Document_and_Entity_Informatio
Document and Entity Information | 3 Months Ended | |
Mar. 31, 2014 | 5-May-14 | |
Document and Entity Information [Abstract] | ' | ' |
Entity Registrant Name | 'SOUTHWESTERN PUBLIC SERVICE CO | ' |
Entity Central Index Key | '0000092521 | ' |
Current Fiscal Year End Date | '--12-31 | ' |
Entity Well-known Seasoned Issuer | 'No | ' |
Entity Voluntary Filers | 'No | ' |
Entity Current Reporting Status | 'Yes | ' |
Entity Filer Category | 'Non-accelerated Filer | ' |
Document Type | '10-Q | ' |
Document Period End Date | 31-Mar-14 | ' |
Document Fiscal Year Focus | '2014 | ' |
Document Fiscal Period Focus | 'Q1 | ' |
Amendment Flag | 'false | ' |
Entity Common Stock, Shares Outstanding | ' | 100 |
STATEMENTS_OF_INCOME_UNAUDITED
STATEMENTS OF INCOME (UNAUDITED) (USD $) | 3 Months Ended | |
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 |
Income Statement [Abstract] | ' | ' |
Operating revenues | $448,400 | $374,257 |
Operating expenses | ' | ' |
Electric fuel and purchased power | 289,204 | 231,234 |
Operating and maintenance expenses | 69,398 | 64,570 |
Demand side management program expenses | 3,064 | 3,040 |
Depreciation and amortization | 30,512 | 30,205 |
Taxes (other than income taxes) | 13,646 | 12,149 |
Total operating expenses | 405,824 | 341,198 |
Operating income | 42,576 | 33,059 |
Other income (expense), net | 41 | -48 |
Allowance for funds used during construction — equity | 3,640 | 2,622 |
Interest charges and financing costs | ' | ' |
Interest charges — includes other financing costs of $730 and $736, respectively | 19,281 | 17,773 |
Allowance for funds used during construction — debt | -2,127 | -1,609 |
Total interest charges and financing costs | 17,154 | 16,164 |
Income before income taxes | 29,103 | 19,469 |
Income taxes | 10,368 | 6,885 |
Net income | $18,735 | $12,584 |
STATEMENTS_OF_INCOME_UNAUDITED1
STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) (USD $) | 3 Months Ended | |
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 |
Interest charges and financing costs | ' | ' |
Other financing costs | $730 | $736 |
STATEMENTS_OF_COMPREHENSIVE_IN
STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $) | 3 Months Ended | |
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 |
Comprehensive income: | ' | ' |
Net income | $18,735 | $12,584 |
Derivative instruments: | ' | ' |
Reclassification of losses to net income, net of tax of $24 for each of the three months ended March 31, 2014 and 2013 | 43 | 42 |
Other comprehensive income | 43 | 42 |
Comprehensive income | $18,778 | $12,626 |
STATEMENTS_OF_COMPREHENSIVE_IN1
STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) (USD $) | 3 Months Ended | |
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 |
Derivative instruments: | ' | ' |
Reclassification of losses to net income, tax | $24 | $24 |
STATEMENTS_OF_CASH_FLOWS_UNAUD
STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $) | 3 Months Ended | |
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 |
Operating activities | ' | ' |
Net income | $18,735 | $12,584 |
Adjustments to reconcile net income to cash provided by operating activities: | ' | ' |
Depreciation and amortization | 31,059 | 30,724 |
Demand side management program amortization | 418 | 418 |
Deferred income taxes | 22,166 | 10,433 |
Amortization of investment tax credits | -85 | -82 |
Allowance for equity funds used during construction | -3,640 | -2,622 |
Net derivative losses | 66 | 66 |
Changes in operating assets and liabilities: | ' | ' |
Accounts receivable | 12,526 | 4,777 |
Accrued unbilled revenues | -2,413 | -7,384 |
Inventories | 5,131 | 6,856 |
Prepayments and other | -15,455 | -10,870 |
Accounts payable | 9,454 | 11,987 |
Net regulatory assets and liabilities | -16,994 | -7,047 |
Other current liabilities | 3,908 | 6,556 |
Pension and other employee benefit obligations | -3,513 | -20,739 |
Change in other noncurrent assets | 2,951 | -2,593 |
Change in other noncurrent liabilities | 1,758 | -2,683 |
Net cash provided by operating activities | 66,072 | 30,381 |
Investing activities | ' | ' |
Utility capital/construction expenditures | -137,637 | -106,376 |
Allowance for equity funds used during construction | 3,640 | 2,622 |
Investments in utility money pool arrangement | -10,000 | -12,000 |
Repayments from utility money pool arrangement | 10,000 | 12,000 |
Net cash used in investing activities | -133,997 | -103,754 |
Financing activities | ' | ' |
(Repayments of) proceeds from short-term borrowings, net | -15,000 | 7,000 |
Borrowings under utility money pool arrangement | 231,000 | 49,000 |
Repayments under utility money pool arrangement | -169,000 | -29,000 |
Capital contributions from parent | 40,000 | 65,000 |
Dividends paid to parent | -18,082 | -16,773 |
Net cash provided by financing activities | 68,918 | 75,227 |
Net change in cash and cash equivalents | 993 | 1,854 |
Cash and cash equivalents at beginning of period | 1,011 | 482 |
Cash and cash equivalents at end of period | 2,004 | 2,336 |
Supplemental disclosure of cash flow information: | ' | ' |
Cash paid for interest (net of amounts capitalized) | -7,570 | -5,171 |
Cash (paid) received for income taxes, net | -2,522 | 1,015 |
Supplemental disclosure of non-cash investing transactions: | ' | ' |
Property, plant and equipment additions in accounts payable | $30,938 | $31,586 |
BALANCE_SHEETS_UNAUDITED
BALANCE SHEETS (UNAUDITED) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
In Thousands, unless otherwise specified | ||
Current assets | ' | ' |
Cash and cash equivalents | $2,004 | $1,011 |
Accounts receivable, net | 67,734 | 70,951 |
Accounts receivable from affiliates | 6,531 | 15,840 |
Accrued unbilled revenues | 111,620 | 109,207 |
Inventories | 32,007 | 37,138 |
Regulatory assets | 30,416 | 27,595 |
Derivative instruments | 13,684 | 17,826 |
Deferred income taxes | 69,655 | 85,362 |
Prepayments and other | 35,026 | 19,571 |
Total current assets | 368,677 | 384,501 |
Property, plant and equipment, net | 3,395,274 | 3,284,030 |
Other assets | ' | ' |
Regulatory assets | 282,654 | 290,415 |
Derivative instruments | 39,083 | 41,056 |
Other | 14,671 | 17,068 |
Total other assets | 336,408 | 348,539 |
Total assets | 4,100,359 | 4,017,070 |
Current liabilities | ' | ' |
Short-term debt | 69,000 | 84,000 |
Borrowings under utility money pool arrangement | 100,000 | 38,000 |
Accounts payable | 162,544 | 143,879 |
Accounts payable to affiliates | 13,809 | 15,387 |
Regulatory liabilities | 60,633 | 83,759 |
Taxes accrued | 16,262 | 23,584 |
Accrued interest | 25,853 | 16,883 |
Dividends payable | 18,181 | 18,082 |
Derivative instruments | 3,574 | 3,583 |
Other | 77,036 | 75,355 |
Total current liabilities | 546,892 | 502,512 |
Deferred credits and other liabilities | ' | ' |
Deferred income taxes | 765,720 | 757,778 |
Regulatory liabilities | 74,258 | 81,504 |
Asset retirement obligations | 19,644 | 19,375 |
Derivative instruments | 33,316 | 34,207 |
Pension and employee benefit obligations | 51,574 | 55,087 |
Other | 4,730 | 3,051 |
Total deferred credits and other liabilities | 949,242 | 951,002 |
Commitments and contingencies | ' | ' |
Capitalization | ' | ' |
Long-term debt | 1,199,937 | 1,199,865 |
Common stock — 200 shares authorized of $1.00 par value; 100 shares outstanding at March 31, 2014 and Dec. 31, 2013, respectively | 0 | 0 |
Additional paid in capital | 1,045,463 | 1,005,463 |
Retained earnings | 359,943 | 359,389 |
Accumulated other comprehensive loss | -1,118 | -1,161 |
Total common stockholder’s equity | 1,404,288 | 1,363,691 |
Total liabilities and equity | $4,100,359 | $4,017,070 |
BALANCE_SHEETS_UNAUDITED_Paren
BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
Capitalization, Long-term Debt and Equity [Abstract] | ' | ' |
Common stock, shares authorized (in shares) | 200 | 200 |
Common stock, par value (in dollars per share) | $1 | $1 |
Common stock, shares outstanding (in shares) | 100 | 100 |
Managements_Opinion
Management's Opinion | 3 Months Ended |
Mar. 31, 2014 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ' |
Management's Opinion | ' |
In the opinion of management, the accompanying unaudited financial statements contain all adjustments necessary to present fairly, in accordance with accounting principles generally accepted in the United States of America (GAAP), the financial position of SPS as of March 31, 2014, and Dec. 31, 2013; the results of its operations, including the components of net income and comprehensive income, for the three months ended March 31, 2014 and 2013; and its cash flows for the three months ended March 31, 2014 and 2013. All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after March 31, 2014 up to the date of issuance of these financial statements. These statements contain all necessary adjustments and disclosures resulting from that evaluation. The Dec. 31, 2013 balance sheet information has been derived from the audited 2013 financial statements included in the SPS Annual Report on Form 10-K for the year ended Dec. 31, 2013. These notes to the financial statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP on an annual basis have been condensed or omitted pursuant to such rules and regulations. For further information, refer to the financial statements and notes thereto included in the SPS Annual Report on Form 10-K for the year ended Dec. 31, 2013, filed with the SEC on Feb. 24, 2014. Due to the seasonality of SPS’ electric sales, interim results are not necessarily an appropriate base from which to project annual results. |
Summary_of_Significant_Account
Summary of Significant Accounting Policies | 3 Months Ended |
Mar. 31, 2014 | |
Accounting Policies [Abstract] | ' |
Summary of Significant Accounting Policies | ' |
Summary of Significant Accounting Policies | |
The significant accounting policies set forth in Note 1 to the financial statements in the SPS Annual Report on Form 10-K for the year ended Dec. 31, 2013, appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference. |
Accounting_Pronouncements
Accounting Pronouncements | 3 Months Ended |
Mar. 31, 2014 | |
New Accounting Pronouncements and Changes in Accounting Principles [Abstract] | ' |
Accounting Pronouncements | ' |
Accounting Pronouncements | |
Recently issued accounting pronouncements that have been adopted in the current period did not materially impact the financial statements, and no material impact is expected from accounting pronouncements issued and pending implementation. |
Selected_Balance_Sheet_Data
Selected Balance Sheet Data | 3 Months Ended | ||||||||
Mar. 31, 2014 | |||||||||
Balance Sheet Related Disclosures [Abstract] | ' | ||||||||
Selected Balance Sheet Data | ' | ||||||||
Selected Balance Sheet Data | |||||||||
(Thousands of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Accounts receivable, net | |||||||||
Accounts receivable | $ | 73,543 | $ | 76,426 | |||||
Less allowance for bad debts | (5,809 | ) | (5,475 | ) | |||||
$ | 67,734 | $ | 70,951 | ||||||
(Thousands of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Inventories | |||||||||
Materials and supplies | $ | 24,011 | $ | 21,600 | |||||
Fuel | 7,996 | 15,538 | |||||||
$ | 32,007 | $ | 37,138 | ||||||
(Thousands of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Property, plant and equipment, net | |||||||||
Electric plant | $ | 4,789,975 | $ | 4,714,398 | |||||
Construction work in progress | 445,751 | 388,323 | |||||||
Total property, plant and equipment | 5,235,726 | 5,102,721 | |||||||
Less accumulated depreciation | (1,840,452 | ) | (1,818,691 | ) | |||||
$ | 3,395,274 | $ | 3,284,030 | ||||||
Income_Taxes
Income Taxes | 3 Months Ended | ||||||||
Mar. 31, 2014 | |||||||||
Income Tax Disclosure [Abstract] | ' | ||||||||
Income Taxes | ' | ||||||||
Income Taxes | |||||||||
Except to the extent noted below, the circumstances set forth in Note 6 to the financial statements included in SPS’ Annual Report on Form 10-K for the year ended Dec. 31, 2013 appropriately represent, in all material respects, the current status of other income tax matters, and are incorporated herein by reference. | |||||||||
