10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended June 30, 2013

or

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

Commission File Number: 001-03140

Northern States Power Company

(Exact name of registrant as specified in its charter)

Wisconsin	39-0508315
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
1414 West Hamilton Avenue
Eau Claire, Wisconsin	54701
(Address of principal executive offices)	(Zip Code)

(715) 737-2625

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 and Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  x Yes  ¨ No

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

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

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

Class	Outstanding at Aug. 5, 2013
Common Stock, $100 par value	933,000 shares

Northern States Power Company (a Wisconsin corporation) meets the conditions set forth in General Instruction H (1)(a) and (b) of Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format specified in General Instruction H (2) to such Form 10-Q.

TABLE OF CONTENTS

PART I — FINANCIAL INFORMATION
Item l    —	Financial Statements (Unaudited)	3
Item 2   —	Management’s Discussion and Analysis of Financial Condition and Results of Operations	19
Item 4   —	Controls and Procedures	23
PART II — OTHER INFORMATION
Item 1    —	Legal Proceedings	23
Item 1A —	Risk Factors	23
Item 4    —	Mine Safety Disclosures	23
Item 5    —	Other Information	23
Item 6    —	Exhibits	24
SIGNATURES		25

Certifications Pursuant to Section 302	1
Certifications Pursuant to Section 906	1
Statement Pursuant to Private Litigation	1

This Form 10-Q is filed by Northern States Power Company, a Wisconsin corporation (NSP-Wisconsin).  NSP-Wisconsin is a wholly owned subsidiary of Xcel Energy Inc.  Xcel Energy Inc. wholly owns the following subsidiaries: Northern States Power Company, a Minnesota corporation (NSP-Minnesota); Southwestern Public Service Company, a New Mexico corporation (SPS); Public Service Company of Colorado, a Colorado corporation (PSCo); and NSP-Wisconsin.  NSP-Minnesota, NSP-Wisconsin, PSCo and SPS are also referred to collectively as utility subsidiaries.  Additional information on Xcel Energy Inc. and its subsidiaries (collectively, Xcel Energy) is available on various filings with the Securities and Exchange Commission (SEC).

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PART I — FINANCIAL INFORMATION

Item 1 — ­FINANCIAL STATEMENTS

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(amounts in thousands)

	Three Months Ended June 30						Six Months Ended June 30
	2013			2012			2013			2012
Operating revenues
Electric	$	185,374		$	179,105		$	376,185		$	361,106
Natural gas	24,555			14,830			74,912			56,322
Other	246			238			493			544
Total operating revenues	210,175			194,173			451,590			417,972
Operating expenses
Electric fuel and purchased power, non-affiliates	1,862			4,467			6,032			7,914
Purchased power, affiliates	100,043			98,813			198,985			197,980
Cost of natural gas sold and transported	14,302			7,123			45,287			34,002
Operating and maintenance expenses	42,992			42,492			84,668			80,992
Conservation program expenses	3,118			3,620			6,110			7,122
Depreciation and amortization	19,051			17,093			37,906			34,102
Taxes (other than income taxes)	6,341			6,217			12,735			12,598
Total operating expenses	187,709			179,825			391,723			374,710
Operating income	22,466			14,348			59,867			43,262
Other income (expense), net	155			(40		)	270			460
Allowance for funds used during construction — equity	780			765			1,726			1,764
Interest charges and financing costs
Interest charges — includes other financing costs of $380, $384, $761 and $810, respectively	6,814			6,044			13,669			12,059
Allowance for funds used during construction — debt	(400		)	(139		)	(809		)	(225		)
Total interest charges and financing costs	6,414			5,905			12,860			11,834
Income before income taxes	16,987			9,168			49,003			33,652
Income taxes	6,443			3,426			18,774			13,032
Net income	$	10,544		$	5,742		$	30,229		$	20,620

See Notes to Consolidated Financial Statements

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NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(amounts in thousands)

	Three Months Ended June 30				Six Months Ended June 30
	2013		2012		2013		2012
Net income	$	10,544	$	5,742	$	30,229	$	20,620
Other comprehensive income
Derivative instruments:
Reclassification of losses to net income, net of tax of $14, $12, $26 and $25, respectively	18		19		37		38
Other comprehensive income	18		19		37		38
Comprehensive income	$	10,562	$	5,761	$	30,266	$	20,658

See Notes to Consolidated Financial Statements

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NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(amounts in thousands)

	Six Months Ended June 30
	2013			2012
Operating activities
Net income	$	30,229		$	20,620
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	38,476			34,680
Deferred income taxes	15,407			14,638
Amortization of investment tax credits	(332		)	(312		)
Allowance for equity funds used during construction	(1,726		)	(1,764		)
Net derivative (gains) losses	(344		)	63
Changes in operating assets and liabilities:
Accounts receivable	1,134			(9,458		)
Accrued unbilled revenues	9,928			9,625
Inventories	1,913			7,696
Other current assets	3,442			(712		)
Accounts payable	(5,435		)	1,860
Net regulatory assets and liabilities	(806		)	4,479
Other current liabilities	1,670			588
Pension and other employee benefit obligations	(10,234		)	(11,730		)
Change in other noncurrent assets	329			(228		)
Change in other noncurrent liabilities	630			582
Net cash provided by operating activities	84,281			70,627
Investing activities
Utility capital/construction expenditures	(81,603		)	(72,230		)
Allowance for equity funds used during construction	1,726			1,764
Other, net	(230		)	1,105
Net cash used in investing activities	(80,107		)	(69,361		)
Financing activities
(Repayments of) proceeds from short-term borrowings, net	(37,000		)	13,000
(Repayments of) proceeds from notes payable to affiliate	(80		)	50
Repayments of long-term debt	(92		)	(32		)
Capital contributions from parent	45,093			2,162
Dividends paid to parent	(15,186		)	(16,225		)
Net cash used in financing activities	(7,265		)	(1,045		)
Net change in cash and cash equivalents	(3,091		)	221
Cash and cash equivalents at beginning of period	4,459			1,571
Cash and cash equivalents at end of period	$	1,368		$	1,792
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(12,122	)	$	(11,302	)
Cash received (paid) for income taxes, net	39			(706		)
Supplemental disclosure of non-cash investing transactions:
Property, plant and equipment additions in accounts payable	$	9,134		$	5,748

See Notes to Consolidated Financial Statements

5

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (UNAUDITED)

(amounts in thousands, except share and per share data)

	June 30, 2013			Dec. 31, 2012
Assets
Current assets
Cash and cash equivalents	$	1,368		$	4,459
Accounts receivable, net	49,584			50,706
Accrued unbilled revenues	39,210			49,138
Inventories	17,773			19,685
Regulatory assets	15,197			12,048
Prepaid taxes	22,490			24,688
Deferred income taxes	2,445			—
Prepayments and other	2,251			4,394
Total current assets	150,318			165,118
Property, plant and equipment, net	1,343,713			1,298,236
Other assets
Regulatory assets	236,085			240,459
Other investments	3,461			3,232
Other	3,662			4,040
Total other assets	243,208			247,731
Total assets	$	1,737,239		$	1,711,085
Liabilities and Equity
Current liabilities
Current portion of long-term debt	$	103		$	1,246
Short-term debt	2,000			39,000
Notes payable to affiliates	470			550
Accounts payable	26,838			30,723
Accounts payable to affiliates	29,461			31,556
Dividends payable to parent	7,757			7,667
Regulatory liabilities	7,718			6,086
Environmental liabilities	17,561			23,427
Accrued interest	7,470			7,304
Other	11,577			11,794
Total current liabilities	110,955			159,353
Deferred credits and other liabilities
Deferred income taxes	280,604			261,800
Deferred investment tax credits	9,294			8,911
Regulatory liabilities	125,016			123,746
Environmental liabilities	87,170			84,655
Customer advances	16,449			15,631
Pension and employee benefit obligations	53,394			63,643
Other	8,672			8,923
Total deferred credits and other liabilities	580,599			567,309
Commitments and contingencies
Capitalization
Long-term debt	468,494			467,317
Common stock — 1,000,000 shares authorized of $100 par value; 933,000 shares outstanding at June 30, 2013 and Dec. 31, 2012, respectively	93,300			93,300
Additional paid in capital	234,961			189,867
Retained earnings	249,330			234,376
Accumulated other comprehensive loss	(400		)	(437		)
Total common stockholder’s equity	577,191			517,106
Total liabilities and equity	$	1,737,239		$	1,711,085

See Notes to Consolidated Financial Statements

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NSP-WISCONSIN AND SUBSIDIARIES

Notes to Consolidated Financial Statements (UNAUDITED)

In the opinion of management, the accompanying unaudited consolidated 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 NSP-Wisconsin and its subsidiaries as of June 30, 2013 and Dec. 31, 2012; the results of its operations, including the components of net income and comprehensive income, for the three and six months ended June 30, 2013 and 2012; and its cash flows for the six months ended June 30, 2013 and 2012.  All adjustments are of a normal, recurring nature, except as otherwise disclosed.  Management has also evaluated the impact of events occurring after June 30, 2013 up to the date of issuance of these consolidated financial statements.  These statements contain all necessary adjustments and disclosures resulting from that evaluation.  The Dec. 31, 2012 balance sheet information has been derived from the audited 2012 consolidated financial statements included in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012.  These notes to the consolidated 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 consolidated financial statements and notes thereto, included in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012, filed with the SEC on Feb. 25, 2013.  Due to the seasonality of NSP-Wisconsin’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.

1. Summary of Significant Accounting Policies

The significant accounting policies set forth in Note 1 to the consolidated financial statements in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012, appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin (NSP System) is operated on an integrated basis and managed by NSP-Minnesota. The electric production and transmission costs of the NSP System are shared by NSP-Minnesota and NSP-Wisconsin. A Federal Energy Regulatory Commission (FERC) approved Interchange Agreement between the two companies provides for the sharing of all generation and transmission costs of the NSP System. Such costs include current and potential obligations of NSP-Minnesota related to its nuclear generating facilities.

2. Accounting Pronouncements

Recently Adopted

Balance Sheet Offsetting — In December 2011, the Financial Accounting Standards Board (FASB) issued Balance Sheet (Topic 210) — Disclosures about Offsetting Assets and Liabilities (Accounting Standards Update (ASU) No. 2011-11), which requires disclosures regarding netting arrangements in agreements underlying derivatives, certain financial instruments and related collateral amounts, and the extent to which an entity’s financial statement presentation policies related to netting arrangements impact amounts recorded to the financial statements.  In January 2013, the FASB issued Balance Sheet (Topic 210) – Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities (ASU No. 2013-01) to clarify the specific instruments that should be considered in these disclosures.  These disclosure requirements do not affect the presentation of amounts in the consolidated balance sheets, and were effective for annual reporting periods beginning on or after Jan. 1, 2013, and interim periods within those annual reporting periods.  NSP-Wisconsin implemented the disclosure guidance effective Jan. 1, 2013, and the implementation did not have a material impact on its consolidated financial statements.  See Note 8 for the required disclosures.

Comprehensive Income Disclosures — In February 2013, the FASB issued Comprehensive Income (Topic 220)  — Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (ASU No. 2013-02), which requires detailed disclosures regarding changes in components of accumulated other comprehensive income and amounts reclassified out of accumulated other comprehensive income.  These disclosure requirements do not change how net income or comprehensive income are presented in the consolidated financial statements.  These disclosure requirements were effective for annual reporting periods beginning on or after Dec. 15, 2012, and interim periods within those annual reporting periods.  NSP-Wisconsin implemented the disclosure guidance effective Jan. 1, 2013, and the implementation did not have a material impact on its consolidated financial statements.  See Note 12 for the required disclosures.

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3. Selected Balance Sheet Data

(Thousands of Dollars)	June 30, 2013			Dec. 31, 2012
Accounts receivable, net
Accounts receivable	$	53,700		$	55,039
Less allowance for bad debts	(4,116		)	(4,333		)
	$	49,584		$	50,706

(Thousands of Dollars)	June 30, 2013		Dec. 31, 2012
Inventories
Materials and supplies	$	6,541	$	6,172
Fuel	7,268		6,664
Natural gas	3,964		6,849
	$	17,773	$	19,685

(Thousands of Dollars)	June 30, 2013			Dec. 31, 2012
Property, plant and equipment, net
Electric plant	$	1,848,303		$	1,795,239
Natural gas plant	227,790			224,625
Common and other property	112,043			111,319
Construction work in progress	77,144			62,629
Total property, plant and equipment	2,265,280			2,193,812
Less accumulated depreciation	(921,567		)	(895,576		)
	$	1,343,713		$	1,298,236

4. Income Taxes

Except to the extent noted below, the circumstances set forth in Note 6 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2012 appropriately represent, in all material respects, the current status of other income tax matters, and are incorporated herein by reference.

Federal Audit— NSP-Wisconsin 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.  As of June 30, 2013, the IRS had not proposed any material adjustments to tax years 2010 and 2011.

State Audits— NSP-Wisconsin is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of June 30, 2013, NSP-Wisconsin’s earliest open tax year that is subject to examination by state taxing authorities under applicable statutes of limitations is 2008.  In the first quarter of 2013, the state of Wisconsin commenced an examination of tax years 2009 through 2011.  As of June 30, 2013, no material adjustments had been proposed for these years.  There are currently no other 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.

8

A reconciliation of the amount of unrecognized tax benefit is as follows:

(Millions of Dollars)	June 30, 2013		Dec. 31, 2012
Unrecognized tax benefit — Permanent tax positions	$	0.1	$	0.1
Unrecognized tax benefit — Temporary tax positions	1.3		1.2
Total unrecognized tax benefit	$	1.4	$	1.3

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)	June 30, 2013			Dec. 31, 2012
NOL and tax credit carryforwards	$	(0.9	)	$	(0.9	)

It is reasonably possible that NSP-Wisconsin’s amount of unrecognized tax benefits could significantly change in the next 12 months as the IRS and state audits progress.  As the IRS examination moves closer to completion, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $1 million.

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 June 30, 2013 and Dec. 31, 2012 were not material.  No amounts were accrued for penalties related to unrecognized tax benefits as of June 30, 2013 or Dec. 31, 2012.

5. Rate Matters

Except to the extent noted below, the circumstances set forth in Note 10 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2012 appropriately represent, in all material respects, the current status of other rate matters, and are incorporated herein by reference.

Pending Regulatory Proceedings — Public Service Commission of Wisconsin (PSCW)

Base Rate

NSP-Wisconsin – Wisconsin 2014 Electric and Gas Rate Case—On May 31, 2013, NSP-Wisconsin filed a request with the PSCW to increase rates for electric and natural gas service effective Jan. 1, 2014. NSP-Wisconsin requested an overall increase in annual electric rates of $40.0 million, or 6.5 percent, and an increase in natural gas rates of $4.7 million, or 3.8 percent.

The rate filing is based on a 2014 forecast test year, a return on equity (ROE) of 10.4 percent, an equity ratio of 52.5 percent, and a forecasted average net investment rate base of approximately $895.3 million for the electric utility and $89.8 million for the natural gas utility.

Next steps in the procedural schedule are expected to be as follows:

• Staff and Intervenor Direct Testimony – Oct. 4, 2013

• Rebuttal Testimony – Oct. 18, 2013

• Surrebuttal testimony – Oct. 28, 2013

• Hearing – Oct. 30, 2013

• Initial Brief – Nov. 13, 2013

• Reply Brief – Nov. 20, 2013

A PSCW decision is anticipated in December 2013, with final rates going into effect in January 2014.

