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 March 31, 2013

or

o 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  o 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  o 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 o	Accelerated filer o
Non-accelerated filer x	Smaller reporting company o
(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).  o 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 May 6, 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	16
Item 4   —	Controls and Procedures	19
PART II — OTHER INFORMATION
Item 1    —	Legal Proceedings	20
Item 1A —	Risk Factors	20
Item 4    —	Mine Safety Disclosures	20
Item 5    —	Other Information	20
Item 6    —	Exhibits	20
SIGNATURES		21

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).

2

PART I — FINANCIAL INFORMATION

Item 1 — ­FINANCIAL STATEMENTS

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

(amounts in thousands)

	Three Months Ended March 31
	2013			2012
Operating revenues
Electric	$	190,811		$	182,001
Natural gas		50,357			41,492
Other		247			306
Total operating revenues		241,415			223,799
Operating expenses
Electric fuel and purchased power, non-affiliates		4,170			3,447
Purchased power, affiliates		98,942			99,167
Cost of natural gas sold and transported		30,985			26,879
Operating and maintenance expenses		41,676			38,500
Conservation program expenses		2,992			3,502
Depreciation and amortization		18,855			17,009
Taxes (other than income taxes)		6,394			6,381
Total operating expenses		204,014			194,885
Operating income		37,401			28,914
Other income, net		115			500
Allowance for funds used during construction — equity		946			999
Interest charges and financing costs
Interest charges — includes other financing costs of $381 and $426, respectively		6,855			6,015
Allowance for funds used during construction — debt		(409	)		(86	)
Total interest charges and financing costs		6,446			5,929
Income before income taxes		32,016			24,484
Income taxes		12,331			9,606
Net income	$	19,685		$	14,878

See Notes to Consolidated Financial Statements

3

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(amounts in thousands)

	Three Months Ended March 31
	2013		2012
Net income	$	19,685	$	14,878
Other comprehensive income
Derivative instruments:
Reclassification of losses to net income, net of tax of $13 for each of the three months ended March 31, 2013 and 2012		19		19
Other comprehensive income		19		19
Comprehensive income	$	19,704	$	14,897

See Notes to Consolidated Financial Statements

4

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(amounts in thousands)

	Three Months Ended March 31
	2013			2012
Operating activities
Net income	$	19,685		$	14,878
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization		19,139			17,319
Deferred income taxes		7,136			5,304
Amortization of investment tax credits		(166	)		(157	)
Allowance for equity funds used during construction		(946	)		(999	)
Net derivative losses		31			32
Changes in operating assets and liabilities:
Accounts receivable		(10,454	)		(7,818	)
Accrued unbilled revenues		8,559			14,184
Inventories		4,633			7,886
Other current assets		7,671			6,395
Accounts payable		(6,337	)		(3,996	)
Net regulatory assets and liabilities		2,541			3,359
Other current liabilities		3,086			2,082
Pension and other employee benefit obligations		(10,860	)		(12,473	)
Change in other noncurrent assets		202			(197	)
Change in other noncurrent liabilities		50			(21	)
Net cash provided by operating activities		43,970			45,778
Investing activities
Utility capital/construction expenditures		(39,370	)		(36,748	)
Allowance for equity funds used during construction		946			999
Other, net		(96	)		1,034
Net cash used in investing activities		(38,520	)		(34,715	)
Financing activities
(Repayments of) proceeds from short-term borrowings, net		(18,000	)		5,000
Proceeds from notes payable to affiliate		-			50
Repayments of long-term debt		(72	)		(16	)
Capital contributions from parent		20,000			-
Dividends paid to parent		(7,667	)		(16,225	)
Net cash used in financing activities		(5,739	)		(11,191	)
Net change in cash and cash equivalents		(289	)		(128	)
Cash and cash equivalents at beginning of period		4,459			1,571
Cash and cash equivalents at end of period	$	4,170		$	1,443
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(6,104	)	$	(6,546	)
Cash received (paid) for income taxes, net		697			(833	)
Supplemental disclosure of non-cash investing transactions:
Property, plant and equipment additions in accounts payable	$	6,627		$	4,406

See Notes to Consolidated Financial Statements

5

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS (UNAUDITED)