Federal Audit — SPS is a member of the Xcel Energy affiliated group that files a consolidated federal income tax return. The statute of limitations applicable to Xcel Energy’s 2008 federal income tax return expired in September 2012. The statute of limitations applicable to Xcel Energy’s 2009 federal income tax return expires in June 2015. In the third quarter of 2012, the Internal Revenue Service (IRS) commenced an examination of tax years 2010 and 2011, including the 2009 carryback claim. As of March 31, 2014, the IRS had proposed an adjustment to the federal tax loss carryback claims that would result in $10 million of income tax expense for the 2009 through 2011 claims and the anticipated claim for 2013. SPS is not expected to accrue any income tax expense related to this adjustment. Xcel Energy is continuing to work through the audit process, but the outcome and timing of a resolution is uncertain. | |||||||||
State Audits — SPS is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of March 31, 2014, SPS’ earliest open tax year that is subject to examination by state taxing authorities under applicable statutes of limitations is 2009. There are currently no state income tax audits in progress. | |||||||||
Unrecognized Tax Benefits — The unrecognized tax benefit balance includes permanent tax positions, which if recognized would affect the annual effective tax rate (ETR). In addition, the unrecognized tax benefit balance includes temporary tax positions for which the ultimate deductibility is highly certain but for which there is uncertainty about the timing of such deductibility. A change in the period of deductibility would not affect the ETR but would accelerate the payment of cash to the taxing authority to an earlier period. | |||||||||
A reconciliation of the amount of unrecognized tax benefit is as follows: | |||||||||
(Millions of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Unrecognized tax benefit — Permanent tax positions | $ | 0.2 | $ | 1.2 | |||||
Unrecognized tax benefit — Temporary tax positions | 2.3 | 2.9 | |||||||
Total unrecognized tax benefit | $ | 2.5 | $ | 4.1 | |||||
The unrecognized tax benefit amounts were reduced by the tax benefits associated with net operating loss (NOL) and tax credit carryforwards. The amounts of tax benefits associated with NOL and tax credit carryforwards are as follows: | |||||||||
(Millions of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
NOL and tax credit carryforwards | $ | (1.3 | ) | $ | (2.4 | ) | |||
It is reasonably possible that SPS’ amount of unrecognized tax benefits could significantly change in the next 12 months as the IRS audit progresses and state audits resume. As the IRS examination moves closer to completion, the change in the unrecognized tax benefit is not expected to be material. | |||||||||
The payable for interest related to unrecognized tax benefits is partially offset by the interest benefit associated with NOL and tax credit carryforwards. The payables for interest related to unrecognized tax benefits at March 31, 2014 and Dec. 31, 2013 were not material. No amounts were accrued for penalties related to unrecognized tax benefits as of March 31, 2014 or Dec. 31, 2013. |
Rate_Matters
Rate Matters | 3 Months Ended | ||||
Mar. 31, 2014 | |||||
Public Utilities, General Disclosures [Abstract] | ' | ||||
Rate Matters | ' | ||||
Rate Matters | |||||
Except to the extent noted below, the circumstances set forth in Note 10 to the financial statements included in SPS’ Annual Report on Form 10-K for the year ended Dec. 31, 2013 appropriately represent, in all material respects, the current status of other rate matters, and are incorporated herein by reference. | |||||
Pending Regulatory Proceedings — Public Utility Commission of Texas (PUCT) | |||||
Texas 2014 Electric Rate Case — In January 2014, SPS filed a retail electric rate case in Texas with each of its Texas municipalities and the PUCT for a net increase in annual revenue of approximately $52.7 million, or 5.8 percent. The net increase reflected a base rate increase, revenue credits transferred from base rates to rate riders or the fuel clause, and resetting the Transmission Cost Recovery Factor (TCRF) to zero when the final base rates become effective. | |||||
The rate filing was based on a historic test year ending June 2013, a requested return on equity (ROE) of 10.40 percent, an electric rate base of approximately $1.27 billion and an equity ratio of 53.89 percent. The requested rate increase reflected an increase in depreciation expense of approximately $16 million. | |||||
In April 2014, SPS revised its requested rate increase to approximately $48.1 million, or 5.3 percent, based on updated information. The following table summarizes SPS’ revised request: | |||||
(Millions of Dollars) | SPS Request | ||||
Adjusted base rate increase | $ | 76.9 | |||
Resetting TCRF | (12.9 | ) | |||
Credit to customers for gain on sale to Lubbock moved to a rider | (4.9 | ) | |||
Adjusted net increase in base revenue | 59.1 | ||||
Fuel clause offsets | (11.0 | ) | |||
Adjusted retail customer net bill impact | $ | 48.1 | |||
The PUCT has suspended SPS’ proposed rates through Oct. 31, 2014. If the PUCT has not issued a final order by July 11, 2014, then SPS’ current rates will not change, but final rates, when approved by the PUCT, will be made effective retroactive to July 12, 2014. SPS, intervenors and other parties have commenced settlement negotiations. | |||||
Next steps in the procedural schedule are as follows: | |||||
• | Intervenor testimony — May 22, 2014; | ||||
• | PUCT Staff testimony — May 29, 2014; | ||||
• | Cross-rebuttal testimony — June 12, 2014; | ||||
• | Rebuttal testimony — June 16, 2014; | ||||
• | Evidentiary hearing — June 25, 2014; and | ||||
• | A PUCT decision and implementation of final rates are anticipated in the third quarter of 2014. | ||||
Electric, Purchased Gas and Resource Adjustment Clauses | |||||
TCRF Rider — In November 2013, SPS filed with the PUCT to implement the TCRF for Texas retail customers. The requested increase in revenues is $13 million. The PUCT issued an order allowing the TCRF to go into effect on an interim basis effective Jan. 1, 2014. In April and May 2014, several parties including both intervenors and the PUCT Staff filed testimony recommending various reductions or modifications to the proposed TCRF. | |||||
Next steps in the procedural schedule are as follows: | |||||
• | SPS Rebuttal testimony — May 8, 2014; and | ||||
• | Evidentiary hearings — May 15 - May 16, 2014. | ||||
Recently Concluded Regulatory Proceedings — New Mexico Public Regulation Commission (NMPRC) | |||||
New Mexico 2014 Electric Rate Case — In December 2012, SPS filed an electric rate case in New Mexico with the NMPRC for an increase in annual revenue of approximately $45.9 million effective in 2014. The rate filing was based on a 2014 forecast test year, a requested ROE of 10.65 percent, an electric rate base of $479.8 million and an equity ratio of 53.89 percent. | |||||
In September 2013, SPS filed rebuttal testimony, revising its requested rate increase to $32.5 million, based on updated information and an ROE of 10.25 percent. This reflects a base and fuel increase of $20.9 million, an increase of rider revenue of $12.1 million and a decrease to other of $0.5 million. | |||||
In March 2014, the NMPRC approved an overall increase of approximately $33.1 million. The increase includes: an ROE of 9.96 percent, an equity ratio of 53.89 percent, allowance of the prepaid pension asset in rate base of approximately $2.4 million, allowance of certain non-labor operating and maintenance (O&M) escalations and recovery of approximately $18.1 million of renewable energy costs through rider revenue instead of base revenue. As a result of a change in the amount of fuel costs recovered through base rates, SPS will no longer be required to credit customers for $2.3 million through the fuel clause adjustment (FCA). Final rates were effective April 5, 2014. On April 25, 2014, the New Mexico Attorney General filed a request for rehearing. The rehearing request is pending with the NMPRC, which has until May 15, 2014 to grant or deny the request. | |||||
The following table summarizes the NMPRC’s approval from SPS’ revised request: | |||||
(Millions of Dollars) | NMPRC Approval | ||||
SPS revised request, September 2013 | $ | 32.5 | |||
Fuel clause adjustment credit — non-renewable energy costs | 2.3 | ||||
SPS revised request, fuel adjusted | 34.8 | ||||
ROE (9.96 percent) | (1.2 | ) | |||
Rate rider adjustment — renewable energy costs | 6 | ||||
Base rate reduction for rate rider — renewable energy costs | (6.0 | ) | |||
Other, net | (0.5 | ) | |||
Approved increase, March 2014 | $ | 33.1 | |||
Means of recovery: | |||||
Base revenue | $ | 12.7 | |||
Rider revenue | 18.1 | ||||
Fuel clause | 2.3 | ||||
$ | 33.1 | ||||
Pending Regulatory Proceedings — Federal Energy Regulatory Commission (FERC) | |||||
2004 FERC Complaint Case Orders — In August 2013, the FERC issued an order on rehearing related to a 2004 Complaint case brought by Golden Spread Electric Cooperative, Inc. (Golden Spread), a wholesale cooperative customer, and Public Service Company of New Mexico (PNM) and an Order on Initial Decision in a subsequent 2006 rate case filed by SPS. | |||||
The original Complaint included two key components: 1) PNM’s claim regarding inappropriate allocation of fuel costs and 2) a base rate complaint, including the appropriate demand-related cost allocator. The FERC previously determined that the allocation of fuel costs and the demand-related cost allocator utilized by SPS was appropriate. | |||||
In the August 2013 Orders, the FERC clarified its previous ruling on the allocation of fuel costs and reaffirmed that the refunds in question should only apply to firm requirements customers and not PNM’s contractual load. The FERC also reversed its prior demand-related cost allocator decision. The FERC stated that it had erred in its initial analysis and concluded that the SPS system was a 3 coincident peak (CP) rather than a 12CP system. | |||||
As of Dec. 31, 2013, SPS had accrued $44.5 million related to these case orders and an additional $1.9 million of principal and interest was accrued during the first quarter of 2014. Pending the timing and resolution of this matter, the annual impact to revenues through 2014 could be up to $6 million and decreasing to $4 million on June 1, 2015. | |||||
In September 2013, SPS filed a request for rehearing of the FERC ruling on the CP allocation and refund decisions. SPS asserted that the FERC applied an improper burden of proof and that precedent did not support retroactive refunds. PNM also requested rehearing of the FERC decision not to reverse its prior ruling. | |||||
In October 2013, the FERC issued orders further considering the requests for rehearing. These matters are currently pending the FERC’s action. If unsuccessful in its rehearing request, SPS will have the opportunity to file rate cases with the FERC and its retail jurisdictions seeking to change all customers to a 3CP allocation method. |
Commitments_and_Contingencies
Commitments and Contingencies | 3 Months Ended |
Mar. 31, 2014 | |
Commitments and Contingencies Disclosure [Abstract] | ' |
Commitments and Contingencies | ' |
Commitments and Contingencies | |
Except to the extent noted below and in Note 5, the circumstances set forth in Notes 10 and 11 to the financial statements in SPS’ Annual Report on Form 10-K for the year ended Dec. 31, 2013, appropriately represent, in all material respects, the current status of commitments and contingent liabilities and are incorporated herein by reference. The following include commitments, contingencies and unresolved contingencies that are material to SPS’ financial position. | |
Purchased Power Agreements (PPAs) | |
Under certain PPAs, SPS purchases power from independent power producing entities that own natural gas fueled power plants for which SPS is required to reimburse natural gas fuel costs, or to participate in tolling arrangements under which SPS procures the natural gas required to produce the energy that it purchases. These specific PPAs create a variable interest in the associated independent power producing entity. | |
SPS had approximately 827 megawatts (MW) of capacity under long-term PPAs as of each of March 31, 2014 and Dec. 31, 2013 with entities that have been determined to be variable interest entities. SPS has concluded that these entities are not required to be consolidated in its financial statements because it does not have the power to direct the activities that most significantly impact the entities’ economic performance. These agreements have expiration dates through the year 2033. | |