6. Commitments and Contingencies

Except as noted below and in Note 5, the circumstances set forth in Notes 10 and 11 to the consolidated financial statements in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2012 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 NSP-Wisconsin’s financial position.

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Guarantees — NSP-Wisconsin provides a guarantee for payment of customer loans related to NSP-Wisconsin’s farm rewiring program.  NSP-Wisconsin’s exposure under the guarantee is based upon the net liability under the agreement.  The guarantee issued by NSP-Wisconsin limits the exposure of NSP-Wisconsin to a maximum amount stated in the guarantee.  The guarantee contains no recourse provisions and requires no collateral.

The following table presents the guarantee issued and outstanding for NSP-Wisconsin:

(Millions of Dollars)	June 30, 2013		Dec. 31, 2012
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under the guarantee	0.4		0.4

Environmental Contingencies

Ashland Manufactured Gas Plant (MGP) Site — NSP-Wisconsin has been named a potentially responsible party (PRP) for contamination at a site in Ashland, Wis.  The Ashland/Northern States Power Lakefront Superfund Site (the Ashland site) includes property owned by NSP-Wisconsin, which was a site previously operated by a predecessor company as a MGP facility (the Upper Bluff), and two other properties: an adjacent city lakeshore park area (Kreher Park), on which an unaffiliated third party previously operated a sawmill and conducted creosote treating operations; and an area of Lake Superior’s Chequamegon Bay adjoining the park (the Sediments).

The U.S. Environmental Protection Agency (EPA) issued its Record of Decision (ROD) in 2010, which describes the preferred remedy the EPA has selected for the cleanup of the Ashland site.  In 2011, the EPA issued special notice letters identifying several entities, including NSP-Wisconsin, as PRPs, for future remediation at the site.  The special notice letters requested that those PRPs participate in negotiations with the EPA regarding how the PRPs intended to conduct or pay for the remediation at the Ashland site.  As a result of those settlement negotiations, the EPA agreed to segment the Ashland site into separate areas.  The first area (Phase I Project Area) includes soil and groundwater in Kreher Park and the Upper Bluff.  The second area includes the Sediments.

In October 2012, a settlement among the EPA, the Wisconsin Department of Natural Resources (WDNR), the Bad River and Red Cliff Bands of the Lake Superior Tribe of Chippewa Indians and NSP-Wisconsin was approved by the U.S. District Court for the Western District of Wisconsin.  This settlement resolves claims against NSP-Wisconsin for its alleged responsibility for the remediation of the Phase I Project Area.  Under the terms of the settlement, NSP-Wisconsin agreed to perform the remediation of the Phase I Project Area, but does not admit any liability with respect to the Ashland site.  The settlement reflects a cost estimate for the clean up of the Phase I Project Area of $40 million.  The settlement also resolves claims by the federal, state and tribal trustees against NSP-Wisconsin for alleged natural resource damages at the Ashland site, including both the Phase I Project Area and the Sediments.  As part of the settlement, NSP-Wisconsin has conveyed approximately 1,390 acres of land to the State of Wisconsin and tribal trustees.  Fieldwork to address the Phase I Project Area at the Ashland site began at the end of 2012 and continues in 2013.

Negotiations between the EPA and NSP-Wisconsin regarding who will pay or perform the cleanup of the Sediments are ongoing.  The EPA’s ROD for the Ashland site includes estimates that the cost of the preferred remediation related to the Sediments is between $63 million and $77 million, with a potential deviation in such estimated costs of up to 50 percent higher to 30 percent lower.

In August 2012, NSP-Wisconsin also filed litigation against other PRPs for their share of the cleanup costs for the Ashland site.  Trial for this matter has been scheduled for June 2014. Negotiations between the EPA, NSP-Wisconsin and several of the other PRPs regarding the PRPs’ fair share of the cleanup costs for the Ashland site are also ongoing.

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At June 30, 2013 and Dec. 31, 2012, NSP-Wisconsin had recorded a liability of $101.3 million and $103.7 million, respectively, for the Ashland site based upon potential remediation and design costs together with estimated outside legal and consultant costs; of which $14.3 million and $20.1 million, respectively, was considered a current liability.  The reduction in recorded liability at June 30, 2013 reflects that cleanup has now commenced and costs are being incurred with respect to the Phase I Project Area.  NSP-Wisconsin’s potential liability, the actual cost of remediation and the time frame over which the amounts may be paid are subject to change.  NSP-Wisconsin also continues to work to identify and access state and federal funds to apply to the ultimate remediation cost of the entire site.  Unresolved issues or factors that could result in higher or lower NSP-Wisconsin remediation costs for the Ashland site include the cleanup approach implemented for the Sediments, which party implements the cleanup, the timing of when the cleanup is implemented, potential contributions by other PRPs and whether federal or state funding may be directed to help offset remediation costs at the Ashland site.

NSP-Wisconsin has deferred the estimated site remediation costs, as a regulatory asset, based on an expectation that the PSCW will continue to allow NSP-Wisconsin to recover payments for environmental remediation from its customers.  The PSCW has consistently authorized in NSP-Wisconsin rates recovery of all remediation costs incurred at the Ashland site, and has authorized recovery of MGP remediation costs by other Wisconsin utilities.  External MGP remediation costs are subject to deferral in the Wisconsin retail jurisdiction and are reviewed for prudence as part of the Wisconsin retail rate case process.  Under an existing PSCW policy, utilities have recovered remediation costs for MGPs in natural gas rates, amortized over a four-to six-year period.  The PSCW historically has not allowed utilities to recover their carrying costs on unamortized regulatory assets for MGP remediation.

In a recent rate case decision, the PSCW recognized the potential magnitude of the future liability for the cleanup at the Ashland site.  In December 2012, the PSCW granted an exception to its existing policy at the request of NSP-Wisconsin.  The elements of this exception include: 1) approval to begin recovery of estimated Phase 1 Project costs beginning on Jan. 1, 2013; 2) approval to amortize these estimated costs over a ten-year period; and 3) approval to apply a three percent carrying cost to the unamortized regulatory asset.  Implementation of this exception will help mitigate the rate impact to natural gas customers and the risk to NSP-Wisconsin from a longer amortization period.

Environmental Requirements

Greenhouse Gas (GHG) New Source Performance Standard Proposal (NSPS) and Emission Guideline for Existing Sources — In April 2012, the EPA proposed a GHG NSPS for newly constructed power plants. The proposal requires that carbon dioxide (CO₂) emission rates be equal to a natural gas combined-cycle plant, even if the plant is coal-fired. The EPA also proposed that NSPS not apply to modified or reconstructed existing power plants and that installation of control equipment on existing plants would not constitute a “modification” to those plants under the NSPS program. On June 25, 2013, President Obama issued a memorandum directing the EPA to re-propose GHG emission standards for new power plants and develop GHG emission standards for existing power plants. It is not possible to evaluate the impact of these regulations until the upcoming proposals and final requirements are known.

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 nitrogen oxide (NOx) from utilities in the eastern half of the United States, including Wisconsin.  The CSAPR would have set more stringent requirements than the proposed Clean Air Transport Rule.  The rule also would have created an emissions trading program.

In August 2012, the U.S. 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 that the EPA must continue administering the Clean Air Interstate Rule (CAIR) pending adoption of a valid replacement.  Although the D.C. Circuit had denied all requests for rehearing, in June 2013, the U.S. Supreme Court elected to review the D.C. Circuit’s 2012 decision to vacate the CSAPR. The Court has ordered the parties to file briefs in the appeal this fall and will likely issue a decision by June 2014.

As the EPA continues administering the CAIR while the CSAPR or a replacement rule is pending, NSP-Wisconsin 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.  NSP-Wisconsin purchased allowances in 2012 and plans to continue to purchase allowances in 2013 to comply with the CAIR.  At June 30, 2013, the estimated annual CAIR NOx allowance cost for NSP-Wisconsin did not have a material impact on the results of operations, financial position or cash flows.

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Federal Clean Water Act - Effluent Limitations Guidelines (ELG) — In June 2013, the 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 (CCR). Refuse derived fuel, biomass and other alternatively fueled power plants are not addressed by the proposed revisions. The proposed rule identifies four potential regulatory options and invites comments on those regulatory approaches. The options differ in the number of waste streams covered, size of the units controlled and stringency of controls. The EPA is also seeking comment on the interaction between the ELG proposal and its proposed CCR rule, which is another proposed rule that would also regulate surface impoundments that store coal combustion byproducts (coal ash) and whether to regulate coal ash as hazardous or nonhazardous waste. A final rule is anticipated in 2014. Under the current proposed rule, facilities would need to comply as soon as possible after July 1, 2017 but no later than July 1, 2022. The impact of this rule on NSP-Wisconsin is uncertain at this time.

Legal Contingencies

NSP-Wisconsin 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 NSP-Wisconsin’s financial statements.  Unless otherwise required by GAAP, legal fees are expensed as incurred.

Environmental Litigation

Native Village of Kivalina vs. Xcel Energy Inc. et al. — In February 2008, the City and Native Village of Kivalina, Alaska, filed a lawsuit in the U.S. District Court for the Northern District of California against Xcel Energy and 23 other utility, oil, gas and coal companies.  Plaintiffs claim that defendants’ emission of CO₂ and other greenhouse gases contribute to global warming, which is harming their village.  Xcel Energy believes the claims asserted in this lawsuit are without merit and joined with other utility defendants in filing a motion to dismiss in June 2008.  In October 2009, the U.S. District Court dismissed the lawsuit on constitutional grounds.  In November 2009, plaintiffs filed a notice of appeal to the U.S. Court of Appeals for the Ninth Circuit (Ninth Circuit).  In October 2012, the Ninth Circuit affirmed the U.S. District Court’s dismissal and subsequently rejected plaintiffs’ request for rehearing.  In May 2013, the U.S. Supreme Court denied plaintiffs’ request for review, which brings this litigation to a close.  No accrual has been recorded for this matter.

Comer vs. Xcel Energy Inc. et al. — In May 2011, less than a year after their initial lawsuit was dismissed, plaintiffs in this purported class action lawsuit filed a second lawsuit against more than 85 utility, oil, chemical and coal companies in the U.S. District Court in Mississippi.  The complaint alleges defendants’ CO₂ emissions intensified the strength of Hurricane Katrina and increased the damage plaintiffs purportedly sustained to their property.  Plaintiffs base their claims on public and private nuisance, trespass and negligence.  Among the defendants named in the complaint are Xcel Energy Inc., SPS, PSCo, NSP-Wisconsin and NSP-Minnesota.  The amount of damages claimed by plaintiffs is unknown.  The defendants believe this lawsuit is without merit and filed a motion to dismiss the lawsuit.  In March 2012, the U.S. District Court granted this motion for dismissal.  In April 2012, plaintiffs appealed this decision to the U.S. Court of Appeals for the Fifth Circuit.  In May 2013, the Fifth Circuit affirmed the district court’s dismissal of this lawsuit. It is uncertain whether plaintiffs will seek further review of this decision. Although Xcel Energy believes the likelihood of loss is remote based upon existing case law, it is not possible to estimate the amount or range of reasonably possible loss in the event of an adverse outcome of this matter.  No accrual has been recorded for this matter.

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7. Borrowings and Other Financing Instruments

Commercial Paper — NSP-Wisconsin meets its short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under its credit facility.  Commercial paper outstanding for NSP-Wisconsin was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2013			Twelve Months Ended Dec. 31, 2012
Borrowing limit	$	150		$	150
Amount outstanding at period end	2			39
Average amount outstanding	11			61
Maximum amount outstanding	27			116
Weighted average interest rate, computed on a daily basis	0.27		%	0.39		%
Weighted average interest rate at period end	0.22			0.40

Letters of Credit— NSP-Wisconsin may use letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations.  At June 30, 2013 and Dec. 31, 2012, there were no letters of credit outstanding.

Credit Facility — In order to use its commercial paper program to fulfill short-term funding needs, NSP-Wisconsin 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 June 30, 2013, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility (a)		Drawn(b)		Available
$	150.0	$	2.0	$	148.0

^(a)  Credit facility expires in July 2017.

^(b)  Includes outstanding commercial paper.

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility.  NSP-Wisconsin had no direct advances on the credit facility outstanding at June 30, 2013 and Dec. 31, 2012.

Other Short-Term Borrowings— The following table presents the notes payable of Clearwater Investments, Inc., a NSP-Wisconsin subsidiary, to Xcel Energy Inc.:

(Amounts in Millions, Except Interest Rates)	June 30, 2013			Dec. 31, 2012
Notes payable to affiliates	$	0.5		$	0.6
Weighted average interest rate	0.27		%	0.33		%

8. 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.

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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 discounted cash flow or option pricing 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.

Derivative Instruments Fair Value Measurements

NSP-Wisconsin enters into derivative instruments, including forward contracts, futures, swaps and options, to manage risk in connection with changes in interest rates and utility commodity prices.

Interest Rate Derivatives — NSP-Wisconsin enters 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 June 30, 2013, accumulated other comprehensive loss related to interest rate derivatives included $0.1 million of net losses expected to be reclassified into earnings during the next 12 months as the related hedged interest rate transactions impact earnings.

There were immaterial pre-tax losses related to interest rate derivatives reclassified from accumulated other comprehensive loss into earnings during the three months ended June 30, 2013 and 2012, and $0.1 million of net losses reclassified from accumulated other comprehensive loss into earnings during the six months ended June 30, 2013 and 2012.

Commodity Derivatives — NSP-Wisconsin may enter into derivative instruments to manage variability of future cash flows from changes in commodity prices in its electric and natural gas operations, including the sale of natural gas or the purchase of natural gas for resale.

The following table details the gross notional amounts of commodity forwards and options at June 30, 2013 and Dec. 31, 2012:

(Amounts in Thousands)(a)(b)	June 30, 2013	Dec. 31, 2012
Million British thermal units (MMBtu) of natural gas	377	53

^(a)  Amounts are not reflective of net positions in the underlying commodities.

^(b)  Notional amounts for options are included on a gross basis, but are weighted for the probability of exercise.

Consideration of Credit Risk and Concentrations—NSP-Wisconsin continuously monitors the creditworthiness of the counterparties to its interest rate 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 NSP-Wisconsin’s own credit risk when determining the fair value of derivative liabilities, the impact of considering credit risk was immaterial to the fair value of commodity derivatives presented in the consolidated balance sheets.

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NSP-Wisconsin 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.