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

	March 31, 2013			Dec. 31, 2012
Assets
Current assets
Cash and cash equivalents	$	4,170		$	4,459
Accounts receivable, net		61,160			50,706
Accrued unbilled revenues		40,579			49,138
Inventories		15,052			19,685
Regulatory assets		13,162			12,048
Prepaid taxes		17,416			24,688
Deferred income taxes		3,494			-
Prepayments and other		2,916			4,394
Total current assets		157,949			165,118
Property, plant and equipment, net		1,317,605			1,298,236
Other assets
Regulatory assets		238,541			240,459
Other investments		3,328			3,232
Other		3,841			4,040
Total other assets		245,710			247,731
Total assets	$	1,721,264		$	1,711,085
Liabilities and Equity
Current liabilities
Current portion of long-term debt	$	103		$	1,246
Short-term debt		21,000			39,000
Notes payable to affiliates		550			550
Accounts payable		23,109			30,723
Accounts payable to affiliates		28,843			31,556
Dividends payable to parent		7,519			7,667
Regulatory liabilities		7,337			6,086
Environmental liabilities		23,200			23,427
Accrued interest		7,359			7,304
Other		13,178			11,794
Total current liabilities		132,198			159,353
Deferred credits and other liabilities
Deferred income taxes		273,592			261,800
Deferred investment tax credits		9,103			8,911
Regulatory liabilities		125,500			123,746
Environmental liabilities		85,774			84,655
Customer advances		15,904			15,631
Pension and employee benefit obligations		52,768			63,643
Other		8,655			8,923
Total deferred credits and other liabilities		571,296			567,309
Commitments and contingencies
Capitalization
Long-term debt		468,479			467,317
Common stock — 1,000,000 shares authorized of $100 par value; 933,000 shares outstanding at March 31, 2013 and Dec. 31, 2012, respectively		93,300			93,300
Additional paid in capital		209,867			189,867
Retained earnings		246,542			234,376
Accumulated other comprehensive loss		(418	)		(437	)
Total common stockholder’s equity		549,291			517,106
Total liabilities and equity	$	1,721,264		$	1,711,085

See Notes to Consolidated Financial Statements

6

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 March 31, 2013 and Dec. 31, 2012; the results of its operations, including the components of net income and comprehensive income, for the three months ended March 31, 2013 and 2012; and its cash flows for the three months ended March 31, 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 March 31, 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.

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 7 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 11 for the required disclosures.

3.  Selected Balance Sheet Data

(Thousands of Dollars)	March 31, 2013			Dec. 31, 2012
Accounts receivable, net (a)
Accounts receivable	$	65,605		$	55,039
Less allowance for bad debts		(4,445	)		(4,333	)
	$	61,160		$	50,706

(a) Accounts receivable, net includes $586 due from affiliates as of Dec. 31, 2012.

7

(Thousands of Dollars)	March 31, 2013		Dec. 31, 2012
Inventories
Materials and supplies	$	6,191	$	6,172
Fuel		7,772		6,664
Natural gas		1,089		6,849
	$	15,052	$	19,685

(Thousands of Dollars)	March 31, 2013			Dec. 31, 2012
Property, plant and equipment, net
Electric plant	$	1,817,310		$	1,795,239
Natural gas plant		226,657			224,625
Common and other property		110,715			111,319
Construction work in progress		71,527			62,629
Total property, plant and equipment		2,226,209			2,193,812
Less accumulated depreciation		(908,604	)		(895,576	)
	$	1,317,605		$	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 March 31, 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 March 31, 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 March 31, 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)	March 31, 2013		Dec. 31, 2012
Unrecognized tax benefit — Permanent tax positions	$	0.1	$	0.1
Unrecognized tax benefit — Temporary tax positions		1.2		1.2
Total unrecognized tax benefit	$	1.3	$	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)	March 31, 2013			Dec. 31, 2012
NOL and tax credit carryforwards	$	(0.9	)	$	(0.9	)

8

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

5.  Commitments and Contingencies

Except as noted below, 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)	March 31, 2013		Dec. 31, 2012
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under the guarantee		0.3		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 will convey approximately 1,390 acres of land to the State of Wisconsin.  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.

9

At March 31, 2013 and Dec. 31, 2012, NSP-Wisconsin had recorded a liability of $103.8 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 $18.1 million and $20.1 million, respectively, was considered a current liability.  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 Public Service Commission of Wisconsin (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

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 also stated that the EPA must continue administering the Clean Air Interstate Rule (CAIR) pending adoption of a valid replacement.  In October 2012, the EPA, as well as state and local governments and environmental advocates, petitioned the D.C. Circuit to rehear the CSAPR appeal.  In January 2013, the D.C. Circuit denied all requests for rehearing.  In March 2013, the EPA and a coalition of environmental advocacy groups separately petitioned for U.S. Supreme Court review of the CSAPR decision.  It is not known whether the Supreme Court will decide to review the D.C. Circuit’s decision.

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 March 31, 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.

10

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 carbon dioxide (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.  Plaintiffs subsequently filed a petition for review with the United States Supreme Court. It is unknown whether the United States Supreme Court will grant this petition.  The amount of damages claimed by plaintiffs is unknown, but likely includes the cost of relocating the Village of Kivalina.  Plaintiffs’ alleged relocation is estimated to cost between $95 million to $400 million.  Although Xcel Energy believes the likelihood of loss is remote based primarily on 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.