Indemnification Agreements | |
In connection with the sale of certain Texas electric transmission assets to Sharyland Distribution and Transmission Services, LLC in 2013, SPS agreed to indemnify the purchaser for losses arising out of any breach of the representations, warranties and covenants under the related asset purchase agreement and for losses arising out of certain other matters, including pre-closing liabilities. SPS’ indemnification obligation is capped at $37.1 million, in the aggregate. The indemnification provisions for most representations and warranties expire in December 2014. The remaining representations and warranties, which relate to due organization and transaction authorization, survive indefinitely. As of March 31, 2014 and Dec. 31, 2013, SPS has recorded a $0.4 million liability related to this indemnity. | |
Environmental Contingencies | |
Environmental Requirements | |
Water and waste | |
Federal Clean Water Act Effluent Limitations Guidelines (ELG) — In June 2013, the U.S. Environmental Protection Agency (EPA) published a proposed ELG rule for power plants that use coal, natural gas, oil or nuclear materials as fuel and discharge treated effluent to surface waters as well as utility-owned landfills that receive coal combustion residuals. The final rule is now expected in September 2015. Under the current proposed rule, facilities would need to comply as soon as possible after July 2017 but no later than July 2022. The impact of this rule on SPS is uncertain at this time. | |
Air | |
Cross-State Air Pollution Rule (CSAPR) — In 2011, the EPA issued the CSAPR to address long range transport of particulate matter (PM) and ozone by requiring reductions in sulfur dioxide (SO2) and nitrous oxide (NOx) from utilities in the eastern half of the United States, including Texas. The CSAPR would set more stringent requirements than the proposed Clean Air Transport Rule and require plants in Texas to reduce their SO2 and annual NOx emissions. The rule would also create an emissions trading program. | |
In August 2012, the United States Court of Appeals for the District of Columbia Circuit (D.C. Circuit) vacated the CSAPR and remanded it back to the EPA. The D.C. Circuit stated the EPA must continue administering the Clean Air Interstate Rule (CAIR) pending adoption of a valid replacement. In April 2014, the U.S. Supreme Court reversed and remanded the case to the D.C. Circuit. The Court held that the EPA’s rule design did not violate the Clean Air Act and that states had received adequate opportunity to develop their own plans. Because the D.C. Circuit overturned the CSAPR on two over-arching issues, there are many other issues the D.C. Circuit did not rule on that will now need to be considered on remand. Because it is not yet known how the litigation over the remaining issues will be resolved, it is not yet known what requirements may be imposed in the future, or their timing. | |
As the EPA continues administering the CAIR while the CSAPR or a replacement rule is pending, SPS expects to comply with the CAIR as described below. | |
CAIR — In 2005, the EPA issued the CAIR to further regulate SO2 and NOx emissions. Under the CAIR’s cap and trade structure, companies can comply through capital investments in emission controls or purchase of emission allowances from other utilities making reductions on their systems. In the SPS region, installation of low-NOx combustion control technology was completed in 2012 on Tolk Unit 1. SPS plans to install the same combustion control technology on Tolk Unit 2 in the second quarter of 2014. These installations will reduce or eliminate SPS’ need to purchase NOx emission allowances. SPS had sufficient SO2 allowances to comply with the CAIR in 2013 and has sufficient allowances through 2015. At March 31, 2014, the estimated annual CAIR NOx allowance cost for SPS did not have a material impact on the results of operations, financial position or cash flows. | |
Regional Haze Rules — In 2005, the EPA amended the best available retrofit technology (BART) requirements of its regional haze rules, which require the installation and operation of emission controls for industrial facilities emitting air pollutants that reduce visibility in certain national parks and wilderness areas. In its first regional haze state implementation plan (SIP), Texas identified the SPS facilities that will have to reduce SO2, NOx and PM emissions under BART and set emissions limits for those facilities. | |
Harrington Units 1 and 2 are potentially subject to BART. Texas developed a SIP that finds the CAIR equal to BART for electric generating units (EGUs). As a result, no additional controls beyond CAIR compliance would be required. In May 2012, the EPA deferred its review of the SIP in its final rule allowing states to find that CSAPR compliance meets BART requirements for EGUs. It is not yet known how the U.S. Supreme Court’s April 2014 decision on the CSAPR may impact the EPA’s approval of the SIP. | |
Legal Contingencies | |
SPS is involved in various litigation matters that are being defended and handled in the ordinary course of business. The assessment of whether a loss is probable or is a reasonable possibility, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. Management maintains accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of a reasonably possible loss in certain situations, including but not limited to when (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss. For current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on SPS’ financial statements. Unless otherwise required by GAAP, legal fees are expensed as incurred. | |
Employment, Tort and Commercial Litigation | |
Exelon Wind (formerly John Deere Wind) Complaint — Several lawsuits in Texas state and federal courts and regulatory proceedings have arisen out of a dispute concerning SPS’ payments for energy and capacity produced from the Exelon Wind subsidiaries’ projects. There are two main areas of dispute. First, Exelon Wind claims that it established legally enforceable obligations (LEOs) for each of its 12 wind facilities in 2005 through 2008 that require SPS to buy power based on SPS’ forecasted avoided cost as determined in 2005 through 2008. Although SPS has refused to accept Exelon Wind’s LEOs, SPS accepts that it must take energy from Exelon Wind under SPS’ PUCT-approved Qualifying Facilities (QF) Tariff. Second, Exelon Wind has raised various challenges to SPS’ PUCT-approved QF Tariff, which became effective in August 2010. The state and federal lawsuits and regulatory proceedings are in various stages of litigation, including a pending appeal by SPS in the Fifth Circuit Court of Appeals. SPS believes the likelihood of loss in these lawsuits and proceedings is remote based primarily on existing case law and while it is not possible to estimate the amount or range of reasonably possible loss in the event of an adverse outcome, SPS believes such loss would not be material based upon its belief that it would be permitted to recover such costs, if needed, through its various fuel clause mechanisms. No accrual has been recorded for this matter. |
Borrowings_and_Other_Financing
Borrowings and Other Financing Instruments | 3 Months Ended | ||||||||||
Mar. 31, 2014 | |||||||||||
Debt Disclosure [Abstract] | ' | ||||||||||
Borrowings and Other Financing Instruments | ' | ||||||||||
Borrowings and Other Financing Instruments | |||||||||||
Short-Term Borrowings | |||||||||||
Money Pool — Xcel Energy Inc. and its utility subsidiaries have established a money pool arrangement that allows for short-term investments in and borrowings between the utility subsidiaries. Xcel Energy Inc. may make investments in the utility subsidiaries at market-based interest rates; however, the money pool arrangement does not allow the utility subsidiaries to make investments in Xcel Energy Inc. Money pool borrowings for SPS were as follows: | |||||||||||
(Amounts in Millions, Except Interest Rates) | Three Months Ended March 31, 2014 | Twelve Months Ended Dec. 31, 2013 | |||||||||
Borrowing limit | $ | 100 | $ | 100 | |||||||
Amount outstanding at period end | 100 | 38 | |||||||||
Average amount outstanding | 30 | 46 | |||||||||
Maximum amount outstanding | 100 | 100 | |||||||||
Weighted average interest rate, computed on a daily basis | 0.21 | % | 0.15 | % | |||||||
Weighted average interest rate at period end | 0.21 | 0.25 | |||||||||
Commercial Paper — SPS meets its short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under its credit facility. Commercial paper outstanding for SPS was as follows: | |||||||||||
(Amounts in Millions, Except Interest Rates) | Three Months Ended March 31, 2014 | Twelve Months Ended Dec. 31, 2013 | |||||||||
Borrowing limit | $ | 300 | $ | 300 | |||||||
Amount outstanding at period end | 69 | 84 | |||||||||
Average amount outstanding | 103 | 32 | |||||||||
Maximum amount outstanding | 158 | 140 | |||||||||
Weighted average interest rate, computed on a daily basis | 0.25 | % | 0.3 | % | |||||||
Weighted average interest rate at period end | 0.24 | 0.27 | |||||||||
Letters of Credit — SPS may use letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations. At March 31, 2014 and Dec. 31, 2013, there were $21.0 million and $25.5 million letters of credit outstanding, respectively, under the credit facility. The contract amounts of these letters of credit approximate their fair value and are subject to fees. | |||||||||||
Credit Facility — In order to use its commercial paper program to fulfill short-term funding needs, SPS must have a revolving credit facility in place at least equal to the amount of its commercial paper borrowing limit and cannot issue commercial paper in an aggregate amount exceeding available capacity under this credit facility. The line of credit provides short-term financing in the form of notes payable to banks, letters of credit and back-up support for commercial paper borrowings. | |||||||||||
At March 31, 2014, SPS had the following committed credit facility available (in millions): | |||||||||||
Credit Facility (a) | Drawn (b) | Available | |||||||||
$ | 300 | $ | 90 | $ | 210 | ||||||
(a) | Credit facility expires in July 2017. | ||||||||||
(b) | Includes outstanding commercial paper and letters of credit. | ||||||||||
All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility. SPS had no direct advances on the credit facility outstanding at March 31, 2014 and Dec. 31, 2013. |
Fair_Value_of_Financial_Assets
Fair Value of Financial Assets and Liabilities | 3 Months Ended | ||||||||||||||||||||||||
Mar. 31, 2014 | |||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | ' | ||||||||||||||||||||||||
Fair Value of Financial Assets and Liabilities | ' | ||||||||||||||||||||||||
Fair Value of Financial Assets and Liabilities | |||||||||||||||||||||||||
Fair Value Measurements | |||||||||||||||||||||||||
The accounting guidance for fair value measurements and disclosures provides a single definition of fair value and requires certain disclosures about assets and liabilities measured at fair value. A hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value is established by this guidance. The three levels in the hierarchy are as follows: | |||||||||||||||||||||||||
Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices. | |||||||||||||||||||||||||
Level 2 — Pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable as of the reporting date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, or priced with models using highly observable inputs. | |||||||||||||||||||||||||
Level 3 — Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation. | |||||||||||||||||||||||||
Specific valuation methods include the following: | |||||||||||||||||||||||||
Cash equivalents — The fair values of cash equivalents are generally based on cost plus accrued interest; money market funds are measured using quoted net asset values. | |||||||||||||||||||||||||
Interest rate derivatives — The fair values of interest rate derivatives are based on broker quotes that utilize current market interest rate forecasts. | |||||||||||||||||||||||||