Financial Impact of Qualifying Cash Flow Hedges — The impact of qualifying interest rate cash flow hedges on NSP-Wisconsin’s accumulated other comprehensive loss, included as a component of common stockholder’s equity and in the consolidated statement of comprehensive income, is detailed in the following table: 

	Three Months Ended June 30
(Thousands of Dollars)	2013			2012
Accumulated other comprehensive loss related to cash flow hedges at April 1	$	(418	)	$	(495	)
After-tax net realized losses on derivative transactions reclassified into earnings	18			19
Accumulated other comprehensive loss related to cash flow hedges at June 30	$	(400	)	$	(476	)

	Six Months Ended June 30
(Thousands of Dollars)	2013			2012
Accumulated other comprehensive loss related to cash flow hedges at Jan. 1	$	(437	)	$	(514	)
After-tax net realized losses on derivative transactions reclassified into earnings	37			38
Accumulated other comprehensive loss related to cash flow hedges at June 30	$	(400	)	$	(476	)

During the three months ended June 30, 2013, changes in the fair value of natural gas commodity derivatives resulted in net losses of $0.2 million, recognized as regulatory assets and liabilities.  For the three months ended June 30, 2012, changes in the fair value of natural gas commodity derivatives resulted in immaterial net gains recognized as regulatory assets and liabilities.  During the six months ended June 30, 2013 and 2012, changes in the fair value of natural gas commodity derivatives resulted in net losses of $0.2 million and $0.4 million, respectively, recognized as regulatory assets and liabilities.  The classification as a regulatory asset or liability is based on commission approved regulatory recovery mechanisms.

Natural gas commodity derivatives settlement losses of $2.9 million were recognized during the six months ended June 30, 2012, and were subject to purchased natural gas cost recovery mechanisms, which result in reclassifications of derivative settlement gains and losses out of income to a regulatory asset or liability, as appropriate.  Such losses for the three and six months ended June 30, 2013, and the three months ended June 30, 2012, were immaterial.

NSP-Wisconsin had no derivative instruments designated as fair value hedges during the three and six months ended June 30, 2013 and 2012.

Recurring Fair Value Measurements — The following table presents for each of the fair value hierarchy levels, NSP-Wisconsin’s derivative assets measured at fair value on a recurring basis at June 30, 2013 and Dec. 31, 2012:

	June 30, 2013
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting(a)		Total(b)
Current derivative assets
Natural gas commodity	$	—	$	191	$	—	$	191	$	—	$	191

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	Dec. 31, 2012
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting(a)		Total(c)
Current derivative liabilities
Natural gas commodity	$	—	$	11	$	—	$	11	$	—	$	11

^(a)  NSP-Wisconsin nets derivative instruments and related collateral in its consolidated 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 June 30, 2013 and Dec. 31, 2012.  The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

^(b)  Included in other current assets balance of $2.3 million at June 30, 2013 in the consolidated balance sheets.

^(c)  Included in other current liabilities balance of $11.8 million at Dec. 31, 2012 in the consolidated balance sheets.

Fair Value of Long-Term Debt

As of June 30, 2013 and Dec. 31, 2012, other financial instruments for which the carrying amount did not equal fair value were as follows:

	June 30, 2013				Dec. 31, 2012
(Thousands of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	468,597	$	531,979	$	468,563	$	576,353

The fair value of NSP-Wisconsin’s 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 June 30, 2013 and Dec. 31, 2012, and given the observability of the inputs to these estimates, the fair values presented for long-term debt have been assigned a Level 2.  

9. Other Income (Expense), Net

Other income (expense), net consisted of the following:

	Three Months Ended June 30						Six Months Ended June 30
(Thousands of Dollars)	2013			2012			2013			2012
Interest income (expense)	$	197		$	(25	)	$	396		$	632
Other nonoperating income	29			46			70			39
Insurance policy expense	(69		)	(61		)	(191		)	(211		)
Other nonoperating expense	(2		)	—			(5		)	—
Other income (expense), net	$	155		$	(40	)	$	270		$	460

10. Segment Information

Operating results from the regulated electric utility and regulated natural gas utility are each separately and regularly reviewed by NSP-Wisconsin’s chief operating decision maker.  NSP-Wisconsin evaluates performance based on profit or loss generated from the product or service provided.  These segments are managed separately because the revenue streams are dependent upon regulated rate recovery, which is separately determined for each segment.

NSP-Wisconsin has the following reportable segments: regulated electric utility, regulated natural gas utility and all other.

• NSP-Wisconsin’s regulated electric utility segment generates electricity which is transmitted and distributed in Wisconsin and Michigan.  In addition, this segment includes sales for resale and provides wholesale transmission service to various entities primarily in Wisconsin.

• NSP-Wisconsin’s regulated natural gas utility segment purchases, transports, stores and distributes natural gas in portions of Wisconsin and Michigan.

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• Revenues from operating segments not included above are below the necessary quantitative thresholds and are therefore included in the all other category.  Those primarily include investments in rental housing projects that qualify for low-income housing tax credits.

Asset and capital expenditure information is not provided for NSP-Wisconsin’s reportable segments because as an integrated electric and natural gas utility, NSP-Wisconsin operates significant assets that are not dedicated to a specific business segment, and reporting assets and capital expenditures by business segment would require arbitrary and potentially misleading allocations which may not necessarily reflect the assets that would be required for the operation of the business segments on a stand-alone basis.

To report income from continuing operations for regulated electric and regulated natural gas utility segments, the majority of costs are directly assigned to each segment.  However, some costs, such as common depreciation, common operating and maintenance (O&M) expenses and interest expense are allocated based on cost causation allocators.  A general allocator is used for certain general and administrative expenses, including office supplies, rent, property insurance and general advertising.

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2013
Operating revenues	$	185,374	$	24,555	$	246	$	—		$	210,175
Intersegment revenues	83		278		—		(361		)	—
Total revenues	$	185,457	$	24,833	$	246	$	(361	)	$	210,175
Net income	$	10,068	$	201	$	275	$	—		$	10,544

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2012
Operating revenues	$	179,105	$	14,830		$	238	$	—		$	194,173
Intersegment revenues	109		61			—		(170		)	—
Total revenues	$	179,214	$	14,891		$	238	$	(170	)	$	194,173
Net income (loss)	$	6,127	$	(947	)	$	562	$	—		$	5,742

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2013
Operating revenues	$	376,185	$	74,912	$	493	$	—		$	451,590
Intersegment revenues	161		586		—		(747		)	—
Total revenues	$	376,346	$	75,498	$	493	$	(747	)	$	451,590
Net income	$	23,671	$	5,825	$	733	$	—		$	30,229

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2012
Operating revenues	$	361,106	$	56,322	$	544	$	—		$	417,972
Intersegment revenues	196		264		—		(460		)	—
Total revenues	$	361,302	$	56,586	$	544	$	(460	)	$	417,972
Net income	$	17,375	$	2,453	$	792	$	—		$	20,620

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11. Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2013			2012			2013			2012
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	1,420		$	1,150		$	6		$	5
Interest cost	1,731			1,925			190			274
Expected return on plan assets	(2,498		)	(2,634		)	(10		)	(12		)
Amortization of transition obligation	—			—			—			43
Amortization of prior service cost (credit)	104			443			(88		)	(3		)
Amortization of net loss	1,981			1,487			241			128
Net benefit cost recognized for financial reporting	$	2,738		$	2,371		$	339		$	435

	Six Months Ended June 30
	2013			2012			2013			2012
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	2,841		$	2,284		$	12		$	10
Interest cost	3,462			3,835			380			538
Expected return on plan assets	(4,997		)	(5,245		)	(21		)	(25		)
Amortization of transition obligation	—			—			—			86
Amortization of prior service cost (credit)	208			886			(176		)	(7		)
Amortization of net loss	3,962			2,922			482			242
Net benefit cost recognized for financial reporting	$	5,476		$	4,682		$	677		$	844

In January 2013, contributions of $191.5 million were made across four of Xcel Energy’s pension plans, of which $11.3 million was attributable to NSP-Wisconsin.  Xcel Energy does not expect additional pension contributions during 2013.

12. Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax, for the three and six months ended June 30, 2013 were as follows:

(Thousands of Dollars)	Gains and Losses on Cash Flow Hedges
Accumulated other comprehensive loss at April 1	$	(418	)
Losses reclassified from net accumulated other comprehensive loss	18
Net current period other comprehensive income	18
Accumulated other comprehensive loss at June 30	$	(400	)

(Thousands of Dollars)	Gains and Losses on Cash Flow Hedges
Accumulated other comprehensive loss at Jan. 1	$	(437	)
Losses reclassified from net accumulated other comprehensive loss	37
Net current period other comprehensive income	37
Accumulated other comprehensive loss at June 30	$	(400	)

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Reclassifications from accumulated other comprehensive loss for the three and six months ended June 30, 2013 were as follows:

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Three Months Ended June 30, 2013				Six Months Ended June 30, 2013
Losses on cash flow hedges:
Interest rate derivatives	$	32		(a)	$	63		(a)
Total, pre-tax	32				63
Tax benefit	(14		)		(26		)
Total amounts reclassified, net of tax	$	18			$	37

^(a)  Included in interest charges.

Item 2 — MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Discussion of financial condition and liquidity for NSP-Wisconsin is omitted per conditions set forth in general instructions H (1) (a) and (b) of Form 10-Q for wholly owned subsidiaries.  It is replaced with management’s narrative analysis of the results of operations set forth in general instructions H (2) (a) of Form 10-Q for wholly owned subsidiaries (reduced disclosure format).

Financial Review

The following discussion and analysis by management focuses on those factors that had a material effect on NSP-Wisconsin’s financial condition, results of operations and cash flows during the periods presented, or are expected to have a material impact in the future.  It should be read in conjunction with the accompanying unaudited consolidated financial statements and related notes to the consolidated financial statements.  Due to the seasonality of NSP-Wisconsin’s electric and natural gas sales, such interim results are not necessarily an appropriate base from which to project annual results.

Forward-Looking Statements

Except for the historical statements contained in this report, the matters discussed in the following discussion and analysis are forward-looking statements that are subject to certain risks, uncertainties and assumptions.  Such forward-looking statements are intended to be identified in this document by the words “anticipate,” “believe,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should” and similar expressions.  Actual results may vary materially.  Forward-looking statements speak only as of the date they are made, and we do not undertake any obligation to update them to reflect changes that occur after that date.  Factors that could cause actual results to differ materially include, but are not limited to: general economic conditions, including inflation rates, monetary fluctuations and their impact on capital expenditures and the ability of NSP-Wisconsin and its subsidiaries to obtain financing on favorable terms; business conditions in the energy industry, including the risk of a slow down in the U.S. economy or delay in growth recovery; trade, fiscal, taxation and environmental policies in areas where NSP-Wisconsin has a financial interest; customer business conditions; actions of credit rating agencies; competitive factors, including the extent and timing of the entry of additional competition in the markets served by NSP-Wisconsin and its subsidiaries; unusual weather; effects of geopolitical events, including war and acts of terrorism; state, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, have an impact on rates or have an impact on asset operation or ownership or impose environmental compliance conditions; structures that affect the speed and degree to which competition enters the electric and natural gas markets; costs and other effects of legal and administrative proceedings, settlements, investigations and claims; actions by regulatory bodies impacting NSP-Minnesota’s nuclear operations, including those affecting costs, operations or the approval of requests pending before the Nuclear Regulatory Commission (NRC); financial or regulatory accounting policies imposed by regulatory bodies; availability or cost of capital; employee workforce factors; the items described under Factors Affecting Results of Operations; and the other risk factors listed from time to time by NSP-Wisconsin in reports filed with the SEC, including “Risk Factors” in Item 1A of NSP-Wisconsin’s Form 10-K for the year ended Dec. 31, 2012, and Item 1A and Exhibit 99.01 to this Quarterly Report on Form 10-Q for the quarter ended June 30, 2013.

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Results of Operations

NSP-Wisconsin’s net income was $30.2 million for the six months ended June 30, 2013 compared with $20.6 million for the same period in 2012.  Higher earnings from electric and gas rates, effective January 2013, and the effect of cooler weather were partially offset by higher depreciation and O&M expenses.

Electric Revenues and Margin

Electric production expenses tend to vary with the quantity of electricity sold and changes in the unit costs of fuel and purchased power.  The electric fuel and purchased power cost recovery mechanism of the Wisconsin jurisdiction may not allow for complete recovery of all expenses and, therefore, changes in fuel or purchased power costs can impact earnings.  The following table details the electric revenues and margin:

	Six Months Ended June 30
(Millions of Dollars)	2013			2012
Electric revenues	$	376		$	361
Electric fuel and purchased power	(205		)	(206		)
Electric margin	$	171		$	155

The following tables summarize the components of the changes in electric revenues and electric margin for the six months ended June 30:

Electric Revenues

(Millions of Dollars)	2013 vs. 2012
Retail rate increase (Wisconsin)	$	16
Interchange billings with Minnesota	8
Estimated impact of weather	4
Fuel and purchased power cost recovery	3
Firm wholesale	(15		)
Other, net	(1		)
Total increase in electric revenues	$	15

Electric Margin

(Millions of Dollars)	2013 vs. 2012
Retail rate increase (Wisconsin)	$	16
Interchange billings with Minnesota	9
Estimated impact of weather	4
Firm wholesale	(10		)
Timing of fuel recovery	(5		)
Other, net	2
Total increase in electric margin	$	16

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Natural Gas Revenues and Margin

The cost of natural gas tends to vary with changing sales requirements and the cost of natural gas purchases.  However, due to the design of purchased natural gas cost recovery mechanisms to recover current expenses for sales to retail customers, fluctuations in the cost of natural gas have little effect on natural gas margin.  The following table details the natural gas revenues and margin:

	Six Months Ended June 30
(Millions of Dollars)	2013			2012
Natural gas revenues	$	75		$	56
Cost of natural gas sold and transported	(45		)	(34		)
Natural gas margin	$	30		$	22

The following tables summarize the components of the changes in natural gas revenues and natural gas margin for the six months ended June 30:

Natural Gas Revenues

(Millions of Dollars)	2013 vs. 2012
Purchased natural gas adjustment clause recovery	$	11
Estimated impact of weather	4
Retail rate increase (Wisconsin)	1
Other, net	3
Total increase in natural gas revenues	$	19

Natural Gas Margin

(Millions of Dollars)	2013 vs. 2012
Estimated impact of weather	$	4
Retail rate increase (Wisconsin)	1
Other, net	3
Total increase in natural gas margin	$	8

Non-Fuel Operating Expenses and Other Items

O&M Expenses — O&M expenses increased $3.7 million, or 4.5 percent, for the six months ended June 30, 2013 compared with the same period in 2012.  The following table summarizes the changes in O&M expenses:

(Millions of Dollars)	2013 vs. 2012
Employee benefits	$	1
Bad debt expense	1
Other electric and gas distribution expenses	1
Other, net	1
Total increase in O&M expenses	$	4

Depreciation and Amortization — Depreciation and amortization increased $3.8 million, or 11.2 percent, for the six months ended June 30, 2013 compared with the same periods in 2012. The increases are primarily attributable to normal system expansion.

Income Taxes — Income tax expense increased $5.7 million for the six months ended June 30, 2013 compared with the same period in 2012.  The increase in income tax expense was primarily due to higher pretax earnings in 2013. The ETR was 38.3 percent for the six months ended June 30, 2013 compared with 38.7 percent for the same period in 2012.  

21

Public Utility Regulation

2013 Electric Fuel Cost Recovery— NSP-Wisconsin’s electric fuel costs for the six months ended June 30, 2013 were higher than authorized in rates, and outside the two percent annual tolerance band established in the Wisconsin fuel cost recovery rules primarily due to extended outages at two baseload generation plants and higher than forecast prices in the MISO market. Under the fuel cost recovery rules, NSP-Wisconsin is at risk for the amount of under-recovery up to two percent of authorized annual fuel costs, up to $3.6 million. However, NSP-Wisconsin may defer the amount of under-recovery in excess of the two percent annual tolerance band for future rate recovery. Accordingly, NSP-Wisconsin recorded a deferral of approximately $1.8 million in June 2013. An application to recover the deferred amount cannot be made until 2013 annual actual fuel costs are known, and the amount of the deferral could increase or decrease based on actual fuel costs incurred for the remainder of the year. Rate recovery of the deferred amount is contingent on review and approval by the PSCW after opportunity for a hearing, and is subject to an earnings test based on NSP-Wisconsin’s most recently authorized ROE of 10.4 percent.

