 | ' | ' |