Commodity derivatives — The methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2. When contractual settlements extend to periods beyond those readily observable on active exchanges or quoted by brokers, the significance of the use of less observable forecasts of long-term forward prices and volatilities on a valuation is evaluated, and may result in Level 3 classification. | |||||||||||||||||||||||||
Electric commodity derivatives held by SPS include transmission congestion instruments purchased from the Southwest Power Pool, Inc. (SPP), generally referred to as financial transmission rights (FTRs). FTRs purchased from a regional transmission organization (RTO) are financial instruments that entitle or obligate the holder to monthly revenues or charges based on transmission congestion across a given transmission path. The value of an FTR is derived from, and designed to offset, the cost of energy congestion, which is caused by overall transmission load and other transmission constraints. In addition to overall transmission load, congestion is also influenced by the operating schedules of power plants and the consumption of electricity pertinent to a given transmission path. Unplanned plant outages, scheduled plant maintenance, changes in the relative costs of fuels used in generation, weather and overall changes in demand for electricity can each impact the operating schedules of the power plants on the transmission grid and the value of an FTR. The valuation process for FTRs utilizes complex iterative modeling to predict the impacts of forecasted changes in these drivers of transmission system congestion on the historical pricing of FTR purchases. | |||||||||||||||||||||||||
If forecasted costs of electric transmission congestion increase or decrease for a given FTR path, the value of that particular FTR instrument will likewise increase or decrease. Given the limited observability of management’s forecasts for several of the inputs to this complex valuation model - including expected plant operating schedules and retail and wholesale demand, fair value measurements for FTRs have been assigned a Level 3. Non-trading monthly FTR settlements are expected to be recovered through fuel and purchased energy cost recovery mechanisms, and therefore changes in the fair value of the yet to be settled portions of FTRs are deferred as a regulatory asset or liability. Given this regulatory treatment and the limited magnitude of FTRs relative to the electric utility operations of SPS, the numerous unobservable quantitative inputs to the complex model used for valuation of FTRs are insignificant to the financial statements of SPS. | |||||||||||||||||||||||||
Derivative Instruments Fair Value Measurements | |||||||||||||||||||||||||
SPS enters into derivative instruments, including forward contracts, for trading purposes and to manage risk in connection with changes in interest rates and electric utility commodity prices. | |||||||||||||||||||||||||
Interest Rate Derivatives — SPS may enter into various instruments that effectively fix the interest payments on certain floating rate debt obligations or effectively fix the yield or price on a specified benchmark interest rate for an anticipated debt issuance for a specific period. These derivative instruments are generally designated as cash flow hedges for accounting purposes. | |||||||||||||||||||||||||
At March 31, 2014, accumulated other comprehensive losses related to interest rate derivatives included $0.2 million of net losses expected to be reclassified into earnings during the next 12 months as the related hedged interest rate transactions impact earnings, including forecasted amounts for unsettled hedges, as applicable. | |||||||||||||||||||||||||
Wholesale and Commodity Trading Risk — SPS conducts various wholesale and commodity trading activities, including the purchase and sale of electric capacity, energy and energy-related instruments. SPS’ risk management policy allows management to conduct these activities within guidelines and limitations as approved by its risk management committee, which is made up of management personnel not directly involved in the activities governed by this policy. | |||||||||||||||||||||||||
Commodity Derivatives — SPS enters into derivative instruments to manage variability of future cash flows from changes in commodity prices in its electric utility operations, as well as for trading purposes. This could include the purchase or sale of energy or energy-related products and FTRs. | |||||||||||||||||||||||||
The following table details the gross notional amounts of commodity FTRs at March 31, 2014 and Dec. 31, 2013: | |||||||||||||||||||||||||
(Amounts in Thousands) (a) | 31-Mar-14 | Dec. 31, 2013 | |||||||||||||||||||||||
Megawatt hours of electricity | 3,989 | 5,989 | |||||||||||||||||||||||
(a) | Amounts are not reflective of net positions in the underlying commodities. | ||||||||||||||||||||||||
Pre-tax losses related to interest rate derivatives reclassified from accumulated other comprehensive loss into earnings were $0.1 million for each of the three months ended March 31, 2014 and 2013. | |||||||||||||||||||||||||
During the three months ended March 31, 2014, changes in the fair value of FTRs resulting in pre-tax net losses of $1.4 million were recognized as regulatory assets and liabilities. The classification as a regulatory asset or liability is based on expected recovery of FTR settlements through fuel and purchased energy cost recovery mechanisms. | |||||||||||||||||||||||||
FTR settlement gains of $2.8 million were recognized for the three months ended March 31, 2014, recorded to electric fuel and purchased power. These derivative settlement gains and losses are shared with electric customers through fuel and purchased energy cost-recovery mechanisms, and reclassified out of income as regulatory assets or liabilities, as appropriate. | |||||||||||||||||||||||||
SPS had no derivative instruments designated as fair value hedges during the three months ended March 31, 2014 and 2013. Therefore, no gains or losses from fair value hedges or related hedged transactions were recognized for these periods. | |||||||||||||||||||||||||
Consideration of Credit Risk and Concentrations — SPS continuously monitors the creditworthiness of the counterparties to its interest rate derivatives and commodity derivative contracts prior to settlement, and assesses each counterparty’s ability to perform on the transactions set forth in the contracts. Given this assessment, as well as an assessment of the impact of SPS’ own credit risk when determining the fair value of derivative liabilities, the impact of considering credit risk was immaterial to the fair value of unsettled commodity derivatives presented in the balance sheets. | |||||||||||||||||||||||||
SPS employs additional credit risk control mechanisms when appropriate, such as letters of credit, parental guarantees, standardized master netting agreements and termination provisions that allow for offsetting of positive and negative exposures. Credit exposure is monitored and, when necessary, the activity with a specific counterparty is limited until credit enhancement is provided. | |||||||||||||||||||||||||
SPS’ most significant concentrations of credit risk with particular entities or industries are contracts with counterparties to its wholesale, trading and non-trading commodity and transmission activities. At March 31, 2014, three of SPS’ 10 most significant counterparties for these activities, comprising $16.4 million or 17 percent of this credit exposure, had investment grade credit ratings from Standard & Poor’s Ratings Services, Moody’s Investor Services or Fitch Ratings. The remaining seven significant counterparties, comprising $46.6 million or 48 percent of this credit exposure, were not rated by these agencies, but based on SPS’ internal analysis, had credit quality consistent with investment grade. All 10 of these significant counterparties are RTOs, municipal or cooperative electric entities or other utilities. | |||||||||||||||||||||||||
Recurring Fair Value Measurements — The following table presents for each of the fair value hierarchy levels, SPS’ derivative assets and liabilities measured at fair value on a recurring basis at March 31, 2014: | |||||||||||||||||||||||||
31-Mar-14 | |||||||||||||||||||||||||
Fair Value | Fair Value Total | Counterparty Netting (b) | |||||||||||||||||||||||
(Thousands of Dollars) | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||
Current derivative assets | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 10,433 | $ | 10,433 | $ | (4,642 | ) | $ | 5,791 | ||||||||||||
Total current derivative assets | $ | — | $ | — | $ | 10,433 | $ | 10,433 | $ | (4,642 | ) | 5,791 | |||||||||||||
PPAs (a) | 7,893 | ||||||||||||||||||||||||
Current derivative instruments | $ | 13,684 | |||||||||||||||||||||||
Noncurrent derivative assets | |||||||||||||||||||||||||
PPAs (a) | $ | 39,083 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 39,083 | |||||||||||||||||||||||
Current derivative liabilities | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 4,642 | $ | 4,642 | $ | (4,642 | ) | $ | — | ||||||||||||
Total current derivative liabilities | $ | — | $ | — | $ | 4,642 | $ | 4,642 | $ | (4,642 | ) | — | |||||||||||||
PPAs (a) | 3,574 | ||||||||||||||||||||||||
Current derivative instruments | $ | 3,574 | |||||||||||||||||||||||
Noncurrent derivative liabilities | |||||||||||||||||||||||||
PPAs (a) | $ | 33,316 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 33,316 | |||||||||||||||||||||||
(a) | In 2003, as a result of implementing new guidance on the normal purchase exception for derivative accounting, SPS began recording several long-term PPAs at fair value due to accounting requirements related to underlying price adjustments. As these purchases are recovered through normal regulatory recovery mechanisms in the respective jurisdictions, the changes in fair value for these contracts were offset by regulatory assets and liabilities. During 2006, SPS qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities. | ||||||||||||||||||||||||
(b) | SPS nets derivative instruments and related collateral in its balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at March 31, 2014. At March 31, 2014, derivative assets and liabilities include no obligations to return cash collateral or rights to reclaim cash collateral. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. | ||||||||||||||||||||||||
The following table presents for each of the fair value hierarchy levels, SPS’ derivative assets and liabilities measured at fair value on a recurring basis at Dec. 31, 2013: | |||||||||||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||||||||||
Fair Value | Fair Value Total | Counterparty Netting (b) | |||||||||||||||||||||||
(Thousands of Dollars) | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||
Current derivative assets | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 16,420 | $ | 16,420 | $ | (6,487 | ) | $ | 9,933 | ||||||||||||
Total current derivative assets | $ | — | $ | — | $ | 16,420 | $ | 16,420 | $ | (6,487 | ) | 9,933 | |||||||||||||
PPAs (a) | 7,893 | ||||||||||||||||||||||||
Current derivative instruments | $ | 17,826 | |||||||||||||||||||||||
Noncurrent derivative assets | |||||||||||||||||||||||||
PPAs (a) | $ | 41,056 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 41,056 | |||||||||||||||||||||||
Current derivative liabilities | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 6,487 | $ | 6,487 | $ | (6,487 | ) | $ | — | ||||||||||||
Total current derivative liabilities | $ | — | $ | — | $ | 6,487 | $ | 6,487 | $ | (6,487 | ) | — | |||||||||||||
PPAs (a) | 3,583 | ||||||||||||||||||||||||
Current derivative instruments | $ | 3,583 | |||||||||||||||||||||||
Noncurrent derivative liabilities | |||||||||||||||||||||||||
PPAs (a) | $ | 34,207 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 34,207 | |||||||||||||||||||||||
(a) | In 2003, as a result of implementing new guidance on the normal purchase exception for derivative accounting, SPS began recording several long-term PPAs at fair value due to accounting requirements related to underlying price adjustments. As these purchases are recovered through normal regulatory recovery mechanisms in the respective jurisdictions, the changes in fair value for these contracts were offset by regulatory assets and liabilities. During 2006, SPS qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities. | ||||||||||||||||||||||||