Summary of Recent Federal Regulatory Developments

The FERC has jurisdiction over rates for electric transmission service in interstate commerce and electricity sold at wholesale, hydro facility licensing, natural gas transportation, accounting practices and certain other activities of NSP-Wisconsin, including enforcement of North American Electric Reliability Corporation mandatory electric reliability standards. State and local agencies have jurisdiction over many of NSP-Wisconsin’s activities, including regulation of retail rates and environmental matters. See additional discussion in the summary of recent federal regulatory developments and public utility regulation sections of the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012.

Midcontinent Independent Transmission System Operator, Inc.(MISO) Transmission Pricing — The MISO Tariff presently provides for different allocation methods for the costs of new transmission investments depending on whether the project is primarily local or regional in nature.  If a project qualifies as a multi-value project (MVP), the costs would be fully allocated to all loads in the MISO region.  MVP eligibility is generally obtained for higher voltage (345 kV and higher) projects considered part of a portfolio of projects expected to serve multiple purposes, such as improved reliability, reduced congestion, transmission for renewable energy, and load serving.  Certain parties appealed the FERC MVP tariff orders to the U.S. Court of Appeals for the Seventh Circuit.  On June 7, 2013, the Court of Appeals for the Seventh Circuit upheld the FERC MVP tariff orders allocating MVP project costs regionally, but remanded the FERC decision to not apply the regional charge to transmission service transactions crossing into the PJM Interconnection, LLC Regional Transmission Organization (RTO). The NSP System has certain new transmission facilities for which other customers in MISO contribute to cost recovery.  Likewise, the NSP System also pays a share of the costs of projects constructed by other transmission owning entities.  The transmission revenues received by the NSP System from MISO, and the transmission charges paid to MISO, associated with projects subject to regional cost allocation could be significant in future periods.

FERC Order 1000, Transmission Planning and Cost Allocation (Order 1000) — The FERC issued Order 1000 adopting new requirements for transmission planning, cost allocation and development to be effective prospectively.  In Order 1000, the FERC required utilities to develop tariffs that provide for joint transmission planning and cost allocation for all FERC-jurisdictional utilities within a region.  In addition, Order 1000 required that regions coordinate to develop interregional plans for transmission planning and cost allocation.  A key provision of Order 1000 is a requirement that FERC-jurisdictional wholesale transmission tariffs exclude provisions that would grant the incumbent transmission owner a federal Right of First Refusal (ROFR) to build certain types of transmission projects in its service area. Various parties have appealed Order 1000 final rules to the D.C. Circuit Court of Appeals. NSP-Wisconsin is participating in the appeals in coordination with other MISO transmission owners and utilities who oppose certain aspects of the rules, including the ROFR prohibition. Initial briefs by parties challenging the final rules were filed May 28, 2013. The FERC is expected to submit its responsive brief in September 2013. Oral arguments have not yet been scheduled. The Court is unlikely to rule before 2014.

The removal of a federal ROFR will eliminate rights that NSP-Wisconsin currently has under the MISO tariff to build transmission within its footprint.  The FERC required that opportunity to build such projects would extend to competitive transmission developers.  Further, Wisconsin has not developed legislation that preserves ROFR rights for Wisconsin utilities at the state level. Compliance with Order 1000 for NSP-Wisconsin will occur through changes to the MISO tariff. MISO made its initial compliance filings to incorporate new provisions into its tariff regarding regional planning and cost allocation. The FERC has ruled on the compliance filing for MISO, directing further changes to fully address the requirements of Order 1000. NSP-Wisconsin has requested rehearing of a number of issues in this order, the rehearing request is pending the FERC’s action. In addition, MISO has received an extension of the deadline for filing its interregional planning and cost allocation agreement with the Midcontinent Area Power Pool (MAPP) which will likely delay that filing until late third quarter of 2013. Filings to address MISO interregional planning and cost allocation requirements with other regions were made on July 10, 2013.

22

Item 4 — CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

NSP-Wisconsin maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms. In addition, the disclosure controls and procedures ensure that information required to be disclosed is accumulated and communicated to management, including the chief executive officer (CEO) and chief financial officer (CFO), allowing timely decisions regarding required disclosure.  As of June 30, 2013, based on an evaluation carried out under the supervision and with the participation of NSP-Wisconsin’s management, including the CEO and CFO, of the effectiveness of its disclosure controls and the procedures, the CEO and CFO have concluded that NSP-Wisconsin’s disclosure controls and procedures were effective.

Internal Control Over Financial Reporting

No change in NSP-Wisconsin’s internal control over financial reporting has occurred during the most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, NSP-Wisconsin’s internal control over financial reporting.

Part II — OTHER INFORMATION

Item 1 — LEGAL PROCEEDINGS

In the normal course of business, various lawsuits and claims have arisen against NSP-Wisconsin.  NSP-Wisconsin has recorded an estimate of the probable cost of settlement or other disposition for such matters.

Additional Information

See Note 5 to the consolidated financial statements for further discussion of legal claims and environmental proceedings.

Item 1A — RISK FACTORS

NSP-Wisconsin’s risk factors are documented in Item 1A of Part I of its Annual Report on Form 10-K for the year ended Dec. 31, 2012, which is incorporated herein by reference.

Item 4 — MINE SAFETY DISCLOSURES

None.

Item 5 — OTHER INFORMATION

None.

23

Item 6 — EXHIBITS

* Indicates incorporation by reference

3.01*	Amended and Restated Articles of Incorporation of NSP-Wisconsin (Exhibit 3.01 to Form S-4 (file no. 333-112033) dated Jan. 21, 2004).
3.02*	By-Laws of NSP-Wisconsin as amended June 3, 2008 (Exhibit 3.02 to Form 10-Q (file no. 001-03140) dated Aug. 4, 2008).
31.01	Principal Executive Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.02	Principal Financial Officer’s certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.01	Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
99.01	Statement pursuant to Private Securities Litigation Reform Act of 1995.
101	The following materials from NSP-Wisconsin’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2013 are formatted in XBRL (eXtensible Business Reporting Language):  (i) the Consolidated Statements of Income, (ii) the Consolidated Statements of Comprehensive Income (iii) the Consolidated Statements of Cash Flows, (iv) the Consolidated Balance Sheets, (v) Notes to Condensed Consolidated Financial Statements, and (vi) document and entity information.

24

SIGNATURES

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

		Northern States Power Company (a Wisconsin corporation)
Aug. 5, 2013	By:	/s/ JEFFREY S. SAVAGE
		Jeffrey S. Savage
		Vice President and Controller
		/s/ TERESA S. MADDEN
		Teresa S. Madden
		Senior Vice President, Chief Financial Officer and Director

25

EX-31.01

Exhibit 31.01

CERTIFICATION

I, Mark E. Stoering, certify that:

1. I have reviewed this report on Form 10-Q of Northern States Power Company (a Wisconsin corporation);

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

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

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

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

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

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

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

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

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

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

Date: Aug. 5, 2013

/s/ MARK E. STOERING

Mark E. Stoering

President, Chief Executive Officer and Director

1

EX-31.02

Exhibit 31.02

CERTIFICATION

I, Teresa S. Madden, certify that:

1. I have reviewed this report on Form 10-Q of Northern States Power Company (a Wisconsin corporation);

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

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

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

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

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

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

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

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

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

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

Date: Aug. 5, 2013

/s/ TERESA S. MADDEN

Teresa S. Madden

Senior Vice President, Chief Financial Officer and Director

2

EX-32.01

Exhibit 32.01

OFFICER CERTIFICATION

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Northern States Power Company, a Wisconsin Corporation (NSP-Wisconsin) on Form 10-Q for the quarter ended June 30, 2013, as filed with the SEC on the date hereof (Form 10-Q), each of the undersigned officers of NSP-Wisconsin certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer’s knowledge:

(1) The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of NSP-Wisconsin as of the dates and for the periods expressed in the Form 10-Q.

Date: Aug. 5, 2013

/s/ MARK E. STOERING

Mark E. Stoering

President, Chief Executive Officer and Director

/s/ TERESA S. MADDEN

Teresa S. Madden

Senior Vice President, Chief Financial Officer and Director

The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of the Report or as a separate disclosure document.

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to NSP-Wisconsin and will be retained by NSP-Wisconsin and furnished to the SEC or its staff upon request.

1

EX-99.01

Exhibit 99.01

NSP-Wisconsin Cautionary Factors

The Private Securities Litigation Reform Act provides a “safe harbor” for forward-looking statements to encourage disclosures without the threat of litigation, providing those statements are identified as forward-looking and are accompanied by meaningful, cautionary statements identifying important factors that could cause the actual results to differ materially from those projected in the statement. Forward-looking statements are made in written documents and oral presentations of NSP-Wisconsin, Xcel Energy Inc. or any of its other subsidiaries. These statements are based on management’s beliefs as well as assumptions and information currently available to management.  Such forward-looking statements are intended to be identified in this document by the words “anticipate,” “believe,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should” and similar expressions.  In addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements, factors that could cause NSP-Wisconsin’s actual results to differ materially from those contemplated in any forward-looking statements include, among others, the following:

• Economic conditions, including inflation rates, monetary fluctuations and their impact on capital expenditures;

• The risk of a significant slowdown in growth or decline in the U.S. economy, the risk of delay in growth recovery in the U.S. economy or the risk of increased cost for insurance premiums, security and other items as a consequence of past or future terrorist attacks;

• Trade, monetary, fiscal, taxation and environmental policies of governments, agencies and similar organizations in geographic areas where NSP-Wisconsin has a financial interest;

• Customer business conditions, including demand for their products or services and supply of labor and materials used in creating their products and services;

• Financial or regulatory accounting principles or policies imposed by the FASB, the SEC, the FERC and similar entities with regulatory oversight;

• Availability or cost of capital such as changes in: interest rates; market perceptions of the utility industry, NSP-Wisconsin, Xcel Energy Inc. or any of its other subsidiaries; or security ratings;

• Factors affecting utility and nonutility operations such as unusual weather conditions; catastrophic weather-related damage; unscheduled generation outages, maintenance or repairs; unanticipated changes to fossil fuel, nuclear fuel or natural gas supply costs or availability due to higher demand, shortages, transportation problems or other developments; nuclear or environmental incidents; cyber incidents; or electric transmission or natural gas pipeline constraints;

• Employee workforce factors, including loss or retirement of key executives, collective-bargaining agreements with union employees, or work stoppages;

• Increased competition in the utility industry or additional competition in the markets served by NSP-Wisconsin, Xcel Energy Inc. and its other subsidiaries;

• State, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, have an impact on rate structures and affect the speed and degree to which competition enters the electric and natural gas markets; industry restructuring initiatives; transmission system operation and/or administration initiatives; recovery of investments made under traditional regulation; nature of competitors entering the industry; retail wheeling; a new pricing structure; and former customers entering the generation market;

• Environmental laws and regulations, including legislation and regulations relating to climate change, and the associated cost of  compliance;

• Rate-setting policies or procedures of regulatory entities, including environmental externalities, which are values established by regulators assigning environmental costs to each method of electricity generation when evaluating generation resource options;

• Nuclear regulatory policies and procedures, including operating regulations and spent nuclear fuel storage;

• Social attitudes regarding the utility and power industries;

• Cost and other effects of legal and administrative proceedings, settlements, investigations and claims;

• Technological developments that result in competitive disadvantages and create the potential for impairment of existing assets;

• Risks associated with implementations of new technologies; and

• Other business or investment considerations that may be disclosed from time to time in NSP-Wisconsin’s SEC filings, including “Risk Factors” in Item 1A of NSP-Wisconsin’s Form 10-K for the year ended Dec. 31, 2012, or in other publicly disseminated written documents.

NSP-Wisconsin undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.  The foregoing review of factors should not be construed as exhaustive.

1

XML

Fair Value of Financial Assets and Liabilities

6 Months Ended

Jun. 30, 2013

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 discounted cash flow or option pricing 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.

Derivative Instruments Fair Value Measurements

NSP-Wisconsin enters into derivative instruments, including forward contracts, futures, swaps and options, to manage risk in connection with changes in interest rates and utility commodity prices.

Interest Rate Derivatives — NSP-Wisconsin enters 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 June 30, 2013, accumulated other comprehensive loss related to interest rate derivatives included $0.1 million of net losses expected to be reclassified into earnings during the next 12 months as the related hedged interest rate transactions impact earnings.

There were immaterial pre-tax losses related to interest rate derivatives reclassified from accumulated other comprehensive loss into earnings during the three months ended June 30, 2013 and 2012, and $0.1 million of net losses reclassified from accumulated other comprehensive loss into earnings during the six months ended June 30, 2013 and 2012.

Commodity Derivatives — NSP-Wisconsin may enter into derivative instruments to manage variability of future cash flows from changes in commodity prices in its electric and natural gas operations, including the sale of natural gas or the purchase of natural gas for resale.

The following table details the gross notional amounts of commodity forwards and options at June 30, 2013 and Dec. 31, 2012:

(Amounts in Thousands)(a)(b)	June 30, 2013	Dec. 31, 2012
Million British thermal units (MMBtu) of natural gas	377	53

^(a)  Amounts are not reflective of net positions in the underlying commodities.

^(b)  Notional amounts for options are included on a gross basis, but are weighted for the probability of exercise.

Consideration of Credit Risk and Concentrations—NSP-Wisconsin continuously monitors the creditworthiness of the counterparties to its interest rate 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 NSP-Wisconsin’s own credit risk when determining the fair value of derivative liabilities, the impact of considering credit risk was immaterial to the fair value of commodity derivatives presented in the consolidated balance sheets.

NSP-Wisconsin 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.

Financial Impact of Qualifying Cash Flow Hedges — The impact of qualifying interest rate cash flow hedges on NSP-Wisconsin’s accumulated other comprehensive loss, included as a component of common stockholder’s equity and in the consolidated statement of comprehensive income, is detailed in the following table: 

	Three Months Ended June 30
(Thousands of Dollars)	2013			2012
Accumulated other comprehensive loss related to cash flow hedges at April 1	$	(418	)	$	(495	)
After-tax net realized losses on derivative transactions reclassified into earnings	18			19
Accumulated other comprehensive loss related to cash flow hedges at June 30	$	(400	)	$	(476	)

	Six Months Ended June 30
(Thousands of Dollars)	2013			2012
Accumulated other comprehensive loss related to cash flow hedges at Jan. 1	$	(437	)	$	(514	)
After-tax net realized losses on derivative transactions reclassified into earnings	37			38
Accumulated other comprehensive loss related to cash flow hedges at June 30	$	(400	)	$	(476	)

During the three months ended June 30, 2013, changes in the fair value of natural gas commodity derivatives resulted in net losses of $0.2 million, recognized as regulatory assets and liabilities.  For the three months ended June 30, 2012, changes in the fair value of natural gas commodity derivatives resulted in immaterial net gains recognized as regulatory assets and liabilities.  During the six months ended June 30, 2013 and 2012, changes in the fair value of natural gas commodity derivatives resulted in net losses of $0.2 million and $0.4 million, respectively, recognized as regulatory assets and liabilities.  The classification as a regulatory asset or liability is based on commission approved regulatory recovery mechanisms.