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.  Oral arguments occurred in May 2013.  It is uncertain when the Fifth Circuit will issue its decision.  Although Xcel Energy believes the likelihood of loss is remote based primarily on 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.

6.  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 March 31, 2013			Twelve Months Ended Dec. 31, 2012
Borrowing limit	$	150		$	150
Amount outstandingat period end		21			39
Average amount outstanding		24			61
Maximum amount outstanding		46			116
Weighted average interest rate, computed on a daily basis		0.34	%		0.39	%
Weighted average interest rate at period end		0.33			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 March 31, 2013 and Dec. 31, 2012, there were no letters of credit outstanding.

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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 March 31, 2013, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility(a)		Drawn (b)		Available
$	150.0	$	21.0	$	129.0

(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 March 31, 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)	March 31, 2013			Dec. 31, 2012
Notes payable to affiliates	$	0.6		$	0.6
Weighted average interest rate		0.33	%		0.33	%

7.  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.

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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 March 31, 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 March 31, 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 March 31, 2013 and Dec. 31, 2012:

(Amounts in Thousands) (a)(b)	March 31, 2013		Dec. 31, 2012
Million British thermal units (MMBtu) of natural gas		-		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 March 31
(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		19			19
Accumulated other comprehensive loss related to cash flow hedges at March 31	$	(418	)	$	(495	)

During the three months ended March 31, 2012, changes in the fair value of natural gas commodity derivatives resulted in net losses of $0.4 million, recognized as regulatory assets and liabilities.  For the three months ended March 31, 2013, changes in the fair value of natural gas commodity derivatives resulted in immaterial net gains 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 three months ended March 31, 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 months ended March 31, 2013 were immaterial.

NSP-Wisconsin had no derivative instruments designated as fair value hedges during the three months ended March 31, 2013 and 2012.

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Recurring Fair Value Measurements — There were no recognized recurring fair value measurements at March 31, 2013.  The following table presents, for each of the fair value hierarchy levels, NSP-Wisconsin’s liabilities measured at fair value on a recurring basis at Dec. 31, 2012:

	Dec. 31, 2012
	Fair Value
(Thousands of Dollars)	Level 1		Level 2		Level 3		Fair Value Total		Counterparty Netting (a)		Total (b)
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 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 liabilities balance of $11.8 million at Dec. 31, 2012 in the consolidated balance sheets.

Fair Value of Long-Term Debt

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

	March 31, 2013				Dec. 31, 2012
	Carrying				Carrying
(Thousands of Dollars)	Amount		Fair Value		Amount		Fair Value
Long-term debt, including current portion	$	468,582	$	579,499	$	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 March 31, 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.  These fair value estimates have not been comprehensively revalued for purposes of these consolidated financial statements since those dates and current estimates of fair values may differ significantly.

8.  Other Income, Net

Other income, net consisted of the following:

	Three Months Ended March 31
(Thousands of Dollars)	2013			2012
Interest income	$	199		$	657
Other nonoperating income		41			-
Insurance policy expense		(122	)		(150	)
Other nonoperating expense		(3	)		(7	)
Other income, net	$	115		$	500

9.  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.

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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.

	Regulated		Regulated		All		Reconciling			Consolidated
(Thousands of Dollars)	Electric		Natural Gas		Other		Eliminations			Total
Three Months Ended March 31, 2013
Operating revenues from external customers	$	190,811	$	50,357	$	247	$	-		$	241,415
Intersegment revenues		78		308		-		(386	)		-
Total revenues	$	190,889	$	50,665	$	247	$	(386	)	$	241,415
Net income	$	13,603	$	5,624	$	458	$	-		$	19,685

	Regulated		Regulated		All		Reconciling			Consolidated
(Thousands of Dollars)	Electric		Natural Gas		Other		Eliminations			Total
Three Months Ended March 31, 2012
Operating revenues from external customers	$	182,001	$	41,492	$	306	$	-		$	223,799
Intersegment revenues		87		203		-		(290	)		-
Total revenues	$	182,088	$	41,695	$	306	$	(290	)	$	223,799
Net income	$	11,248	$	3,400	$	230	$	-		$	14,878

10.  Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost

	Three Months Ended March 31
	2013			2012			2013			2012
							Postretirement Health
(Thousands of Dollars)	Pension Benefits						Care Benefits
Service cost	$	1,421		$	1,134		$	6		$	5
Interest cost		1,731			1,910			190			264
Expected return on plan assets		(2,499	)		(2,611	)		(11	)		(13	)
Amortization of transition obligation		-			-			-			43
Amortization of prior service cost (credit)		104			443			(88	)		(4	)
Amortization of net loss		1,981			1,435			241			114
Net benefit cost recognized for financial reporting	$	2,738		$	2,311		$	338		$	409

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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11. Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax, for the three months ended March 31, 2013 were as follows:

(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		19
Net current period other comprehensive income		19
Accumulated other comprehensive loss at March 31	$	(418	)

Reclassifications from accumulated other comprehensive loss for the three months ended March 31, 2013 were as follows:

(Thousands of Dollars)	Amounts Reclassified from Accumulated Other Comprehensive Loss
Losses on cash flow hedges:
Interest rate derivatives	$	32	(a)
Total, pre-tax		32
Tax benefit		(13	)
Total amounts reclassified, net of tax	$	19

(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.