(b) | SPS nets derivative instruments and related collateral in its balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Dec. 31, 2013. At Dec. 31, 2013, derivative assets and liabilities include no obligations to return cash collateral or rights to reclaim cash collateral. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. | ||||||||||||||||||||||||
The following table presents the changes in Level 3 commodity derivatives for the three months ended March 31, 2014, and there were no Level 3 commodity derivatives during the three months ended March 31, 2013: | |||||||||||||||||||||||||
(Thousands of Dollars) | 2014 | ||||||||||||||||||||||||
Balance at Jan. 1 | $ | 9,933 | |||||||||||||||||||||||
Purchases | 1,056 | ||||||||||||||||||||||||
Settlements | (1,101 | ) | |||||||||||||||||||||||
Net transactions recorded during the period: | |||||||||||||||||||||||||
Losses recognized as regulatory assets and liabilities | (4,097 | ) | |||||||||||||||||||||||
Balance at March 31 | $ | 5,791 | |||||||||||||||||||||||
SPS recognizes transfers between levels as of the beginning of each period. There were no transfers of amounts between levels for derivative instruments for the three months ended March 31, 2014 and 2013. | |||||||||||||||||||||||||
Fair Value of Long-Term Debt | |||||||||||||||||||||||||
As of March 31, 2014 and Dec. 31, 2013, other financial instruments for which the carrying amount did not equal fair value were as follows: | |||||||||||||||||||||||||
March 31, 2014 | Dec. 31, 2013 | ||||||||||||||||||||||||
(Thousands of Dollars) | Carrying | Fair Value | Carrying | Fair Value | |||||||||||||||||||||
Amount | Amount | ||||||||||||||||||||||||
Long-term debt, including current portion | $ | 1,199,937 | $ | 1,361,503 | $ | 1,199,865 | $ | 1,307,035 | |||||||||||||||||
The fair value of SPS’ long-term debt is estimated based on recent trades and observable spreads from benchmark interest rates for similar securities. The fair value estimates are based on information available to management as of March 31, 2014 and Dec. 31, 2013, and given the observability of the inputs to these estimates, the fair values presented for long-term debt have been assigned a Level 2. |
Other_Income_Expense_Net
Other Income (Expense), Net | 3 Months Ended | ||||||||
Mar. 31, 2014 | |||||||||
Other Income and Expenses [Abstract] | ' | ||||||||
Other Income (Expense), Net | ' | ||||||||
Other Income (Expense), Net | |||||||||
Other income (expense), net consisted of the following: | |||||||||
Three Months Ended March 31 | |||||||||
(Thousands of Dollars) | 2014 | 2013 | |||||||
Interest income | $ | 187 | $ | 113 | |||||
Other nonoperating income | — | 3 | |||||||
Insurance policy expense | (144 | ) | (164 | ) | |||||
Other nonoperating expense | (2 | ) | — | ||||||
Other income (expense), net | $ | 41 | $ | (48 | ) | ||||
Benefit_Plans_and_Other_Postre
Benefit Plans and Other Postretirement Benefits | 3 Months Ended | ||||||||||||||||
Mar. 31, 2014 | |||||||||||||||||
Compensation and Retirement Disclosure [Abstract] | ' | ||||||||||||||||
Benefit Plans and Other Postretirement Benefits | ' | ||||||||||||||||
Benefit Plans and Other Postretirement Benefits | |||||||||||||||||
Components of Net Periodic Benefit Cost (Credit) | |||||||||||||||||
Three Months Ended March 31 | |||||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||||
(Thousands of Dollars) | Pension Benefits | Postretirement Health | |||||||||||||||
Care Benefits | |||||||||||||||||
Service cost | $ | 2,296 | $ | 2,404 | $ | 312 | $ | 342 | |||||||||
Interest cost | 5,111 | 4,477 | 643 | 588 | |||||||||||||
Expected return on plan assets | (6,545 | ) | (5,993 | ) | (812 | ) | (796 | ) | |||||||||
Amortization of prior service cost (credit) | 14 | 218 | (100 | ) | (121 | ) | |||||||||||
Amortization of net loss (gain) | 3,332 | 4,287 | (80 | ) | (2 | ) | |||||||||||
Net periodic benefit cost (credit) | 4,208 | 5,393 | (37 | ) | 11 | ||||||||||||
Credits (costs) not recognized due to the effects of regulation | 707 | (1,075 | ) | — | — | ||||||||||||
Net benefit cost (credit) recognized for financial reporting | $ | 4,915 | $ | 4,318 | $ | (37 | ) | $ | 11 | ||||||||
In January 2014, contributions of $130.0 million were made across three of Xcel Energy’s pension plans, of which $4.4 million was attributable to SPS. Xcel Energy does not expect additional pension contributions during 2014. |
Other_Comprehensive_Income
Other Comprehensive Income | 3 Months Ended | |||||||||
Mar. 31, 2014 | ||||||||||
Stockholders' Equity Note [Abstract] | ' | |||||||||
Other Comprehensive Income | ' | |||||||||
Other Comprehensive Income | ||||||||||
Changes in accumulated other comprehensive loss, net of tax, for the three months ended March 31, 2014 and 2013 were as follows: | ||||||||||
Gains and Losses on | ||||||||||
Cash Flow Hedges | ||||||||||
(Thousands of Dollars) | Three Months Ended March 31, 2014 | Three Months Ended March 31, 2013 | ||||||||
Accumulated other comprehensive loss at Jan. 1 | $ | (1,161 | ) | $ | (1,332 | ) | ||||
Losses reclassified from net accumulated other comprehensive loss | 43 | 42 | ||||||||
Net current period other comprehensive income | 43 | 42 | ||||||||
Accumulated other comprehensive loss at March 31 | $ | (1,118 | ) | $ | (1,290 | ) | ||||
Reclassifications from accumulated other comprehensive loss for the three months ended March 31, 2014 and 2013 were as follows: | ||||||||||
Amounts Reclassified from | ||||||||||
Accumulated Other | ||||||||||
Comprehensive Loss | ||||||||||
(Thousands of Dollars) | Three Months Ended March 31, 2014 | Three Months Ended March 31, 2013 | ||||||||
Losses on cash flow hedges: | ||||||||||
Interest rate derivatives | $ | 67 | (a) | $ | 66 | (a) | ||||
Total, pre-tax | 67 | 66 | ||||||||
Tax benefit | (24 | ) | (24 | ) | ||||||
Total amounts reclassified, net of tax | $ | 43 | $ | 42 | ||||||
(a) | Included in interest charges. |
Selected_Balance_Sheet_Data_Ta
Selected Balance Sheet Data (Tables) | 3 Months Ended | ||||||||
Mar. 31, 2014 | |||||||||
Balance Sheet Related Disclosures [Abstract] | ' | ||||||||
Accounts Receivable, Net | ' | ||||||||
(Thousands of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Accounts receivable, net | |||||||||
Accounts receivable | $ | 73,543 | $ | 76,426 | |||||
Less allowance for bad debts | (5,809 | ) | (5,475 | ) | |||||
$ | 67,734 | $ | 70,951 | ||||||
Inventories | ' | ||||||||
(Thousands of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Inventories | |||||||||
Materials and supplies | $ | 24,011 | $ | 21,600 | |||||
Fuel | 7,996 | 15,538 | |||||||
$ | 32,007 | $ | 37,138 | ||||||
Property, Plant and Equipment, Net | ' | ||||||||
(Thousands of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Property, plant and equipment, net | |||||||||
Electric plant | $ | 4,789,975 | $ | 4,714,398 | |||||
Construction work in progress | 445,751 | 388,323 | |||||||
Total property, plant and equipment | 5,235,726 | 5,102,721 | |||||||
Less accumulated depreciation | (1,840,452 | ) | (1,818,691 | ) | |||||
$ | 3,395,274 | $ | 3,284,030 | ||||||
Income_Taxes_Tables
Income Taxes (Tables) | 3 Months Ended | ||||||||
Mar. 31, 2014 | |||||||||
Income Tax Disclosure [Abstract] | ' | ||||||||
Reconciliation of Unrecognized Tax Benefits | ' | ||||||||
A reconciliation of the amount of unrecognized tax benefit is as follows: | |||||||||
(Millions of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
Unrecognized tax benefit — Permanent tax positions | $ | 0.2 | $ | 1.2 | |||||
Unrecognized tax benefit — Temporary tax positions | 2.3 | 2.9 | |||||||
Total unrecognized tax benefit | $ | 2.5 | $ | 4.1 | |||||
Tax Benefits Associated with NOL and Tax Credit Carryforwards | ' | ||||||||
The unrecognized tax benefit amounts were reduced by the tax benefits associated with net operating loss (NOL) and tax credit carryforwards. The amounts of tax benefits associated with NOL and tax credit carryforwards are as follows: | |||||||||
(Millions of Dollars) | March 31, 2014 | Dec. 31, 2013 | |||||||
NOL and tax credit carryforwards | $ | (1.3 | ) | $ | (2.4 | ) |
Rate_Matters_Rate_Matters_Tabl
Rate Matters Rate Matters (Tables) | 3 Months Ended | ||||
Mar. 31, 2014 | |||||
Public Utilities, General Disclosures [Abstract] | ' | ||||
SPS' Texas 2014 Electric Rate Case | ' | ||||
In April 2014, SPS revised its requested rate increase to approximately $48.1 million, or 5.3 percent, based on updated information. The following table summarizes SPS’ revised request: | |||||
(Millions of Dollars) | SPS Request | ||||
Adjusted base rate increase | $ | 76.9 | |||
Resetting TCRF | (12.9 | ) | |||
Credit to customers for gain on sale to Lubbock moved to a rider | (4.9 | ) | |||
Adjusted net increase in base revenue | 59.1 | ||||
Fuel clause offsets | (11.0 | ) | |||
Adjusted retail customer net bill impact | $ | 48.1 | |||
SPS' New Mexico 2014 Electric Rate Case | ' | ||||
The following table summarizes the NMPRC’s approval from SPS’ revised request: | |||||
(Millions of Dollars) | NMPRC Approval | ||||
SPS revised request, September 2013 | $ | 32.5 | |||
Fuel clause adjustment credit — non-renewable energy costs | 2.3 | ||||
SPS revised request, fuel adjusted | 34.8 | ||||
ROE (9.96 percent) | (1.2 | ) | |||
Rate rider adjustment — renewable energy costs | 6 | ||||
Base rate reduction for rate rider — renewable energy costs | (6.0 | ) | |||
Other, net | (0.5 | ) | |||
Approved increase, March 2014 | $ | 33.1 | |||
Means of recovery: | |||||
Base revenue | $ | 12.7 | |||
Rider revenue | 18.1 | ||||
Fuel clause | 2.3 | ||||
$ | 33.1 | ||||
Borrowings_and_Other_Financing1
Borrowings and Other Financing Instruments (Tables) | 3 Months Ended | ||||||||||
Mar. 31, 2014 | |||||||||||
Borrowings and Other Financing Instruments [Abstract] | ' | ||||||||||
Committed Credit Facility Available | ' | ||||||||||
At March 31, 2014, SPS had the following committed credit facility available (in millions): | |||||||||||
Credit Facility (a) | Drawn (b) | Available | |||||||||
$ | 300 | $ | 90 | $ | 210 | ||||||
(a) | Credit facility expires in July 2017. | ||||||||||
(b) | Includes outstanding commercial paper and letters of credit. | ||||||||||
Money Pool | ' | ||||||||||
Borrowings and Other Financing Instruments [Abstract] | ' | ||||||||||
Short-Term Borrowings | ' | ||||||||||
Money pool borrowings for SPS were as follows: | |||||||||||
(Amounts in Millions, Except Interest Rates) | Three Months Ended March 31, 2014 | Twelve Months Ended Dec. 31, 2013 | |||||||||
Borrowing limit | $ | 100 | $ | 100 | |||||||
Amount outstanding at period end | 100 | 38 | |||||||||
Average amount outstanding | 30 | 46 | |||||||||
Maximum amount outstanding | 100 | 100 | |||||||||
Weighted average interest rate, computed on a daily basis | 0.21 | % | 0.15 | % | |||||||
Weighted average interest rate at period end | 0.21 | 0.25 | |||||||||
Commercial Paper | ' | ||||||||||
Borrowings and Other Financing Instruments [Abstract] | ' | ||||||||||
Short-Term Borrowings | ' | ||||||||||
Commercial paper outstanding for SPS was as follows: | |||||||||||
(Amounts in Millions, Except Interest Rates) | Three Months Ended March 31, 2014 | Twelve Months Ended Dec. 31, 2013 | |||||||||
Borrowing limit | $ | 300 | $ | 300 | |||||||
Amount outstanding at period end | 69 | 84 | |||||||||
Average amount outstanding | 103 | 32 | |||||||||
Maximum amount outstanding | 158 | 140 | |||||||||
Weighted average interest rate, computed on a daily basis | 0.25 | % | 0.3 | % | |||||||
Weighted average interest rate at period end | 0.24 | 0.27 | |||||||||
Fair_Value_of_Financial_Assets1
Fair Value of Financial Assets and Liabilities (Tables) | 3 Months Ended | ||||||||||||||||||||||||
Mar. 31, 2014 | |||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | ' | ||||||||||||||||||||||||
Gross Notional Amounts of Commodity FTRs | ' | ||||||||||||||||||||||||
The following table details the gross notional amounts of commodity FTRs at March 31, 2014 and Dec. 31, 2013: | |||||||||||||||||||||||||
(Amounts in Thousands) (a) | 31-Mar-14 | Dec. 31, 2013 | |||||||||||||||||||||||