Natural gas commodity derivatives settlement losses of $2.9 million were recognized during the six months ended June 30, 2012, and were subject to purchased natural gas cost recovery mechanisms, which result in reclassifications of derivative settlement gains and losses out of income to a regulatory asset or liability, as appropriate.  Such losses for the three and six months ended June 30, 2013, and the three months ended June 30, 2012, were immaterial.

NSP-Wisconsin had no derivative instruments designated as fair value hedges during the three and six months ended June 30, 2013 and 2012.

Recurring Fair Value Measurements — The following table presents for each of the fair value hierarchy levels, NSP-Wisconsin’s derivative assets measured at fair value on a recurring basis at June 30, 2013 and Dec. 31, 2012:

	June 30, 2013
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting(a)		Total(b)
Current derivative assets
Natural gas commodity	$	—	$	191	$	—	$	191	$	—	$	191

	Dec. 31, 2012
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting(a)		Total(c)
Current derivative liabilities
Natural gas commodity	$	—	$	11	$	—	$	11	$	—	$	11

^(a)  NSP-Wisconsin nets derivative instruments and related collateral in its consolidated 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 June 30, 2013 and Dec. 31, 2012.  The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

^(b)  Included in other current assets balance of $2.3 million at June 30, 2013 in the consolidated balance sheets.

^(c)  Included in other current liabilities balance of $11.8 million at Dec. 31, 2012 in the consolidated balance sheets.

Fair Value of Long-Term Debt

As of June 30, 2013 and Dec. 31, 2012, other financial instruments for which the carrying amount did not equal fair value were as follows:

	June 30, 2013				Dec. 31, 2012
(Thousands of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	468,597	$	531,979	$	468,563	$	576,353

The fair value of NSP-Wisconsin’s 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 June 30, 2013 and Dec. 31, 2012, and given the observability of the inputs to these estimates, the fair values presented for long-term debt have been assigned a Level 2.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Comprehensive income:
Net income	$ 10,544	$ 5,742	$ 30,229	$ 20,620
Derivative instruments:
Reclassification of losses to net income, net of tax of $14, $12, $26 and $25, respectively	18	19	37	38
Other comprehensive income	18	19	37	38
Comprehensive income	$ 10,562	$ 5,761	$ 30,266	$ 20,658

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2013

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

The significant accounting policies set forth in Note 1 to the consolidated financial statements in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012, appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin (NSP System) is operated on an integrated basis and managed by NSP-Minnesota. The electric production and transmission costs of the NSP System are shared by NSP-Minnesota and NSP-Wisconsin. A Federal Energy Regulatory Commission (FERC) approved Interchange Agreement between the two companies provides for the sharing of all generation and transmission costs of the NSP System. Such costs include current and potential obligations of NSP-Minnesota related to its nuclear generating facilities.

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Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Guarantee Issued and Outstanding

The following table presents the guarantee issued and outstanding for NSP-Wisconsin:

(Millions of Dollars)	June 30, 2013		Dec. 31, 2012
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under the guarantee	0.4		0.4

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Other Income (Expense), Net

6 Months Ended

Jun. 30, 2013

Other Income and Expenses [Abstract]

Other Income (Expense), Net

Other Income (Expense), Net

Other income (expense), net consisted of the following:

	Three Months Ended June 30						Six Months Ended June 30
(Thousands of Dollars)	2013			2012			2013			2012
Interest income (expense)	$	197		$	(25	)	$	396		$	632
Other nonoperating income	29			46			70			39
Insurance policy expense	(69		)	(61		)	(191		)	(211		)
Other nonoperating expense	(2		)	—			(5		)	—
Other income (expense), net	$	155		$	(40	)	$	270		$	460

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Fair Value of Financial Assets and Liabilities, Fair Value of Long-Term Debt (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Carrying Amount
Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, including current portion	$ 468,597	$ 468,563
Fair Value
Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, including current portion	$ 531,979	$ 576,353

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Commitments and Contingencies Commitments and Contingencies, Environmental Contingencies - Unrecorded Unconditional Purchase Obligation (Details) (Federal Clean Water Act)	Jun. 30, 2013 Regulation
Federal Clean Water Act
Environmental Requirements [Abstract]
Number of potential regulatory options under the proposed Effluent Limitations Guidelines rule	4

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Other Income (Expense), Net (Tables)

6 Months Ended

Jun. 30, 2013

Other Income and Expenses [Abstract]

Other Income (Expense), Net

Other income (expense), net consisted of the following:

	Three Months Ended June 30						Six Months Ended June 30
(Thousands of Dollars)	2013			2012			2013			2012
Interest income (expense)	$	197		$	(25	)	$	396		$	632
Other nonoperating income	29			46			70			39
Insurance policy expense	(69		)	(61		)	(191		)	(211		)
Other nonoperating expense	(2		)	—			(5		)	—
Other income (expense), net	$	155		$	(40	)	$	270		$	460

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Fair Value of Financial Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2013

Fair Value Disclosures [Abstract]

Gross Notional Amounts of Commodity Forwards and Options

The following table details the gross notional amounts of commodity forwards and options at June 30, 2013 and Dec. 31, 2012:

(Amounts in Thousands)(a)(b)	June 30, 2013	Dec. 31, 2012
Million British thermal units (MMBtu) of natural gas	377	53

^(a)  Amounts are not reflective of net positions in the underlying commodities.

^(b)  Notional amounts for options are included on a gross basis, but are weighted for the probability of exercise.

Financial Impact of Qualifying Cash Flow Hedges on Accumulated Other Comprehensive Loss

Financial Impact of Qualifying Cash Flow Hedges — The impact of qualifying interest rate cash flow hedges on NSP-Wisconsin’s accumulated other comprehensive loss, included as a component of common stockholder’s equity and in the consolidated statement of comprehensive income, is detailed in the following table: 

	Three Months Ended June 30
(Thousands of Dollars)	2013			2012
Accumulated other comprehensive loss related to cash flow hedges at April 1	$	(418	)	$	(495	)
After-tax net realized losses on derivative transactions reclassified into earnings	18			19
Accumulated other comprehensive loss related to cash flow hedges at June 30	$	(400	)	$	(476	)

	Six Months Ended June 30
(Thousands of Dollars)	2013			2012
Accumulated other comprehensive loss related to cash flow hedges at Jan. 1	$	(437	)	$	(514	)
After-tax net realized losses on derivative transactions reclassified into earnings	37			38
Accumulated other comprehensive loss related to cash flow hedges at June 30	$	(400	)	$	(476	)

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, NSP-Wisconsin’s derivative assets measured at fair value on a recurring basis at June 30, 2013 and Dec. 31, 2012:

	June 30, 2013
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting(a)		Total(b)
Current derivative assets
Natural gas commodity	$	—	$	191	$	—	$	191	$	—	$	191

	Dec. 31, 2012
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting(a)		Total(c)
Current derivative liabilities
Natural gas commodity	$	—	$	11	$	—	$	11	$	—	$	11

^(a)  NSP-Wisconsin nets derivative instruments and related collateral in its consolidated 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 June 30, 2013 and Dec. 31, 2012.  The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

^(b)  Included in other current assets balance of $2.3 million at June 30, 2013 in the consolidated balance sheets.

^(c)  Included in other current liabilities balance of $11.8 million at Dec. 31, 2012 in the consolidated balance sheets.

Carrying Amount and Fair Value of Long-term Debt

As of June 30, 2013 and Dec. 31, 2012, other financial instruments for which the carrying amount did not equal fair value were as follows:

	June 30, 2013				Dec. 31, 2012
(Thousands of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	468,597	$	531,979	$	468,563	$	576,353

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Fair Value of Financial Assets and Liabilities, Financial Impact of Qualifying Cash Flow Hedges (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Financial Impact of Qualifying Cash Flow Hedges on Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Accumulated other comprehensive loss related to cash flow hedges at beginning of period	$ (418,000)	$ (495,000)	$ (437,000)	$ (514,000)
After-tax net realized losses on derivative transactions reclassified into earnings	18,000	19,000	37,000	38,000
Accumulated other comprehensive loss related to cash flow hedges at end of period	(400,000)	(476,000)	(400,000)	(476,000)
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)				2,900,000
Natural Gas Commodity Contract [Member] | Cash Flow Hedging Other [Member]
Financial Impact of Qualifying Cash Flow Hedges on Accumulated Other Comprehensive Income (Loss) [Roll Forward]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities	$ 200,000		$ 200,000	$ 400,000

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Income Taxes (Details) (USD $)			3 Months Ended	6 Months Ended	3 Months Ended	6 Months Ended
	Jun. 30, 2013	Dec. 31, 2012	Sep. 30, 2012 Internal Revenue Service (IRS)	Jun. 30, 2013 Internal Revenue Service (IRS)	Mar. 31, 2013 State Jurisdiction (Wisconsin)	Jun. 30, 2013 State Jurisdiction (Wisconsin)
Tax Audits [Abstract]
Year(s) no longer subject to audit as statute of limitations has expired				2008
Earliest year subject to examination				2009		2008
Year(s) under examination			2010 and 2011		2009 through 2011
Unrecognized Tax Benefits [Abstract]
Unrecognized tax benefit — Permanent tax positions	$ 100,000	$ 100,000
Unrecognized tax benefit — Temporary tax positions	1,300,000	1,200,000
Total unrecognized tax benefit	1,400,000	1,300,000
NOL and tax credit carryforwards	(900,000)	(900,000)
Upper bound of decrease in unrecognized tax benefit that is reasonably possible	(1,000,000)
Amounts accrued for penalties related to unrecognized tax benefits	$ 0	$ 0

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Borrowings and Other Financing Instruments, Commercial Paper (Details) (USD $)	3 Months Ended	12 Months Ended
	Jun. 30, 2013	Dec. 31, 2012
Short-term Debt [Line Items]
Amount outstanding at period end	$ 2,000,000	$ 39,000,000
Commercial Paper
Short-term Debt [Line Items]
Borrowing limit	150,000,000	150,000,000
Amount outstanding at period end	2,000,000	39,000,000
Average amount outstanding	11,000,000	61,000,000
Maximum amount outstanding	$ 27,000,000	$ 116,000,000
Weighted average interest rate, computed on a daily basis (in hundredths)	0.27%	0.39%
Weighted average interest rate at end of period (in hundredths)	0.22%	0.40%

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Other Income (Expense), Net (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Other Income and Expenses [Abstract]
Interest income (expense)	$ 197	$ (25)	$ 396	$ 632
Other nonoperating income	29	46	70	39
Insurance policy expense	(69)	(61)	(191)	(211)
Other nonoperating expense	(2)	0	(5)	0
Other income (expense), net	$ 155	$ (40)	$ 270	$ 460

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Selected Balance Sheet Data, Accounts Receivable (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Accounts Receivable, Net
Accounts receivable	$ 53,700	$ 55,039
Less allowance for bad debts	(4,116)	(4,333)
Accounts receivable, net	$ 49,584	$ 50,706

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Borrowings and Other Financing Instruments, Intercompany Borrowing Arrangement and Other Short-Term Borrowings (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Short-term Debt [Line Items]
Notes payable to affiliates	$ 470	$ 550
Intercompany Borrowing Arrangement
Short-term Debt [Line Items]
Notes payable to affiliates	$ 500	$ 600
Weighted average interest rate at end of period (in hundredths)	0.27%	0.33%

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Borrowings and Other Financing Instruments (Tables)

6 Months Ended

Jun. 30, 2013

Debt Instruments [Abstract]

Committed Credit Facility Available

At June 30, 2013, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility (a)		Drawn(b)		Available
$	150.0	$	2.0	$	148.0

^(a)  Credit facility expires in July 2017.

^(b)  Includes outstanding commercial paper.

Commercial Paper

Debt Instruments [Abstract]

Short-Term Borrowings

Commercial Paper — NSP-Wisconsin meets its short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under its credit facility.  Commercial paper outstanding for NSP-Wisconsin was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2013			Twelve Months Ended Dec. 31, 2012
Borrowing limit	$	150		$	150
Amount outstanding at period end	2			39
Average amount outstanding	11			61
Maximum amount outstanding	27			116
Weighted average interest rate, computed on a daily basis	0.27		%	0.39		%
Weighted average interest rate at period end	0.22			0.40

Intercompany Borrowing Arrangement

Debt Instruments [Abstract]

Short-Term Borrowings

Other Short-Term Borrowings— The following table presents the notes payable of Clearwater Investments, Inc., a NSP-Wisconsin subsidiary, to Xcel Energy Inc.:

(Amounts in Millions, Except Interest Rates)	June 30, 2013			Dec. 31, 2012
Notes payable to affiliates	$	0.5		$	0.6
Weighted average interest rate	0.27		%	0.33		%

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CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Operating activities
Net income	$ 30,229	$ 20,620
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	38,476	34,680
Deferred income taxes	15,407	14,638
Amortization of investment tax credits	(332)	(312)
Allowance for equity funds used during construction	(1,726)	(1,764)
Net derivative (gains) losses	(344)	63
Changes in operating assets and liabilities:
Accounts receivable	1,134	(9,458)
Accrued unbilled revenues	9,928	9,625
Inventories	1,913	7,696
Other current assets	3,442	(712)
Accounts payable	(5,435)	1,860
Net regulatory assets and liabilities	(806)	4,479
Other current liabilities	1,670	588
Pension and other employee benefit obligations	(10,234)	(11,730)
Change in other noncurrent assets	329	(228)
Change in other noncurrent liabilities	630	582
Net cash provided by operating activities	84,281	70,627
Investing activities
Utility capital/construction expenditures	(81,603)	(72,230)
Allowance for equity funds used during construction	1,726	1,764
Other, net	(230)	1,105
Net cash used in investing activities	(80,107)	(69,361)
Financing activities
(Repayments of) proceeds from short-term borrowings, net	(37,000)	13,000
(Repayments of) proceeds from notes payable to affiliate	(80)	50
Repayments of long-term debt	(92)	(32)
Capital contributions from parent	45,093	2,162
Dividends paid to parent	(15,186)	(16,225)
Net cash used in financing activities	(7,265)	(1,045)
Net change in cash and cash equivalents	(3,091)	221
Cash and cash equivalents at beginning of period	4,459	1,571
Cash and cash equivalents at end of period	1,368	1,792
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(12,122)	(11,302)
Cash received (paid) for income taxes, net	39	(706)
Supplemental disclosure of non-cash investing transactions:
Property, plant and equipment additions in accounts payable	$ 9,134	$ 5,748

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) (USD $)	Jun. 30, 2013	Dec. 31, 2012
Capitalization
Common stock, shares authorized (in shares)	1,000,000	1,000,000
Common stock, par value (in dollars per share)	$ 100	$ 100
Common stock, shares outstanding (in shares)	933,000	933,000

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Accounting Pronouncements

6 Months Ended

Jun. 30, 2013

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Accounting Pronouncements

Accounting Pronouncements

Recently Adopted

Balance Sheet Offsetting — In December 2011, the Financial Accounting Standards Board (FASB) issued Balance Sheet (Topic 210) — Disclosures about Offsetting Assets and Liabilities (Accounting Standards Update (ASU) No. 2011-11), which requires disclosures regarding netting arrangements in agreements underlying derivatives, certain financial instruments and related collateral amounts, and the extent to which an entity’s financial statement presentation policies related to netting arrangements impact amounts recorded to the financial statements.  In January 2013, the FASB issued Balance Sheet (Topic 210) – Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities (ASU No. 2013-01) to clarify the specific instruments that should be considered in these disclosures.  These disclosure requirements do not affect the presentation of amounts in the consolidated balance sheets, and were effective for annual reporting periods beginning on or after Jan. 1, 2013, and interim periods within those annual reporting periods.  NSP-Wisconsin implemented the disclosure guidance effective Jan. 1, 2013, and the implementation did not have a material impact on its consolidated financial statements.  See Note 8 for the required disclosures.