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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 March 31, 2013.

Results of Operations

NSP-Wisconsin’s net income was $19.7 million for the three months ended March 31, 2013, compared with $14.9 million for the same period in 2012.  The increase is the result of higher electric and gas rates implemented in January 2013 and the effect of cooler weather, which were partially offset by higher O&M expenses and depreciation expense.

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:

	Three Months Ended March 31
(Millions of Dollars)	2013			2012
Electric revenues	$	191		$	182
Electric fuel and purchased power		(103	)		(103	)
Electric margin	$	88		$	79

The following tables summarize the components of the changes in electric revenues and electric margin for the three months ended March 31:

Electric Revenues

(Millions of Dollars)	2013 vs. 2012
Retail rate increase (Wisconsin)	$	8
Estimated impact of weather		5
Fuel and purchased power cost recovery		2
Firm wholesale		(8	)
Other, net		2
Total increase in electric revenues	$	9

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Electric Margin

(Millions of Dollars)	2013 vs. 2012
Retail rate increase (Wisconsin)	$	8
Estimated impact of weather		5
Firm wholesale		(5	)
Other, net		1
Total increase in electric margin	$	9

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:

	Three Months Ended March 31
(Millions of Dollars)	2013			2012
Natural gas revenues	$	50		$	41
Cost of natural gas sold and transported		(31	)		(27	)
Natural gas margin	$	19		$	14

The following tables summarize the components of the changes in natural gas revenues and natural gas margin for the three months ended March 31:

Natural Gas Revenues

(Millions of Dollars)	2013 vs. 2012
Purchased natural gas adjustment clause recovery	$	4
Estimated impact of weather		3
Retail rate increase (Wisconsin)		1
Other, net		1
Total increase in natural gas revenues	$	9

Natural Gas Margin

(Millions of Dollars)	2013 vs. 2012
Estimated impact of weather	$	3
Retail rate increase (Wisconsin)		1
Other, net		1
Total increase in natural gas margin	$	5

Non-Fuel Operating Expenses and Other Items

O&M Expenses — O&M expenses increased $3.2 million, or 8.2 percent, for the first quarter of 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
Interchange costs		1
Other, net		1
Total increase in O&M expenses	$	3

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Income Taxes — Income tax expense increased by $2.7 million for the first quarter of 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 38.5 percent for the first quarter of 2013 compared with 39.2 percent for the same period in 2012.

Factors Affecting Results of Operations

Public Utility Regulation

CapX2020 Hampton, Minn. to Rochester, Minn. to La Crosse, Wis. 345 kilovolt (kV) Transmission Line — The PSCW issued a certificate of public convenience and necessity (CPCN) for the Wisconsin portion of the project in May 2012.  The Wisconsin route is approximately 50 miles of new transmission line with an estimated cost of $211 million.  Subsequent legal challenges to the PSCW’s order by intervenors were unsuccessful, thereby rendering the PSCW’s order final.  Construction on the Wisconsin portion of the line is anticipated to begin in 2014 and the line is expected to go into service in 2015.

Summary of Recent Federal Regulatory Developments

The Federal Energy Regulatory Commission (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.

Midwest 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 expected to serve multiple purposes, such as improved reliability, reduced congestion, transmission for renewable energy, and load serving.  Certain parties have appealed the FERC MVP tariff orders to the U.S. Court of Appeals for the Seventh Circuit.  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, FERC 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.  Rather, the FERC required that opportunity to build such projects would extend to competitive transmission developers.  Compliance with Order 1000 for NSP-Wisconsin will occur through changes to the MISO tariff.  MISO has made its initial compliance filings to incorporate new provisions into its tariffs regarding regional planning and cost allocation; the filings to address interregional planning and cost allocation requirements are due July 10, 2013.  Wisconsin has not developed legislation that preserves ROFR rights for utilities at the state level.

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 March 31, 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.

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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.

Item 6 — EXHIBITS

* Indicates incorporation by reference

t Furnished, herewith, not filed.  Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

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 t	The following materials from NSP-Wisconsin’s Quarterly Report on Form 10-Q for the quarter ended March 31, 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.

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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)
May 6, 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

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