Megawatt hours of electricity | 3,989 | 5,989 | |||||||||||||||||||||||
(a) | Amounts are not reflective of net positions in the underlying commodities. | ||||||||||||||||||||||||
Derivative Assets and Liabilities Measured at Fair Value on a Recurring Basis by Hierarchy Level | ' | ||||||||||||||||||||||||
Recurring Fair Value Measurements — The following table presents for each of the fair value hierarchy levels, SPS’ derivative assets and liabilities measured at fair value on a recurring basis at March 31, 2014: | |||||||||||||||||||||||||
31-Mar-14 | |||||||||||||||||||||||||
Fair Value | Fair Value Total | Counterparty Netting (b) | |||||||||||||||||||||||
(Thousands of Dollars) | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||
Current derivative assets | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 10,433 | $ | 10,433 | $ | (4,642 | ) | $ | 5,791 | ||||||||||||
Total current derivative assets | $ | — | $ | — | $ | 10,433 | $ | 10,433 | $ | (4,642 | ) | 5,791 | |||||||||||||
PPAs (a) | 7,893 | ||||||||||||||||||||||||
Current derivative instruments | $ | 13,684 | |||||||||||||||||||||||
Noncurrent derivative assets | |||||||||||||||||||||||||
PPAs (a) | $ | 39,083 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 39,083 | |||||||||||||||||||||||
Current derivative liabilities | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 4,642 | $ | 4,642 | $ | (4,642 | ) | $ | — | ||||||||||||
Total current derivative liabilities | $ | — | $ | — | $ | 4,642 | $ | 4,642 | $ | (4,642 | ) | — | |||||||||||||
PPAs (a) | 3,574 | ||||||||||||||||||||||||
Current derivative instruments | $ | 3,574 | |||||||||||||||||||||||
Noncurrent derivative liabilities | |||||||||||||||||||||||||
PPAs (a) | $ | 33,316 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 33,316 | |||||||||||||||||||||||
(a) | In 2003, as a result of implementing new guidance on the normal purchase exception for derivative accounting, SPS began recording several long-term PPAs at fair value due to accounting requirements related to underlying price adjustments. As these purchases are recovered through normal regulatory recovery mechanisms in the respective jurisdictions, the changes in fair value for these contracts were offset by regulatory assets and liabilities. During 2006, SPS qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities. | ||||||||||||||||||||||||
(b) | SPS nets derivative instruments and related collateral in its balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at March 31, 2014. At March 31, 2014, derivative assets and liabilities include no obligations to return cash collateral or rights to reclaim cash collateral. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. | ||||||||||||||||||||||||
The following table presents for each of the fair value hierarchy levels, SPS’ derivative assets and liabilities measured at fair value on a recurring basis at Dec. 31, 2013: | |||||||||||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||||||||||
Fair Value | Fair Value Total | Counterparty Netting (b) | |||||||||||||||||||||||
(Thousands of Dollars) | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||
Current derivative assets | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 16,420 | $ | 16,420 | $ | (6,487 | ) | $ | 9,933 | ||||||||||||
Total current derivative assets | $ | — | $ | — | $ | 16,420 | $ | 16,420 | $ | (6,487 | ) | 9,933 | |||||||||||||
PPAs (a) | 7,893 | ||||||||||||||||||||||||
Current derivative instruments | $ | 17,826 | |||||||||||||||||||||||
Noncurrent derivative assets | |||||||||||||||||||||||||
PPAs (a) | $ | 41,056 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 41,056 | |||||||||||||||||||||||
Current derivative liabilities | |||||||||||||||||||||||||
Other derivative instruments: | |||||||||||||||||||||||||
Electric commodity | $ | — | $ | — | $ | 6,487 | $ | 6,487 | $ | (6,487 | ) | $ | — | ||||||||||||
Total current derivative liabilities | $ | — | $ | — | $ | 6,487 | $ | 6,487 | $ | (6,487 | ) | — | |||||||||||||
PPAs (a) | 3,583 | ||||||||||||||||||||||||
Current derivative instruments | $ | 3,583 | |||||||||||||||||||||||
Noncurrent derivative liabilities | |||||||||||||||||||||||||
PPAs (a) | $ | 34,207 | |||||||||||||||||||||||
Noncurrent derivative instruments | $ | 34,207 | |||||||||||||||||||||||
(a) | In 2003, as a result of implementing new guidance on the normal purchase exception for derivative accounting, SPS began recording several long-term PPAs at fair value due to accounting requirements related to underlying price adjustments. As these purchases are recovered through normal regulatory recovery mechanisms in the respective jurisdictions, the changes in fair value for these contracts were offset by regulatory assets and liabilities. During 2006, SPS qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities. | ||||||||||||||||||||||||
(b) | SPS nets derivative instruments and related collateral in its balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Dec. 31, 2013. At Dec. 31, 2013, derivative assets and liabilities include no obligations to return cash collateral or rights to reclaim cash collateral. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. | ||||||||||||||||||||||||
Changes in Level 3 Commodity Derivatives | ' | ||||||||||||||||||||||||
The following table presents the changes in Level 3 commodity derivatives for the three months ended March 31, 2014, and there were no Level 3 commodity derivatives during the three months ended March 31, 2013: | |||||||||||||||||||||||||
(Thousands of Dollars) | 2014 | ||||||||||||||||||||||||
Balance at Jan. 1 | $ | 9,933 | |||||||||||||||||||||||
Purchases | 1,056 | ||||||||||||||||||||||||
Settlements | (1,101 | ) | |||||||||||||||||||||||
Net transactions recorded during the period: | |||||||||||||||||||||||||
Losses recognized as regulatory assets and liabilities | (4,097 | ) | |||||||||||||||||||||||
Balance at March 31 | $ | 5,791 | |||||||||||||||||||||||
Carrying Amount and Fair Value of Long-term Debt | ' | ||||||||||||||||||||||||
As of March 31, 2014 and Dec. 31, 2013, other financial instruments for which the carrying amount did not equal fair value were as follows: | |||||||||||||||||||||||||
March 31, 2014 | Dec. 31, 2013 | ||||||||||||||||||||||||
(Thousands of Dollars) | Carrying | Fair Value | Carrying | Fair Value | |||||||||||||||||||||
Amount | Amount | ||||||||||||||||||||||||
Long-term debt, including current portion | $ | 1,199,937 | $ | 1,361,503 | $ | 1,199,865 | $ | 1,307,035 | |||||||||||||||||
Other_Income_Expense_Net_Table
Other Income (Expense), Net (Tables) | 3 Months Ended | ||||||||
Mar. 31, 2014 | |||||||||
Other Income and Expenses [Abstract] | ' | ||||||||
Other Income (Expense), Net | ' | ||||||||
Other income (expense), net consisted of the following: | |||||||||
Three Months Ended March 31 | |||||||||
(Thousands of Dollars) | 2014 | 2013 | |||||||
Interest income | $ | 187 | $ | 113 | |||||
Other nonoperating income | — | 3 | |||||||
Insurance policy expense | (144 | ) | (164 | ) | |||||
Other nonoperating expense | (2 | ) | — | ||||||
Other income (expense), net | $ | 41 | $ | (48 | ) | ||||
Benefit_Plans_and_Other_Postre1
Benefit Plans and Other Postretirement Benefits (Tables) | 3 Months Ended | ||||||||||||||||
Mar. 31, 2014 | |||||||||||||||||
Compensation and Retirement Disclosure [Abstract] | ' | ||||||||||||||||
Components of Net Periodic Benefit Cost (Credit) | ' | ||||||||||||||||
Components of Net Periodic Benefit Cost (Credit) | |||||||||||||||||
Three Months Ended March 31 | |||||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||||
(Thousands of Dollars) | Pension Benefits | Postretirement Health | |||||||||||||||
Care Benefits | |||||||||||||||||
Service cost | $ | 2,296 | $ | 2,404 | $ | 312 | $ | 342 | |||||||||
Interest cost | 5,111 | 4,477 | 643 | 588 | |||||||||||||
Expected return on plan assets | (6,545 | ) | (5,993 | ) | (812 | ) | (796 | ) | |||||||||
Amortization of prior service cost (credit) | 14 | 218 | (100 | ) | (121 | ) | |||||||||||
Amortization of net loss (gain) | 3,332 | 4,287 | (80 | ) | (2 | ) | |||||||||||
Net periodic benefit cost (credit) | 4,208 | 5,393 | (37 | ) | 11 | ||||||||||||
Credits (costs) not recognized due to the effects of regulation | 707 | (1,075 | ) | — | — | ||||||||||||
Net benefit cost (credit) recognized for financial reporting | $ | 4,915 | $ | 4,318 | $ | (37 | ) | $ | 11 | ||||||||
Other_Comprehensive_Income_Tab
Other Comprehensive Income (Tables) | 3 Months Ended | |||||||||
Mar. 31, 2014 | ||||||||||
Stockholders' Equity Note [Abstract] | ' | |||||||||
Changes in Accumulated Other Comprehensive Loss, Net of Tax | ' | |||||||||
Changes in accumulated other comprehensive loss, net of tax, for the three months ended March 31, 2014 and 2013 were as follows: | ||||||||||
Gains and Losses on | ||||||||||
Cash Flow Hedges | ||||||||||
(Thousands of Dollars) | Three Months Ended March 31, 2014 | Three Months Ended March 31, 2013 | ||||||||
Accumulated other comprehensive loss at Jan. 1 | $ | (1,161 | ) | $ | (1,332 | ) | ||||
Losses reclassified from net accumulated other comprehensive loss | 43 | 42 | ||||||||
Net current period other comprehensive income | 43 | 42 | ||||||||
Accumulated other comprehensive loss at March 31 | $ | (1,118 | ) | $ | (1,290 | ) | ||||
Reclassifications out of Accumulated Other Comprehensive Loss | ' | |||||||||
Reclassifications from accumulated other comprehensive loss for the three months ended March 31, 2014 and 2013 were as follows: | ||||||||||
Amounts Reclassified from | ||||||||||
Accumulated Other | ||||||||||
Comprehensive Loss | ||||||||||
(Thousands of Dollars) | Three Months Ended March 31, 2014 | Three Months Ended March 31, 2013 | ||||||||
Losses on cash flow hedges: | ||||||||||
Interest rate derivatives | $ | 67 | (a) | $ | 66 | (a) | ||||
Total, pre-tax | 67 | 66 | ||||||||
Tax benefit | (24 | ) | (24 | ) | ||||||
Total amounts reclassified, net of tax | $ | 43 | $ | 42 | ||||||
(a) | Included in interest charges. |
Selected_Balance_Sheet_Data_De
Selected Balance Sheet Data (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
In Thousands, unless otherwise specified | ||
Accounts receivable, net | ' | ' |
Accounts receivable | $73,543 | $76,426 |
Less allowance for bad debts | -5,809 | -5,475 |
Accounts receivable, net | $67,734 | $70,951 |
Selected_Balance_Sheet_Data_Ba
Selected Balance Sheet Data Balance Sheet Related Disclosures, Inventories (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
In Thousands, unless otherwise specified | ||
Public Utilities, Inventory [Line Items] | ' | ' |
Inventories | $32,007 | $37,138 |
Materials and supplies | ' | ' |
Public Utilities, Inventory [Line Items] | ' | ' |
Inventories | 24,011 | 21,600 |
Fuel | ' | ' |
Public Utilities, Inventory [Line Items] | ' | ' |
Inventories | $7,996 | $15,538 |
Selected_Balance_Sheet_Data_Ba1
Selected Balance Sheet Data Balance Sheet Related Disclosures, Property, Plant and Equipment (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
In Thousands, unless otherwise specified | ||
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' |
Property, plant and equipment, gross | $5,235,726 | $5,102,721 |
Less accumulated depreciation | -1,840,452 | -1,818,691 |
Property, plant and equipment, net | 3,395,274 | 3,284,030 |
Electric plant | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' |
Property, plant and equipment, gross | 4,789,975 | 4,714,398 |
Construction work in progress | ' | ' |
Public Utility, Property, Plant and Equipment [Line Items] | ' | ' |
Property, plant and equipment, gross | $445,751 | $388,323 |
Income_Taxes_Details
Income Taxes (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 | Mar. 31, 2014 | Sep. 30, 2012 | Mar. 31, 2014 |
Internal Revenue Service (IRS) | Internal Revenue Service (IRS) | State Jurisdiction (Texas) | |||
Tax Audits [Abstract] | ' | ' | ' | ' | ' |
Year(s) no longer subject to audit as statute of limitations has expired | ' | ' | '2008 | ' | ' |
Earliest year subject to examination | ' | ' | '2009 | ' | '2009 |
Year(s) under examination | ' | ' | ' | '2010 and 2011 | ' |
Tax Adjustments, Settlements, and Unusual Provisions | ' | ' | $10,000,000 | ' | ' |
Unrecognized Tax Benefits [Abstract] | ' | ' | ' | ' | ' |
Unrecognized tax benefit - Permanent tax positions | 200,000 | 1,200,000 | ' | ' | ' |