Comprehensive Income Disclosures — In February 2013, the FASB issued Comprehensive Income (Topic 220)  — Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income (ASU No. 2013-02), which requires detailed disclosures regarding changes in components of accumulated other comprehensive income and amounts reclassified out of accumulated other comprehensive income.  These disclosure requirements do not change how net income or comprehensive income are presented in the consolidated financial statements.  These disclosure requirements were effective for annual reporting periods beginning on or after Dec. 15, 2012, and interim periods within those annual reporting periods.  NSP-Wisconsin implemented the disclosure guidance effective Jan. 1, 2013, and the implementation did not have a material impact on its consolidated financial statements.  See Note 12 for the required disclosures.

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Management's Opinion

6 Months Ended

Jun. 30, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Management's Opinion

In the opinion of management, the accompanying unaudited consolidated 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 NSP-Wisconsin and its subsidiaries as of June 30, 2013 and Dec. 31, 2012; the results of its operations, including the components of net income and comprehensive income, for the three and six months ended June 30, 2013 and 2012; and its cash flows for the six months ended June 30, 2013 and 2012.  All adjustments are of a normal, recurring nature, except as otherwise disclosed.  Management has also evaluated the impact of events occurring after June 30, 2013 up to the date of issuance of these consolidated financial statements.  These statements contain all necessary adjustments and disclosures resulting from that evaluation.  The Dec. 31, 2012 balance sheet information has been derived from the audited 2012 consolidated financial statements included in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012.  These notes to the consolidated 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 consolidated financial statements and notes thereto, included in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2012, filed with the SEC on Feb. 25, 2013.  Due to the seasonality of NSP-Wisconsin’s electric and natural gas sales, interim results are not necessarily an appropriate base from which to project annual results.

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Borrowings and Other Financing Instruments, Letters of Credit (Details) (USD $)	6 Months Ended
	Jun. 30, 2013	Dec. 31, 2012
Letters of Credit [Abstract]
Terms of letters of credit (in years)	1 year
Letters of credit outstanding under credit facilities	$ 0	$ 0

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2013

Segment Reporting [Abstract]

Results from Continuing Operations by Reportable Segment

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2013
Operating revenues	$	185,374	$	24,555	$	246	$	—		$	210,175
Intersegment revenues	83		278		—		(361		)	—
Total revenues	$	185,457	$	24,833	$	246	$	(361	)	$	210,175
Net income	$	10,068	$	201	$	275	$	—		$	10,544

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2012
Operating revenues	$	179,105	$	14,830		$	238	$	—		$	194,173
Intersegment revenues	109		61			—		(170		)	—
Total revenues	$	179,214	$	14,891		$	238	$	(170	)	$	194,173
Net income (loss)	$	6,127	$	(947	)	$	562	$	—		$	5,742

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2013
Operating revenues	$	376,185	$	74,912	$	493	$	—		$	451,590
Intersegment revenues	161		586		—		(747		)	—
Total revenues	$	376,346	$	75,498	$	493	$	(747	)	$	451,590
Net income	$	23,671	$	5,825	$	733	$	—		$	30,229

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2012
Operating revenues	$	361,106	$	56,322	$	544	$	—		$	417,972
Intersegment revenues	196		264		—		(460		)	—
Total revenues	$	361,302	$	56,586	$	544	$	(460	)	$	417,972
Net income	$	17,375	$	2,453	$	792	$	—		$	20,620

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Selected Balance Sheet Data, Inventory (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Public Utilities, Inventory [Line Items]
Inventories	$ 17,773	$ 19,685
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	6,541	6,172
Fuel
Public Utilities, Inventory [Line Items]
Inventories	7,268	6,664
Natural gas
Public Utilities, Inventory [Line Items]
Inventories	$ 3,964	$ 6,849

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Commitments and Contingencies, Environmental Contingencies - Site Contingencies (Details) (USD $)	6 Months Ended
	Jun. 30, 2013 Site	Dec. 31, 2012
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Liability for estimated cost of remediating sites, current	$ 17,561,000	$ 23,427,000
Ashland MGP Site
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Number of properties included in superfund site which NSP-Wisconsin does not own	2
Liability for estimated cost of remediating sites	101,300,000	103,700,000
Liability for estimated cost of remediating sites, current	14,300,000	20,100,000
Amortization period for recovery of remediation costs in natural gas rates, low end of range (in years)	4 years
Amortization period for recovery of remediation costs in natural gas rates, high end of range (in years)	6 years
Ashland MGP Site - Phase I Project Area
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Liability for estimated cost of remediating sites	40,000,000
Number of acres of land conveyed to the State of Wisconsin and tribal trustees (in acres)	1,390
Approved amortization period for recovery of remediation costs in natural gas rates (in years)	10 years
Carrying cost percentage to be applied to the unamortized regulatory asset for MGP remediation (in hundredths)	3.00%
Ashland MGP Site - Sediments
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Estimated cost of remediating site, low end of range	63,000,000
Estimated cost of remediating site, high end of range	$ 77,000,000
Potential percent of increase to the high end of the range of estimated site remediation costs (in hundredths)	50.00%
Potential percent of decrease to the low end of the range of estimated site remediation costs (in hundredths)	30.00%

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Segment Reporting Information [Line Items]
Operating revenues	$ 210,175	$ 194,173	$ 451,590	$ 417,972
Net income	10,544	5,742	30,229	20,620
Regulated Electric
Segment Reporting Information [Line Items]
Operating revenues	185,374	179,105	376,185	361,106
Net income	10,068	6,127	23,671	17,375
Regulated Natural Gas
Segment Reporting Information [Line Items]
Operating revenues	24,555	14,830	74,912	56,322
Net income	201	(947)	5,825	2,453
All Other
Segment Reporting Information [Line Items]
Operating revenues	246	238	493	544
Net income	275	562	733	792
Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	210,175	194,173	451,590	417,972
Operating Segments | Regulated Electric
Segment Reporting Information [Line Items]
Operating revenues	185,457	179,214	376,346	361,302
Operating Segments | Regulated Natural Gas
Segment Reporting Information [Line Items]
Operating revenues	24,833	14,891	75,498	56,586
Operating Segments | All Other
Segment Reporting Information [Line Items]
Operating revenues	246	238	493	544
Intersegment Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(361)	(170)	(747)	(460)
Intersegment Eliminations | Regulated Electric
Segment Reporting Information [Line Items]
Operating revenues	83	109	161	196
Intersegment Eliminations | Regulated Natural Gas
Segment Reporting Information [Line Items]
Operating revenues	278	61	586	264
Intersegment Eliminations | All Other
Segment Reporting Information [Line Items]
Operating revenues	$ 0	$ 0	$ 0	$ 0

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Fair Value of Financial Assets and Liabilities, Impact of Derivative Activity (Details) (Other Derivative Instruments [Member], Natural Gas Commodity Contract [Member])	Jun. 30, 2013 MMBTU		Dec. 31, 2012 MMBTU
Other Derivative Instruments [Member] | Natural Gas Commodity Contract [Member]
Gross Notional Amounts of Commodity Forwards and Options [Abstract]
Notional amount	377,000	[1],[2]	53,000	[1],[2]

[1] Notional amounts for options are included on a gross basis, but are weighted for the probability of exercise.

[2] Amounts are not reflective of net positions in the underlying commodities.

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CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Interest charges and financing costs
Other financing costs	$ 380	$ 384	$ 761	$ 810

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Rate Matters (Notes)

6 Months Ended

Jun. 30, 2013

Public Utilities, General Disclosures [Abstract]

Rate Matters

Rate Matters

Except to the extent noted below, the circumstances set forth in Note 10 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2012 appropriately represent, in all material respects, the current status of other rate matters, and are incorporated herein by reference.

Pending Regulatory Proceedings — Public Service Commission of Wisconsin (PSCW)

Base Rate

NSP-Wisconsin – Wisconsin 2014 Electric and Gas Rate Case—On May 31, 2013, NSP-Wisconsin filed a request with the PSCW to increase rates for electric and natural gas service effective Jan. 1, 2014. NSP-Wisconsin requested an overall increase in annual electric rates of $40.0 million, or 6.5 percent, and an increase in natural gas rates of $4.7 million, or 3.8 percent.

The rate filing is based on a 2014 forecast test year, a return on equity (ROE) of 10.4 percent, an equity ratio of 52.5 percent, and a forecasted average net investment rate base of approximately $895.3 million for the electric utility and $89.8 million for the natural gas utility.

Next steps in the procedural schedule are expected to be as follows:

• Staff and Intervenor Direct Testimony – Oct. 4, 2013

• Rebuttal Testimony – Oct. 18, 2013

• Surrebuttal testimony – Oct. 28, 2013

• Hearing – Oct. 30, 2013

• Initial Brief – Nov. 13, 2013

• Reply Brief – Nov. 20, 2013

A PSCW decision is anticipated in December 2013, with final rates going into effect in January 2014.

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Derivative instruments:
Reclassification of losses to net income, net of tax	$ 14	$ 12	$ 26	$ 25

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CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Operating revenues
Electric	$ 185,374	$ 179,105	$ 376,185	$ 361,106
Natural gas	24,555	14,830	74,912	56,322
Other	246	238	493	544
Total operating revenues	210,175	194,173	451,590	417,972
Operating expenses
Electric fuel and purchased power, non-affiliates	1,862	4,467	6,032	7,914
Purchased power, affiliates	100,043	98,813	198,985	197,980
Cost of natural gas sold and transported	14,302	7,123	45,287	34,002
Operating and maintenance expenses	42,992	42,492	84,668	80,992
Conservation program expenses	3,118	3,620	6,110	7,122
Depreciation and amortization	19,051	17,093	37,906	34,102
Taxes (other than income taxes)	6,341	6,217	12,735	12,598
Total operating expenses	187,709	179,825	391,723	374,710
Operating income	22,466	14,348	59,867	43,262
Other income (expense), net	155	(40)	270	460
Allowance for funds used during construction — equity	780	765	1,726	1,764
Interest charges and financing costs
Interest charges — includes other financing costs of $380, $384, $761 and $810, respectively	6,814	6,044	13,669	12,059
Allowance for funds used during construction — debt	(400)	(139)	(809)	(225)
Total interest charges and financing costs	6,414	5,905	12,860	11,834
Income before income taxes	16,987	9,168	49,003	33,652
Income taxes	6,443	3,426	18,774	13,032
Net income	$ 10,544	$ 5,742	$ 30,229	$ 20,620

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Benefit Plans and Other Postretirement Benefits (Details) (USD $)	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2013	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Pension Benefits
Components of Net Periodic Benefit Cost [Abstract]
Service cost		$ 1,420,000	$ 1,150,000	$ 2,841,000	$ 2,284,000
Interest cost		1,731,000	1,925,000	3,462,000	3,835,000
Expected return on plan assets		(2,498,000)	(2,634,000)	(4,997,000)	(5,245,000)
Amortization of transition obligation		0	0	0	0
Amortization of prior service cost (credit)		104,000	443,000	208,000	886,000
Amortization of net loss		1,981,000	1,487,000	3,962,000	2,922,000
Net benefit cost recognized for financial reporting		2,738,000	2,371,000	5,476,000	4,682,000
Total contributions to Xcel Energy's pension plans during the period	11,300,000
Postretirement Health Care Benefits
Components of Net Periodic Benefit Cost [Abstract]
Service cost		6,000	5,000	12,000	10,000
Interest cost		190,000	274,000	380,000	538,000
Expected return on plan assets		(10,000)	(12,000)	(21,000)	(25,000)
Amortization of transition obligation		0	43,000	0	86,000
Amortization of prior service cost (credit)		(88,000)	(3,000)	(176,000)	(7,000)
Amortization of net loss		241,000	128,000	482,000	242,000
Net benefit cost recognized for financial reporting		339,000	435,000	677,000	844,000
Xcel Energy Inc. | Pension Benefits
Components of Net Periodic Benefit Cost [Abstract]
Total contributions to Xcel Energy's pension plans during the period	$ 191,500,000
Number of Xcel Energy's pension plans to which contributions were made	4

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Benefit Plans and Other Postretirement Benefits (Tables)

6 Months Ended

Jun. 30, 2013

Compensation and Retirement Disclosure [Abstract]

Components of Net Periodic Benefit Cost

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2013			2012			2013			2012
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	1,420		$	1,150		$	6		$	5
Interest cost	1,731			1,925			190			274
Expected return on plan assets	(2,498		)	(2,634		)	(10		)	(12		)
Amortization of transition obligation	—			—			—			43
Amortization of prior service cost (credit)	104			443			(88		)	(3		)
Amortization of net loss	1,981			1,487			241			128
Net benefit cost recognized for financial reporting	$	2,738		$	2,371		$	339		$	435

	Six Months Ended June 30
	2013			2012			2013			2012
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	2,841		$	2,284		$	12		$	10
Interest cost	3,462			3,835			380			538
Expected return on plan assets	(4,997		)	(5,245		)	(21		)	(25		)
Amortization of transition obligation	—			—			—			86
Amortization of prior service cost (credit)	208			886			(176		)	(7		)
Amortization of net loss	3,962			2,922			482			242
Net benefit cost recognized for financial reporting	$	5,476		$	4,682		$	677		$	844

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2013

Income Tax Disclosure [Abstract]

Reconciliation of Unrecognized Tax Benefits

A reconciliation of the amount of unrecognized tax benefit is as follows:

(Millions of Dollars)	June 30, 2013		Dec. 31, 2012
Unrecognized tax benefit — Permanent tax positions	$	0.1	$	0.1
Unrecognized tax benefit — Temporary tax positions	1.3		1.2
Total unrecognized tax benefit	$	1.4	$	1.3

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)	June 30, 2013			Dec. 31, 2012
NOL and tax credit carryforwards	$	(0.9	)	$	(0.9	)

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Fair Value of Financial Assets and Liabilities, Derivative Instruments (Details) (Interest Rate Swap [Member], USD $) In Millions, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
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	$ 0.1
Amount of accumulated other comprehensive losses related to interest rate derivatives expected to be reclassified into earnings	$ 0.1	$ 0.1

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Commitments and Contingencies, Legal Contingencies (Details) (USD $)	Jun. 30, 2013 Native Village of Kivalina vs. Xcel Energy Inc. et al. [Member]	Feb. 29, 2008 Native Village of Kivalina vs. Xcel Energy Inc. et al. [Member] Counterparty	Jun. 30, 2013 Comer vs. Xcel Energy Inc. et al. [Member]	May 31, 2011 Comer vs. Xcel Energy Inc. et al. [Member] Counterparty
Legal Contingencies [Abstract]
Number of other entities against which the native village of Kivalina has filed a lawsuit		23
Accrual for legal contingency	$ 0		$ 0
Minimum number of utility, oil, chemical and coal companies against which a lawsuit was filed in U.S. District Court in Mississippi				85

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Rate Matters (Details) (Public Service Commission of Wisconsin (PSCW) [Member], NSP-Wisconsin [Member], USD $) In Millions, unless otherwise specified	1 Months Ended
	May 31, 2013
Electric and Gas Rate Case 2014, Electric Rates [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 40.0
Public Utilities, Requested Rate Increase (Decrease), Percentage	6.50%
Electric and Gas Rate Case 2014, Gas Rates [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	4.7
Public Utilities, Requested Rate Increase (Decrease), Percentage	3.80%
Electric and Gas Rate Case 2014 [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage	10.40%
Public Utilities, Requested Equity Capital Structure, Percentage	52.50%
Forecasted Average Net Investment Rate Base, Electric Utility	895.3
Forecasted Average Net Investment Rate Base, Natural Gas Utility	$ 89.8

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Commitments and Contingencies, Guarantees and Indemnifications (Details) (Payment or Performance Guarantee, Customer Loans for Farm Rewiring Program, USD $) In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Payment or Performance Guarantee | Customer Loans for Farm Rewiring Program
Guarantees [Abstract]
Guarantee issued and outstanding	$ 1.0	$ 1.0
Current exposure under the guarantee	$ 0.4	$ 0.4

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Income Taxes

6 Months Ended

Jun. 30, 2013

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

Except to the extent noted below, the circumstances set forth in Note 6 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2012 appropriately represent, in all material respects, the current status of other income tax matters, and are incorporated herein by reference.

Federal Audit— NSP-Wisconsin 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.  As of June 30, 2013, the IRS had not proposed any material adjustments to tax years 2010 and 2011.

State Audits— NSP-Wisconsin is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of June 30, 2013, NSP-Wisconsin’s earliest open tax year that is subject to examination by state taxing authorities under applicable statutes of limitations is 2008.  In the first quarter of 2013, the state of Wisconsin commenced an examination of tax years 2009 through 2011.  As of June 30, 2013, no material adjustments had been proposed for these years.  There are currently no other 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)	June 30, 2013		Dec. 31, 2012
Unrecognized tax benefit — Permanent tax positions	$	0.1	$	0.1
Unrecognized tax benefit — Temporary tax positions	1.3		1.2
Total unrecognized tax benefit	$	1.4	$	1.3

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)	June 30, 2013			Dec. 31, 2012
NOL and tax credit carryforwards	$	(0.9	)	$	(0.9	)

It is reasonably possible that NSP-Wisconsin’s amount of unrecognized tax benefits could significantly change in the next 12 months as the IRS and state audits progress.  As the IRS examination moves closer to completion, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $1 million.

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 June 30, 2013 and Dec. 31, 2012 were not material.  No amounts were accrued for penalties related to unrecognized tax benefits as of June 30, 2013 or Dec. 31, 2012.

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Other Comprehensive Income (Tables)

6 Months Ended

Jun. 30, 2013

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 and six months ended June 30, 2013 were as follows:

(Thousands of Dollars)	Gains and Losses on Cash Flow Hedges
Accumulated other comprehensive loss at April 1	$	(418	)
Losses reclassified from net accumulated other comprehensive loss	18
Net current period other comprehensive income	18
Accumulated other comprehensive loss at June 30	$	(400	)

(Thousands of Dollars)	Gains and Losses on Cash Flow Hedges
Accumulated other comprehensive loss at Jan. 1	$	(437	)
Losses reclassified from net accumulated other comprehensive loss	37
Net current period other comprehensive income	37
Accumulated other comprehensive loss at June 30	$	(400	)

Reclassification out of Accumulated Other Comprehensive Loss

Reclassifications from accumulated other comprehensive loss for the three and six months ended June 30, 2013 were as follows:

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Three Months Ended June 30, 2013				Six Months Ended June 30, 2013
Losses on cash flow hedges:
Interest rate derivatives	$	32		(a)	$	63		(a)
Total, pre-tax	32				63
Tax benefit	(14		)		(26		)
Total amounts reclassified, net of tax	$	18			$	37

^(a)  Included in interest charges.

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Borrowings and Other Financing Instruments, Credit Facility (Details) (USD $)	Jun. 30, 2013		Dec. 31, 2012
Credit Facility [Abstract]
Credit facility	$ 150,000,000	[1]
Drawn	2,000,000	[2]
Available	148,000,000
Credit facility bank borrowings outstanding	$ 0		$ 0

[1] Credit facility expires in July 2017.

[2] Includes outstanding commercial paper.

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Borrowings and Other Financing Instruments

6 Months Ended

Jun. 30, 2013

Debt Disclosure [Abstract]

Borrowings and Other Financing Instruments

Borrowings and Other Financing Instruments

Commercial Paper — NSP-Wisconsin meets its short-term liquidity requirements primarily through the issuance of commercial paper and borrowings under its credit facility.  Commercial paper outstanding for NSP-Wisconsin was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2013			Twelve Months Ended Dec. 31, 2012
Borrowing limit	$	150		$	150
Amount outstanding at period end	2			39
Average amount outstanding	11			61
Maximum amount outstanding	27			116
Weighted average interest rate, computed on a daily basis	0.27		%	0.39		%
Weighted average interest rate at period end	0.22			0.40

Letters of Credit— NSP-Wisconsin may use letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations.  At June 30, 2013 and Dec. 31, 2012, there were no letters of credit outstanding.

Credit Facility — In order to use its commercial paper program to fulfill short-term funding needs, NSP-Wisconsin 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 June 30, 2013, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility (a)		Drawn(b)		Available
$	150.0	$	2.0	$	148.0

^(a)  Credit facility expires in July 2017.

^(b)  Includes outstanding commercial paper.

All credit facility bank borrowings, outstanding letters of credit and outstanding commercial paper reduce the available capacity under the credit facility.  NSP-Wisconsin had no direct advances on the credit facility outstanding at June 30, 2013 and Dec. 31, 2012.

Other Short-Term Borrowings— The following table presents the notes payable of Clearwater Investments, Inc., a NSP-Wisconsin subsidiary, to Xcel Energy Inc.:

(Amounts in Millions, Except Interest Rates)	June 30, 2013			Dec. 31, 2012
Notes payable to affiliates	$	0.5		$	0.6
Weighted average interest rate	0.27		%	0.33		%

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Selected Balance Sheet Data

6 Months Ended

Jun. 30, 2013

Balance Sheet Related Disclosures [Abstract]

Selected Balance Sheet Data

Selected Balance Sheet Data

(Thousands of Dollars)	June 30, 2013			Dec. 31, 2012
Accounts receivable, net
Accounts receivable	$	53,700		$	55,039
Less allowance for bad debts	(4,116		)	(4,333		)
	$	49,584		$	50,706

(Thousands of Dollars)	June 30, 2013		Dec. 31, 2012
Inventories
Materials and supplies	$	6,541	$	6,172
Fuel	7,268		6,664
Natural gas	3,964		6,849
	$	17,773	$	19,685

(Thousands of Dollars)	June 30, 2013			Dec. 31, 2012
Property, plant and equipment, net
Electric plant	$	1,848,303		$	1,795,239
Natural gas plant	227,790			224,625
Common and other property	112,043			111,319
Construction work in progress	77,144			62,629
Total property, plant and equipment	2,265,280			2,193,812
Less accumulated depreciation	(921,567		)	(895,576		)
	$	1,343,713		$	1,298,236

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Current assets
Cash and cash equivalents	$ 1,368	$ 4,459
Accounts receivable, net	49,584	50,706
Accrued unbilled revenues	39,210	49,138
Inventories	17,773	19,685
Regulatory assets	15,197	12,048
Prepaid taxes	22,490	24,688
Deferred income taxes	2,445	0
Prepayments and other	2,251	4,394
Total current assets	150,318	165,118
Property, plant and equipment, net	1,343,713	1,298,236
Other assets
Regulatory assets	236,085	240,459
Other investments	3,461	3,232
Other	3,662	4,040
Total other assets	243,208	247,731
Total assets	1,737,239	1,711,085
Current liabilities
Current portion of long-term debt	103	1,246
Short-term debt	2,000	39,000
Notes payable to affiliates	470	550
Accounts payable	26,838	30,723
Accounts payable to affiliates	29,461	31,556
Dividends payable to parent	7,757	7,667
Regulatory liabilities	7,718	6,086
Environmental liabilities	17,561	23,427
Accrued interest	7,470	7,304
Other	11,577	11,794
Total current liabilities	110,955	159,353
Deferred credits and other liabilities
Deferred income taxes	280,604	261,800
Deferred investment tax credits	9,294	8,911
Regulatory liabilities	125,016	123,746
Environmental liabilities	87,170	84,655
Customer advances	16,449	15,631
Pension and employee benefit obligations	53,394	63,643
Other	8,672	8,923
Total deferred credits and other liabilities	580,599	567,309
Commitments and contingencies
Capitalization
Long-term debt	468,494	467,317
Common stock — 1,000,000 shares authorized of $100 par value; 933,000 shares outstanding at June 30, 2013 and Dec. 31, 2012, respectively	93,300	93,300
Additional paid in capital	234,961	189,867
Retained earnings	249,330	234,376
Accumulated other comprehensive loss	(400)	(437)
Total common stockholder’s equity	577,191	517,106
Total liabilities and equity	$ 1,737,239	$ 1,711,085

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Other Comprehensive Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended			6 Months Ended
	Jun. 30, 2013		Jun. 30, 2012	Jun. 30, 2013		Jun. 30, 2012
Accumulated Other Comprehensive Income [Roll Forward]
Accumulated other comprehensive loss at beginning of period				$ (437)
Accumulated other comprehensive loss at end of period	(400)			(400)
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest charges	6,814		6,044	13,669		12,059
Total, pre-tax	(16,987)		(9,168)	(49,003)		(33,652)
Tax benefit	6,443		3,426	18,774		13,032
Gains and Losses on Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income [Roll Forward]
Accumulated other comprehensive loss at beginning of period	(418)			(437)
(Gains) losses reclassified from net accumulated other comprehensive loss	18			37
Net current period other comprehensive income (loss)	18			37
Accumulated other comprehensive loss at end of period	(400)			(400)
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	32			63
Tax benefit	(14)			(26)
Total, net of tax	18			37
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 charges	$ 32	[1]		$ 63	[1]

[1] Included in interest charges.

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Fair Value of Financial Assets and Liabilities, Derivative Assets and Liabilities at Fair Value (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013		Dec. 31, 2012
Current derivative liabilities [Abstract]
Prepayments and other	$ 2,251		$ 4,394
Other current liabilities	11,577		11,794
Fair Value Measured on a Recurring Basis [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Natural gas commodity	191	[1]
Current derivative liabilities [Abstract]
Natural gas commodity	0		11	[2]
Fair Value Measured on a Recurring Basis [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Natural gas commodity	0
Current derivative liabilities [Abstract]
Natural gas commodity	0		0
Fair Value Measured on a Recurring Basis [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Natural gas commodity	191
Current derivative liabilities [Abstract]
Natural gas commodity	0		11
Fair Value Measured on a Recurring Basis [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Natural gas commodity	0
Current derivative liabilities [Abstract]
Natural gas commodity	0		0
Fair Value Measured on a Recurring Basis [Member] | Fair Value Total [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Natural gas commodity	191
Current derivative liabilities [Abstract]
Natural gas commodity	0		11
Prepayments and other	2,300
Other current liabilities			11,800
Fair Value Measured on a Recurring Basis [Member] | Counterparty Netting [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Natural gas commodity	0
Current derivative liabilities [Abstract]
Natural gas commodity	$ 0		$ 0	[3]

[1] Included in other current assets balance of $2.3 million at June 30, 2013 in the consolidated balance sheets.

[2] Included in other current liabilities balance of $11.8 million at Dec. 31, 2012 in the consolidated balance sheets.

[3] NSP-Wisconsin nets derivative instruments and related collateral in its consolidated 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 June 30, 2013 and Dec. 31, 2012. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.

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Selected Balance Sheet Data, Property, Plant and Equipment (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 2,265,280	$ 2,193,812
Less accumulated depreciation	(921,567)	(895,576)
Property, plant and equipment, net	1,343,713	1,298,236
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	1,848,303	1,795,239
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	227,790	224,625
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	112,043	111,319
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 77,144	$ 62,629

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Segment Information

6 Months Ended

Jun. 30, 2013

Segment Reporting [Abstract]

Segment Information

Segment Information

Operating results from the regulated electric utility and regulated natural gas utility are each separately and regularly reviewed by NSP-Wisconsin’s chief operating decision maker.  NSP-Wisconsin evaluates performance based on profit or loss generated from the product or service provided.  These segments are managed separately because the revenue streams are dependent upon regulated rate recovery, which is separately determined for each segment.

NSP-Wisconsin has the following reportable segments: regulated electric utility, regulated natural gas utility and all other.

• NSP-Wisconsin’s regulated electric utility segment generates electricity which is transmitted and distributed in Wisconsin and Michigan.  In addition, this segment includes sales for resale and provides wholesale transmission service to various entities primarily in Wisconsin.

• NSP-Wisconsin’s regulated natural gas utility segment purchases, transports, stores and distributes natural gas in portions of Wisconsin and Michigan.

• Revenues from operating segments not included above are below the necessary quantitative thresholds and are therefore included in the all other category.  Those primarily include investments in rental housing projects that qualify for low-income housing tax credits.

Asset and capital expenditure information is not provided for NSP-Wisconsin’s reportable segments because as an integrated electric and natural gas utility, NSP-Wisconsin operates significant assets that are not dedicated to a specific business segment, and reporting assets and capital expenditures by business segment would require arbitrary and potentially misleading allocations which may not necessarily reflect the assets that would be required for the operation of the business segments on a stand-alone basis.

To report income from continuing operations for regulated electric and regulated natural gas utility segments, the majority of costs are directly assigned to each segment.  However, some costs, such as common depreciation, common operating and maintenance (O&M) expenses and interest expense are allocated based on cost causation allocators.  A general allocator is used for certain general and administrative expenses, including office supplies, rent, property insurance and general advertising.

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2013
Operating revenues	$	185,374	$	24,555	$	246	$	—		$	210,175
Intersegment revenues	83		278		—		(361		)	—
Total revenues	$	185,457	$	24,833	$	246	$	(361	)	$	210,175
Net income	$	10,068	$	201	$	275	$	—		$	10,544

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2012
Operating revenues	$	179,105	$	14,830		$	238	$	—		$	194,173
Intersegment revenues	109		61			—		(170		)	—
Total revenues	$	179,214	$	14,891		$	238	$	(170	)	$	194,173
Net income (loss)	$	6,127	$	(947	)	$	562	$	—		$	5,742

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2013
Operating revenues	$	376,185	$	74,912	$	493	$	—		$	451,590
Intersegment revenues	161		586		—		(747		)	—
Total revenues	$	376,346	$	75,498	$	493	$	(747	)	$	451,590
Net income	$	23,671	$	5,825	$	733	$	—		$	30,229

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2012
Operating revenues	$	361,106	$	56,322	$	544	$	—		$	417,972
Intersegment revenues	196		264		—		(460		)	—
Total revenues	$	361,302	$	56,586	$	544	$	(460	)	$	417,972
Net income	$	17,375	$	2,453	$	792	$	—		$	20,620

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Except as noted below and in Note 5, the circumstances set forth in Notes 10 and 11 to the consolidated financial statements in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2012 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 NSP-Wisconsin’s financial position.