Unrecognized tax benefit - Temporary tax positions | 2,300,000 | 2,900,000 | ' | ' | ' |
Total unrecognized tax benefit | 2,500,000 | 4,100,000 | ' | ' | ' |
NOL and tax credit carryforwards | -1,300,000 | -2,400,000 | ' | ' | ' |
Amounts accrued for penalties related to unrecognized tax benefits | $0 | $0 | ' | ' | ' |
Rate_Matters_Details
Rate Matters (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 | Jan. 31, 2014 | Nov. 30, 2013 | Mar. 31, 2014 | Sep. 30, 2013 | Dec. 31, 2012 | Oct. 31, 2013 | Aug. 31, 2013 | Mar. 31, 2014 | Dec. 31, 2013 | Aug. 31, 2013 | Aug. 31, 2013 | Apr. 30, 2014 |
Public Utility Commission of Texas (PUCT) | Public Utility Commission of Texas (PUCT) | New Mexico Public Regulation Commission (NMPRC) | New Mexico Public Regulation Commission (NMPRC) | New Mexico Public Regulation Commission (NMPRC) | Federal Energy Regulatory Commission (FERC) | Federal Energy Regulatory Commission (FERC) | Federal Energy Regulatory Commission (FERC) | Federal Energy Regulatory Commission (FERC) | Federal Energy Regulatory Commission (FERC) | Federal Energy Regulatory Commission (FERC) | Subsequent Event | |||
2014 Electric Rate Case | Transmission Cost Recovery Factor (TCRF) Rider | 2014 Electric Rate Case | 2014 Electric Rate Case | 2014 Electric Rate Case | FERC Orders | FERC Orders | FERC Orders | FERC Orders | FERC Orders, Settlement Impact Through May 31, 2015 | FERC Orders, Settlement Impact Effective June 1, 2015 | Public Utility Commission of Texas (PUCT) | |||
Factor | 2014 Electric Rate Case | |||||||||||||
Rate Matters [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Rate Increase (Decrease), Net Amount | ' | ' | $52,700,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Rate Increase (Decrease), Percentage | ' | ' | 5.80% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Return on Equity, Percentage | ' | ' | 10.40% | ' | ' | 10.25% | 10.65% | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Rate Base, Amount | ' | ' | 1,270,000,000 | ' | ' | ' | 479,800,000 | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Equity Capital Structure, Percentage | ' | ' | 53.89% | ' | ' | ' | 53.89% | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Portion of requested rate increase (decrease) related to depreciation expense | ' | ' | 16,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Rate Increase (Decrease), Amended, Net Amount | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 48,100,000 |
Public Utilities, Requested Rate Increase (Decrease), Amended, Percentage | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 5.30% |
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | ' | ' | ' | ' | ' | 32,500,000 | ' | ' | ' | ' | ' | ' | ' | 76,900,000 |
Public Utilities, Adjustment requested by public utility to rate increase (decrease) related to resetting TCRF to zero | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | -12,900,000 |
Public Utilities, Adjustment requested by public utility to rate increase (decrease) related to customer credit for gain on sale | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | -4,900,000 |
Public Utilities, Requested base revenue increase (decrease) excluding fuel clause offsets, Amended | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 59,100,000 |
Public Utilities, Adjustment requested by public utility to rate increase (decrease) related to fuel offsets | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | -11,000,000 |
Public Utilities, Requested increase (decrease) to rider revenue | ' | ' | ' | 13,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Requested Rate Increase (Decrease), Amount | ' | ' | ' | ' | ' | ' | 45,900,000 | ' | ' | ' | ' | ' | ' | ' |
Public utilities, portion of revised rate increase (decrease) related to base and fuel revenue. | ' | ' | ' | ' | ' | 20,900,000 | ' | ' | ' | ' | ' | ' | ' | ' |
Public utilities, portion of revised rate increase (decrease) related to rider revenue | ' | ' | ' | ' | ' | 12,100,000 | ' | ' | ' | ' | ' | ' | ' | ' |
Public utilities, portion of revised rate increase (decrease) related to other costs | ' | ' | ' | ' | ' | -500,000 | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Approved Rate Increase (Decrease), Amount | ' | ' | ' | ' | 33,100,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Approved Return on Equity, Percentage | ' | ' | ' | ' | 9.96% | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Approved Equity Capital Structure, Percentage | ' | ' | ' | ' | 53.89% | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Approved Rate Increase (Decrease) due to pension, Amount | ' | ' | ' | ' | 2,400,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public utilities, portion of approved rate increase (decrease) to be recovered through rider revenue | ' | ' | ' | ' | 18,100,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public utilities, portion of approved rate increase (decrease) to be recovered through fuel clause adjustment | ' | ' | ' | ' | 2,300,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public utilities, revised rate increase (decrease), fuel adjusted | ' | ' | ' | ' | 34,800,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Approved Rate Increase (Decrease) due to return on equity, Amount | ' | ' | ' | ' | -1,200,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, approved rate increase (decrease) due to rider adjustment for renewable energy costs | ' | ' | ' | ' | 6,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, approved rate increase (decrease) due to base rate adjustment for renewable energy costs | ' | ' | ' | ' | -6,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, Approved Rate Increase (Decrease) due to other, Amount | ' | ' | ' | ' | -500,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Public Utilities, portion of approved rate increase (decrease) to be recovered in base revenue | ' | ' | ' | ' | 12,700,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Number of components included in regulatory proceeding | ' | ' | ' | ' | ' | ' | ' | ' | 2 | ' | ' | ' | ' | ' |
Number of coincident peaks used as demand allocator, revised | ' | ' | ' | ' | ' | ' | ' | 3 | 3 | ' | ' | ' | ' | ' |
Number of coincident peaks used as demand allocator, original | ' | ' | ' | ' | ' | ' | ' | ' | 12 | ' | ' | ' | ' | ' |
Other Liabilities, Current | 77,036,000 | 75,355,000 | ' | ' | ' | ' | ' | ' | ' | ' | 44,500,000 | ' | ' | ' |
Current year pre-tax earnings impact of regulatory proceedings | ' | ' | ' | ' | ' | ' | ' | ' | ' | 1,900,000 | ' | ' | ' | ' |
Public utilities, annual increase (decrease) in revenues resulting from regulatory proceeding | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ($6,000,000) | ($4,000,000) | ' |
Commitments_and_Contingencies_
Commitments and Contingencies, Purchased Power Agreements (Details) (Independent Power Producing Entities) | Mar. 31, 2014 | Dec. 31, 2013 |
MW | MW | |
Independent Power Producing Entities | ' | ' |
Purchased Power Agreements [Abstract] | ' | ' |
Generating capacity (in MW) | 827 | 827 |
Commitments_and_Contingencies_1
Commitments and Contingencies Commitments and Contingencies, Guarantees and Indemnifications (Details) (Indemnification Agreement, Obligations Under Sale Of Sharyland, USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
In Millions, unless otherwise specified | ||
Indemnification Agreement | Obligations Under Sale Of Sharyland | ' | ' |
Guarantor Obligations [Line Items] | ' | ' |
Guarantee issued and outstanding | $37.10 | $37.10 |
Guarantor Obligations, Current Carrying Value | $0.40 | $0.40 |
Commitments_and_Contingencies_2
Commitments and Contingencies, Environmental Contingencies - Unrecorded Unconditional Purchase Obligation (Details) (Subsequent Event, Cross-State Air Pollution Rule) | Apr. 30, 2014 |
Subsequent Event | Cross-State Air Pollution Rule | ' |
Environmental Requirements [Abstract] | ' |
Number of issues on which the D.C. Circuit overturned the CSAPR | 2 |
Commitments_and_Contingencies_3
Commitments and Contingencies, Legal Contingencies (Details) (Exelon Wind Complaint [Member], USD $) | Mar. 31, 2014 |
Site | |
Dispute | |
Exelon Wind Complaint [Member] | ' |
Legal Contingencies [Abstract] | ' |
Accrual for legal contingency | $0 |
Number of main areas of dispute | 2 |
Number of wind facilities | 12 |
Borrowings_and_Other_Financing2
Borrowings and Other Financing Instruments, Short-Term Borrowings (Details) (USD $) | 3 Months Ended | 12 Months Ended |
Mar. 31, 2014 | Dec. 31, 2013 | |
Short-term Debt [Line Items] | ' | ' |
Amount outstanding at period end | $69,000,000 | $84,000,000 |
Money Pool | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Borrowing limit | 100,000,000 | 100,000,000 |
Amount outstanding at period end | 100,000,000 | 38,000,000 |
Average amount outstanding | 30,000,000 | 46,000,000 |
Maximum amount outstanding | 100,000,000 | 100,000,000 |
Weighted average interest rate, computed on a daily basis (in hundredths) | 0.21% | 0.15% |
Weighted average interest rate at period end (in hundredths) | 0.21% | 0.25% |
Commercial Paper | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Borrowing limit | 300,000,000 | 300,000,000 |
Amount outstanding at period end | 69,000,000 | 84,000,000 |
Average amount outstanding | 103,000,000 | 32,000,000 |
Maximum amount outstanding | $158,000,000 | $140,000,000 |
Weighted average interest rate, computed on a daily basis (in hundredths) | 0.25% | 0.30% |
Weighted average interest rate at period end (in hundredths) | 0.24% | 0.27% |
Borrowings_and_Other_Financing3
Borrowings and Other Financing Instruments, Letters of Credit (Details) (USD $) | 3 Months Ended | |
In Millions, unless otherwise specified | Mar. 31, 2014 | Dec. 31, 2013 |
Letters of Credit [Abstract] | ' | ' |
Terms of letters of credit (in years) | '1 year | ' |
Letters of credit outstanding under credit facilities | $21 | $25.50 |
Borrowings_and_Other_Financing4
Borrowings and Other Financing Instruments, Credit Facility (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 | |
Credit Facility [Abstract] | ' | ' | |
Credit facility | $300,000,000 | [1] | ' |
Drawn | 90,000,000 | [2] | ' |
Available | 210,000,000 | ' | |
Credit facility bank borrowings outstanding | $0 | $0 | |
[1] | Credit facility expires in July 2017. | ||
[2] | Includes outstanding commercial paper and letters of credit. |
Fair_Value_of_Financial_Assets2
Fair Value of Financial Assets and Liabilities, Derivative Instruments (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 | ||
In Millions, unless otherwise specified | MWh | MWh | ||
Credit Concentration Risk [Member] | ' | ' | ||
Consideration of Credit Risk and Concentrations [Abstract] | ' | ' | ||
Number of most significant counterparties for wholesale, trading and non-trading commodity and transmission activities with credit exposure | 10 | ' | ||
Credit Concentration Risk [Member] | Investment Grade Ratings from Standard & Poor's, Moody's, or Fitch Ratings [Member] | ' | ' | ||
Consideration of Credit Risk and Concentrations [Abstract] | ' | ' | ||
Number of most significant counterparties for wholesale, trading and non-trading commodity and transmission activities with credit exposure | 3 | ' | ||
Wholesale, trading and non-trading commodity and transmission activity credit exposure for the most significant counterparties | 16.4 | ' | ||
Percentage of wholesale, trading and non-trading commodity and transmission activity credit exposure for the most significant counterparties (in hundredths) | 17.00% | ' | ||
Credit Concentration Risk [Member] | No Investment Grade Ratings from External Credit Rating Agencies [Member] | ' | ' | ||
Consideration of Credit Risk and Concentrations [Abstract] | ' | ' | ||
Number of most significant counterparties for wholesale, trading and non-trading commodity and transmission activities with credit exposure | 7 | ' | ||
Wholesale, trading and non-trading commodity and transmission activity credit exposure for the most significant counterparties | 46.6 | ' | ||
Percentage of wholesale, trading and non-trading commodity and transmission activity credit exposure for the most significant counterparties (in hundredths) | 48.00% | ' | ||
Interest Rate Swap [Member] | ' | ' | ||
Interest Rate Derivatives [Abstract] | ' | ' | ||