Guarantees — NSP-Wisconsin provides a guarantee for payment of customer loans related to NSP-Wisconsin’s farm rewiring program.  NSP-Wisconsin’s exposure under the guarantee is based upon the net liability under the agreement.  The guarantee issued by NSP-Wisconsin limits the exposure of NSP-Wisconsin to a maximum amount stated in the guarantee.  The guarantee contains no recourse provisions and requires no collateral.

The following table presents the guarantee issued and outstanding for NSP-Wisconsin:

(Millions of Dollars)	June 30, 2013		Dec. 31, 2012
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under the guarantee	0.4		0.4

Environmental Contingencies

Ashland Manufactured Gas Plant (MGP) Site — NSP-Wisconsin has been named a potentially responsible party (PRP) for contamination at a site in Ashland, Wis.  The Ashland/Northern States Power Lakefront Superfund Site (the Ashland site) includes property owned by NSP-Wisconsin, which was a site previously operated by a predecessor company as a MGP facility (the Upper Bluff), and two other properties: an adjacent city lakeshore park area (Kreher Park), on which an unaffiliated third party previously operated a sawmill and conducted creosote treating operations; and an area of Lake Superior’s Chequamegon Bay adjoining the park (the Sediments).

The U.S. Environmental Protection Agency (EPA) issued its Record of Decision (ROD) in 2010, which describes the preferred remedy the EPA has selected for the cleanup of the Ashland site.  In 2011, the EPA issued special notice letters identifying several entities, including NSP-Wisconsin, as PRPs, for future remediation at the site.  The special notice letters requested that those PRPs participate in negotiations with the EPA regarding how the PRPs intended to conduct or pay for the remediation at the Ashland site.  As a result of those settlement negotiations, the EPA agreed to segment the Ashland site into separate areas.  The first area (Phase I Project Area) includes soil and groundwater in Kreher Park and the Upper Bluff.  The second area includes the Sediments.

In October 2012, a settlement among the EPA, the Wisconsin Department of Natural Resources (WDNR), the Bad River and Red Cliff Bands of the Lake Superior Tribe of Chippewa Indians and NSP-Wisconsin was approved by the U.S. District Court for the Western District of Wisconsin.  This settlement resolves claims against NSP-Wisconsin for its alleged responsibility for the remediation of the Phase I Project Area.  Under the terms of the settlement, NSP-Wisconsin agreed to perform the remediation of the Phase I Project Area, but does not admit any liability with respect to the Ashland site.  The settlement reflects a cost estimate for the clean up of the Phase I Project Area of $40 million.  The settlement also resolves claims by the federal, state and tribal trustees against NSP-Wisconsin for alleged natural resource damages at the Ashland site, including both the Phase I Project Area and the Sediments.  As part of the settlement, NSP-Wisconsin has conveyed approximately 1,390 acres of land to the State of Wisconsin and tribal trustees.  Fieldwork to address the Phase I Project Area at the Ashland site began at the end of 2012 and continues in 2013.

Negotiations between the EPA and NSP-Wisconsin regarding who will pay or perform the cleanup of the Sediments are ongoing.  The EPA’s ROD for the Ashland site includes estimates that the cost of the preferred remediation related to the Sediments is between $63 million and $77 million, with a potential deviation in such estimated costs of up to 50 percent higher to 30 percent lower.

In August 2012, NSP-Wisconsin also filed litigation against other PRPs for their share of the cleanup costs for the Ashland site.  Trial for this matter has been scheduled for June 2014. Negotiations between the EPA, NSP-Wisconsin and several of the other PRPs regarding the PRPs’ fair share of the cleanup costs for the Ashland site are also ongoing.

At June 30, 2013 and Dec. 31, 2012, NSP-Wisconsin had recorded a liability of $101.3 million and $103.7 million, respectively, for the Ashland site based upon potential remediation and design costs together with estimated outside legal and consultant costs; of which $14.3 million and $20.1 million, respectively, was considered a current liability.  The reduction in recorded liability at June 30, 2013 reflects that cleanup has now commenced and costs are being incurred with respect to the Phase I Project Area.  NSP-Wisconsin’s potential liability, the actual cost of remediation and the time frame over which the amounts may be paid are subject to change.  NSP-Wisconsin also continues to work to identify and access state and federal funds to apply to the ultimate remediation cost of the entire site.  Unresolved issues or factors that could result in higher or lower NSP-Wisconsin remediation costs for the Ashland site include the cleanup approach implemented for the Sediments, which party implements the cleanup, the timing of when the cleanup is implemented, potential contributions by other PRPs and whether federal or state funding may be directed to help offset remediation costs at the Ashland site.

NSP-Wisconsin has deferred the estimated site remediation costs, as a regulatory asset, based on an expectation that the PSCW will continue to allow NSP-Wisconsin to recover payments for environmental remediation from its customers.  The PSCW has consistently authorized in NSP-Wisconsin rates recovery of all remediation costs incurred at the Ashland site, and has authorized recovery of MGP remediation costs by other Wisconsin utilities.  External MGP remediation costs are subject to deferral in the Wisconsin retail jurisdiction and are reviewed for prudence as part of the Wisconsin retail rate case process.  Under an existing PSCW policy, utilities have recovered remediation costs for MGPs in natural gas rates, amortized over a four-to six-year period.  The PSCW historically has not allowed utilities to recover their carrying costs on unamortized regulatory assets for MGP remediation.

In a recent rate case decision, the PSCW recognized the potential magnitude of the future liability for the cleanup at the Ashland site.  In December 2012, the PSCW granted an exception to its existing policy at the request of NSP-Wisconsin.  The elements of this exception include: 1) approval to begin recovery of estimated Phase 1 Project costs beginning on Jan. 1, 2013; 2) approval to amortize these estimated costs over a ten-year period; and 3) approval to apply a three percent carrying cost to the unamortized regulatory asset.  Implementation of this exception will help mitigate the rate impact to natural gas customers and the risk to NSP-Wisconsin from a longer amortization period.

Environmental Requirements

Greenhouse Gas (GHG) New Source Performance Standard Proposal (NSPS) and Emission Guideline for Existing Sources — In April 2012, the EPA proposed a GHG NSPS for newly constructed power plants. The proposal requires that carbon dioxide (CO₂) emission rates be equal to a natural gas combined-cycle plant, even if the plant is coal-fired. The EPA also proposed that NSPS not apply to modified or reconstructed existing power plants and that installation of control equipment on existing plants would not constitute a “modification” to those plants under the NSPS program. On June 25, 2013, President Obama issued a memorandum directing the EPA to re-propose GHG emission standards for new power plants and develop GHG emission standards for existing power plants. It is not possible to evaluate the impact of these regulations until the upcoming proposals and final requirements are known.

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 nitrogen oxide (NOx) from utilities in the eastern half of the United States, including Wisconsin.  The CSAPR would have set more stringent requirements than the proposed Clean Air Transport Rule.  The rule also would have created an emissions trading program.

In August 2012, the U.S. 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 that the EPA must continue administering the Clean Air Interstate Rule (CAIR) pending adoption of a valid replacement.  Although the D.C. Circuit had denied all requests for rehearing, in June 2013, the U.S. Supreme Court elected to review the D.C. Circuit’s 2012 decision to vacate the CSAPR. The Court has ordered the parties to file briefs in the appeal this fall and will likely issue a decision by June 2014.

As the EPA continues administering the CAIR while the CSAPR or a replacement rule is pending, NSP-Wisconsin 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.  NSP-Wisconsin purchased allowances in 2012 and plans to continue to purchase allowances in 2013 to comply with the CAIR.  At June 30, 2013, the estimated annual CAIR NOx allowance cost for NSP-Wisconsin did not have a material impact on the results of operations, financial position or cash flows.

Federal Clean Water Act - Effluent Limitations Guidelines (ELG) — In June 2013, the 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 (CCR). Refuse derived fuel, biomass and other alternatively fueled power plants are not addressed by the proposed revisions. The proposed rule identifies four potential regulatory options and invites comments on those regulatory approaches. The options differ in the number of waste streams covered, size of the units controlled and stringency of controls. The EPA is also seeking comment on the interaction between the ELG proposal and its proposed CCR rule, which is another proposed rule that would also regulate surface impoundments that store coal combustion byproducts (coal ash) and whether to regulate coal ash as hazardous or nonhazardous waste. A final rule is anticipated in 2014. Under the current proposed rule, facilities would need to comply as soon as possible after July 1, 2017 but no later than July 1, 2022. The impact of this rule on NSP-Wisconsin is uncertain at this time.

Legal Contingencies

NSP-Wisconsin 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 NSP-Wisconsin’s financial statements.  Unless otherwise required by GAAP, legal fees are expensed as incurred.

Environmental Litigation

Native Village of Kivalina vs. Xcel Energy Inc. et al. — In February 2008, the City and Native Village of Kivalina, Alaska, filed a lawsuit in the U.S. District Court for the Northern District of California against Xcel Energy and 23 other utility, oil, gas and coal companies.  Plaintiffs claim that defendants’ emission of CO₂ and other greenhouse gases contribute to global warming, which is harming their village.  Xcel Energy believes the claims asserted in this lawsuit are without merit and joined with other utility defendants in filing a motion to dismiss in June 2008.  In October 2009, the U.S. District Court dismissed the lawsuit on constitutional grounds.  In November 2009, plaintiffs filed a notice of appeal to the U.S. Court of Appeals for the Ninth Circuit (Ninth Circuit).  In October 2012, the Ninth Circuit affirmed the U.S. District Court’s dismissal and subsequently rejected plaintiffs’ request for rehearing.  In May 2013, the U.S. Supreme Court denied plaintiffs’ request for review, which brings this litigation to a close.  No accrual has been recorded for this matter.

Comer vs. Xcel Energy Inc. et al. — In May 2011, less than a year after their initial lawsuit was dismissed, plaintiffs in this purported class action lawsuit filed a second lawsuit against more than 85 utility, oil, chemical and coal companies in the U.S. District Court in Mississippi.  The complaint alleges defendants’ CO₂ emissions intensified the strength of Hurricane Katrina and increased the damage plaintiffs purportedly sustained to their property.  Plaintiffs base their claims on public and private nuisance, trespass and negligence.  Among the defendants named in the complaint are Xcel Energy Inc., SPS, PSCo, NSP-Wisconsin and NSP-Minnesota.  The amount of damages claimed by plaintiffs is unknown.  The defendants believe this lawsuit is without merit and filed a motion to dismiss the lawsuit.  In March 2012, the U.S. District Court granted this motion for dismissal.  In April 2012, plaintiffs appealed this decision to the U.S. Court of Appeals for the Fifth Circuit.  In May 2013, the Fifth Circuit affirmed the district court’s dismissal of this lawsuit. It is uncertain whether plaintiffs will seek further review of this decision. Although Xcel Energy believes the likelihood of loss is remote based upon existing case law, it is not possible to estimate the amount or range of reasonably possible loss in the event of an adverse outcome of this matter.  No accrual has been recorded for this matter.

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Selected Balance Sheet Data (Tables)

6 Months Ended

Jun. 30, 2013

Balance Sheet Related Disclosures [Abstract]

Accounts Receivable, Net

(Thousands of Dollars)	June 30, 2013			Dec. 31, 2012
Accounts receivable, net
Accounts receivable	$	53,700		$	55,039
Less allowance for bad debts	(4,116		)	(4,333		)
	$	49,584		$	50,706

Inventories

(Thousands of Dollars)	June 30, 2013		Dec. 31, 2012
Inventories
Materials and supplies	$	6,541	$	6,172
Fuel	7,268		6,664
Natural gas	3,964		6,849
	$	17,773	$	19,685

Property, Plant and Equipment, Net

(Thousands of Dollars)	June 30, 2013			Dec. 31, 2012
Property, plant and equipment, net
Electric plant	$	1,848,303		$	1,795,239
Natural gas plant	227,790			224,625
Common and other property	112,043			111,319
Construction work in progress	77,144			62,629
Total property, plant and equipment	2,265,280			2,193,812
Less accumulated depreciation	(921,567		)	(895,576		)
	$	1,343,713		$	1,298,236

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Benefit Plans and Other Postretirement Benefits

6 Months Ended

Jun. 30, 2013

Compensation and Retirement Disclosure [Abstract]

Benefit Plans and Other Postretirement Benefits

Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2013			2012			2013			2012
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	1,420		$	1,150		$	6		$	5
Interest cost	1,731			1,925			190			274
Expected return on plan assets	(2,498		)	(2,634		)	(10		)	(12		)
Amortization of transition obligation	—			—			—			43
Amortization of prior service cost (credit)	104			443			(88		)	(3		)
Amortization of net loss	1,981			1,487			241			128
Net benefit cost recognized for financial reporting	$	2,738		$	2,371		$	339		$	435

	Six Months Ended June 30
	2013			2012			2013			2012
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	2,841		$	2,284		$	12		$	10
Interest cost	3,462			3,835			380			538
Expected return on plan assets	(4,997		)	(5,245		)	(21		)	(25		)
Amortization of transition obligation	—			—			—			86
Amortization of prior service cost (credit)	208			886			(176		)	(7		)
Amortization of net loss	3,962			2,922			482			242
Net benefit cost recognized for financial reporting	$	5,476		$	4,682		$	677		$	844

In January 2013, contributions of $191.5 million were made across four of Xcel Energy’s pension plans, of which $11.3 million was attributable to NSP-Wisconsin.  Xcel Energy does not expect additional pension contributions during 2013.

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Document and Entity Information	6 Months Ended
	Jun. 30, 2013	Aug. 05, 2013
Document and Entity Information [Abstract]
Entity Registrant Name	NORTHERN STATES POWER CO /WI/
Entity Central Index Key	0000072909
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding		933,000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes

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Other Comprehensive Income

6 Months Ended

Jun. 30, 2013

Stockholders' Equity Note [Abstract]

Other Comprehensive Income

Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax, for the three and six months ended June 30, 2013 were as follows:

(Thousands of Dollars)	Gains and Losses on Cash Flow Hedges
Accumulated other comprehensive loss at April 1	$	(418	)
Losses reclassified from net accumulated other comprehensive loss	18
Net current period other comprehensive income	18
Accumulated other comprehensive loss at June 30	$	(400	)

(Thousands of Dollars)	Gains and Losses on Cash Flow Hedges
Accumulated other comprehensive loss at Jan. 1	$	(437	)
Losses reclassified from net accumulated other comprehensive loss	37
Net current period other comprehensive income	37
Accumulated other comprehensive loss at June 30	$	(400	)

Reclassifications from accumulated other comprehensive loss for the three and six months ended June 30, 2013 were as follows:

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Three Months Ended June 30, 2013				Six Months Ended June 30, 2013
Losses on cash flow hedges:
Interest rate derivatives	$	32		(a)	$	63		(a)
Total, pre-tax	32				63
Tax benefit	(14		)		(26		)
Total amounts reclassified, net of tax	$	18			$	37

^(a)  Included in interest charges.