Amount of accumulated other comprehensive gains (losses) related to interest rate derivatives expected to be reclassified into earnings within the next twelve months | -0.2 | ' | ||
Electric Commodity [Member] | ' | ' | ||
Gross Notional Amounts of Commodity FTRs [Abstract] | ' | ' | ||
Notional Amount | 3,989,000 | [1] | 5,989,000 | [1] |
[1] | Amounts are not reflective of net positions in the underlying commodities. |
Fair_Value_of_Financial_Assets3
Fair Value of Financial Assets and Liabilities, Impact of Derivative Activity (Details) (USD $) | 3 Months Ended | |
Mar. 31, 2014 | Mar. 31, 2013 | |
Financial Impact of Qualifying Fair Value Hedges on Earnings [Abstract] | ' | ' |
Derivative instruments designated as fair value hedges | $0 | $0 |
Recognized gains (losses) from fair value hedges or related hedged transactions | 0 | 0 |
Cash Flow Hedges [Member] | Interest Rate Contract [Member] | ' | ' |
Impact of Derivative Activity on Accumulated Other Comprehensive Loss Regulatory Assets and Liabilities and Income [Abstract] | ' | ' |
Pre-tax losses reclassified into income during the period from accumulated other comprehensive loss | -100,000 | -100,000 |
Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' |
Impact of Derivative Activity on Accumulated Other Comprehensive Loss Regulatory Assets and Liabilities and Income [Abstract] | ' | ' |
Pre-tax fair value losses recognized during the period in regulatory assets and liabilities | -1,400,000 | ' |
Pre-tax gains reclassified into income during the period from regulatory assets and liabilities | $2,800,000 | ' |
Fair_Value_of_Financial_Assets4
Fair Value of Financial Assets and Liabilities, Fair Value Measurements (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Collateral, Obligation to Return Cash, Offset | $0 | $0 | ||
Derivative Liability, Collateral, Right to Reclaim Cash, Offset | 0 | 0 | ||
Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 13,684,000 | 17,826,000 | ||
Other Noncurrent Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 39,083,000 | 41,056,000 | ||
Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 3,574,000 | 3,583,000 | ||
Other Noncurrent Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 33,316,000 | 34,207,000 | ||
Fair Value Measured on a Recurring Basis | Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 5,791,000 | 9,933,000 | ||
Fair Value Measured on a Recurring Basis | Other Current Assets [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 5,791,000 | 9,933,000 | ||
Fair Value Measured on a Recurring Basis | Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Other Current Liabilities [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 1 | Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 1 | Other Current Assets [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 1 | Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 1 | Other Current Liabilities [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 2 | Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 2 | Other Current Assets [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 2 | Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 2 | Other Current Liabilities [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 0 | 0 | ||
Fair Value Measured on a Recurring Basis | Level 3 | Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 10,433,000 | 16,420,000 | ||
Fair Value Measured on a Recurring Basis | Level 3 | Other Current Assets [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 10,433,000 | 16,420,000 | ||
Fair Value Measured on a Recurring Basis | Level 3 | Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 4,642,000 | 6,487,000 | ||
Fair Value Measured on a Recurring Basis | Level 3 | Other Current Liabilities [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 4,642,000 | 6,487,000 | ||
Fair Value Measured on a Recurring Basis | Fair Value Total | Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 10,433,000 | 16,420,000 | ||
Fair Value Measured on a Recurring Basis | Fair Value Total | Other Current Assets [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 10,433,000 | 16,420,000 | ||
Fair Value Measured on a Recurring Basis | Fair Value Total | Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 4,642,000 | 6,487,000 | ||
Fair Value Measured on a Recurring Basis | Fair Value Total | Other Current Liabilities [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 4,642,000 | 6,487,000 | ||
Fair Value Measured on a Recurring Basis | Counterparty Netting [Member] | Other Current Assets [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | -4,642,000 | [1] | -6,487,000 | [2] |
Fair Value Measured on a Recurring Basis | Counterparty Netting [Member] | Other Current Assets [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | -4,642,000 | [1] | -6,487,000 | [2] |
Fair Value Measured on a Recurring Basis | Counterparty Netting [Member] | Other Current Liabilities [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | -4,642,000 | [1] | -6,487,000 | [2] |
Fair Value Measured on a Recurring Basis | Counterparty Netting [Member] | Other Current Liabilities [Member] | Other Derivative Instruments [Member] | Electric Commodity Contract [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | -4,642,000 | [1] | -6,487,000 | [2] |
Fair Value, Measurements, Nonrecurring [Member] | Other Current Assets [Member] | Purchased Power Agreements [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 7,893,000 | [3] | 7,893,000 | [3] |
Fair Value, Measurements, Nonrecurring [Member] | Other Noncurrent Assets [Member] | Purchased Power Agreements [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Asset, Fair Value, Gross Asset | 39,083,000 | [3] | 41,056,000 | [3] |
Fair Value, Measurements, Nonrecurring [Member] | Other Current Liabilities [Member] | Purchased Power Agreements [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | 3,574,000 | [3] | 3,583,000 | [3] |
Fair Value, Measurements, Nonrecurring [Member] | Other Noncurrent Liabilities [Member] | Purchased Power Agreements [Member] | ' | ' | ||
Derivatives, Fair Value [Line Items] | ' | ' | ||
Derivative Liability, Fair Value, Gross Liability | $33,316,000 | [3] | $34,207,000 | [3] |
[1] | SPS nets derivative instruments and related collateral in its balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at March 31, 2014. At March 31, 2014, derivative assets and liabilities include no obligations to return cash collateral or rights to reclaim cash collateral. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. | |||
[2] | SPS nets derivative instruments and related collateral in its balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Dec. 31, 2013. At Dec. 31, 2013, derivative assets and liabilities include no obligations to return cash collateral or rights to reclaim cash collateral. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements. | |||
[3] | In 2003, as a result of implementing new guidance on the normal purchase exception for derivative accounting, SPS began recording several long-term PPAs at fair value due to accounting requirements related to underlying price adjustments. As these purchases are recovered through normal regulatory recovery mechanisms in the respective jurisdictions, the changes in fair value for these contracts were offset by regulatory assets and liabilities. During 2006, SPS qualified these contracts under the normal purchase exception. Based on this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities. |
Fair_Value_of_Financial_Assets5
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities, Changes in Level 3 Commodity Derivatives (Details) (Commodity Contract [Member], USD $) | 3 Months Ended | |
Mar. 31, 2014 | Mar. 31, 2013 | |
Commodity Contract [Member] | ' | ' |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ' | ' |
Balance at beginning of period | $9,933,000 | ' |
Purchases | 1,056,000 | ' |
Settlements | -1,101,000 | ' |
Losses recognized as regulatory assets and liabilities | -4,097,000 | ' |
Balance at end of period | 5,791,000 | 0 |
Transfers into Level 3 | 0 | 0 |
Transfers out of Level 3 | $0 | $0 |
Fair_Value_of_Financial_Assets6
Fair Value of Financial Assets and Liabilities, Fair Value of Long-Term Debt (Details) (USD $) | Mar. 31, 2014 | Dec. 31, 2013 |
In Thousands, unless otherwise specified | ||
Carrying Amount | ' | ' |
Financial Liabilities, Balance Sheet Groupings [Abstract] | ' | ' |
Long-term debt, including current portion | $1,199,937 | $1,199,865 |
Fair Value | ' | ' |
Financial Liabilities, Balance Sheet Groupings [Abstract] | ' | ' |
Long-term debt, including current portion | $1,361,503 | $1,307,035 |
Other_Income_Expense_Net_Detai
Other Income (Expense), Net (Details) (USD $) | 3 Months Ended | |
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 |
Other Income and Expenses [Abstract] | ' | ' |
Interest income | $187 | $113 |
Other nonoperating income | 0 | 3 |
Insurance policy expense | -144 | -164 |
Other Nonoperating Expense | -2 | 0 |
Other income (expense), net | $41 | ($48) |
Benefit_Plans_and_Other_Postre2
Benefit Plans and Other Postretirement Benefits (Details) (USD $) | 1 Months Ended | 3 Months Ended | |
Jan. 31, 2014 | Mar. 31, 2014 | Mar. 31, 2013 | |
Pension Benefits | ' | ' | ' |
Components of Net Periodic Benefit Cost (Credit) [Abstract] | ' | ' | ' |
Service cost | ' | $2,296,000 | $2,404,000 |
Interest cost | ' | 5,111,000 | 4,477,000 |
Expected return on plan assets | ' | -6,545,000 | -5,993,000 |
Amortization of prior service cost (credit) | ' | 14,000 | 218,000 |
Amortization of net loss (gain) | ' | 3,332,000 | 4,287,000 |
Net periodic benefit cost (credit) | ' | 4,208,000 | 5,393,000 |
Credits (costs) not recognized due to the effects of regulation | ' | 707,000 | -1,075,000 |
Net benefit cost (credit) recognized for financial reporting | ' | 4,915,000 | 4,318,000 |
Total contributions to the pension plans during the period | 4,400,000 | ' | ' |
Postretirement Health Care Benefits | ' | ' | ' |
Components of Net Periodic Benefit Cost (Credit) [Abstract] | ' | ' | ' |
Service cost | ' | 312,000 | 342,000 |
Interest cost | ' | 643,000 | 588,000 |
Expected return on plan assets | ' | -812,000 | -796,000 |
Amortization of prior service cost (credit) | ' | -100,000 | -121,000 |
Amortization of net loss (gain) | ' | -80,000 | -2,000 |
Net periodic benefit cost (credit) | ' | -37,000 | 11,000 |
Credits (costs) not recognized due to the effects of regulation | ' | 0 | 0 |
Net benefit cost (credit) recognized for financial reporting | ' | -37,000 | 11,000 |
Xcel Energy Inc. | Pension Benefits | ' | ' | ' |
Components of Net Periodic Benefit Cost (Credit) [Abstract] | ' | ' | ' |
Total contributions to the pension plans during the period | $130,000,000 | ' | ' |
Number of Xcel Energy's pension plans to which contributions were made | 3 | ' | ' |
Other_Comprehensive_Income_Det
Other Comprehensive Income (Details) (USD $) | 3 Months Ended | |||
In Thousands, unless otherwise specified | Mar. 31, 2014 | Mar. 31, 2013 | ||
Accumulated Other Comprehensive Income [Roll Forward] | ' | ' | ||
Accumulated other comprehensive loss at beginning of period | ($1,161) | ' | ||
Accumulated other comprehensive loss at end of period | -1,118 | ' | ||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ' | ' | ||
Total, pre-tax | -29,103 | -19,469 | ||
Tax benefit | 10,368 | 6,885 | ||
Gains and Losses on Cash Flow Hedges [Member] | ' | ' | ||
Accumulated Other Comprehensive Income [Roll Forward] | ' | ' | ||
Accumulated other comprehensive loss at beginning of period | -1,161 | -1,332 | ||
Losses reclassified from net accumulated other comprehensive loss | 43 | 42 | ||
Net current period other comprehensive income | 43 | 42 | ||
Accumulated other comprehensive loss at end of period | -1,118 | -1,290 | ||
Gains and Losses on Cash Flow Hedges [Member] | Amounts Reclassified from Accumulated Other Comprehensive Loss [Member] | ' | ' | ||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ' | ' | ||
Total, pre-tax | 67 | 66 | ||
Tax benefit | -24 | -24 | ||
Total, net of tax | 43 | 42 | ||
Gains and Losses on Cash Flow Hedges [Member] | Interest Rate Derivatives [Member] | Amounts Reclassified from Accumulated Other Comprehensive Loss [Member] | ' | ' | ||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ' | ' | ||
Interest Income (Expense), Net | $67 | [1] | $66 | [1] |
[1] | Included in interest charges. |