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, 2017

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, smaller reporting company or an emerging growth company.  See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth 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)	Emerging growth company ¨

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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 July 28, 2017
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	22
PART II — OTHER INFORMATION
Item 1    —	Legal Proceedings	23
Item 1A —	Risk Factors	23
Item 6    —	Exhibits	23
SIGNATURES		24

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.  The electric production and transmission system of NSP-Minnesota and NSP-Wisconsin, which is operated on an integrated basis and is managed by NSP-Minnesota, is referred to collectively as the NSP System. Additional information on Xcel Energy Inc. and its subsidiaries (collectively, Xcel Energy) is available on various filings with the Securities and Exchange Commission (SEC).

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
	2017			2016			2017			2016
Operating revenues
Electric	$	210,742		$	202,879		$	427,051		$	414,403
Natural gas	19,027			16,005			67,374			59,025
Other	257			289			532			595
Total operating revenues	230,026			219,173			494,957			474,023
Operating expenses
Electric fuel and purchased power, non-affiliates	3,583			3,651			6,456			7,632
Purchased power, affiliates	101,793			96,853			208,251			205,567
Cost of natural gas sold and transported	8,563			6,465			34,550			29,883
Operating and maintenance expenses	49,210			50,516			99,072			99,135
Conservation expenses	3,177			3,094			6,231			6,160
Depreciation and amortization	27,628			23,720			54,677			48,169
Taxes (other than income taxes)	7,005			7,096			13,878			14,251
Total operating expenses	200,959			191,395			423,115			410,797
Operating income	29,067			27,778			71,842			63,226
Other income, net	83			77			329			526
Allowance for funds used during construction — equity	1,751			918			3,038			1,728
Interest charges and financing costs
Interest charges — includes other financing costs of $461, $461, $917 and $923, respectively	8,656			8,583			17,338			17,187
Allowance for funds used during construction — debt	(749		)	(392		)	(1,299		)	(739		)
Total interest charges and financing costs	7,907			8,191			16,039			16,448
Income before income taxes	22,994			20,582			59,170			49,032
Income taxes	8,753			7,957			22,510			18,776
Net income	$	14,241		$	12,625		$	36,660		$	30,256

See Notes to Consolidated Financial Statements

3

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

(amounts in thousands)

	Three Months Ended June 30				Six Months Ended June 30
	2017		2016		2017		2016
Net income	$	14,241	$	12,625	$	36,660	$	30,256
Other comprehensive income
Derivative instruments:
Reclassification of losses to net income, net of tax of $12, $12, $24 and $25, respectively	19		19		38		38
Other comprehensive income	19		19		38		38
Comprehensive income	$	14,260	$	12,644	$	36,698	$	30,294

See Notes to Consolidated Financial Statements

4

NSP-WISCONSIN AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

(amounts in thousands)

	Six Months Ended June 30
	2017			2016
Operating activities
Net income	$	36,660		$	30,256
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	55,434			48,929
Deferred income taxes	22,588			15,188
Amortization of investment tax credits	(262		)	(264		)
Allowance for equity funds used during construction	(3,038		)	(1,728		)
Net derivative losses	115			138
Other, net	(1,505		)	—
Changes in operating assets and liabilities:
Accounts receivable	(295		)	4,599
Accrued unbilled revenues	10,846			6,072
Inventories	2,669			5,429
Other current assets	(58		)	329
Accounts payable	28,882			12,907
Net regulatory assets and liabilities	(3,112		)	1,555
Other current liabilities	(9,191		)	589
Pension and other employee benefit obligations	(8,735		)	(6,848		)
Change in other noncurrent assets	(359		)	(393		)
Change in other noncurrent liabilities	(2,696		)	555
Net cash provided by operating activities	127,943			117,313
Investing activities
Utility capital/construction expenditures	(90,735		)	(87,791		)
Allowance for equity funds used during construction	3,038			1,728
Other, net	(33		)	687
Net cash used in investing activities	(87,730		)	(85,376		)
Financing activities
Repayments of short-term borrowings, net	(14,000		)	(2,000		)
Repayments of long-term debt	(27		)	(29		)
Capital contributions from (to) parent	12,282			(1,545		)
Dividends paid to parent	(38,800		)	(27,850		)
Other, net	(70		)	—
Net cash used in financing activities	(40,615		)	(31,424		)
Net change in cash and cash equivalents	(402		)	513
Cash and cash equivalents at beginning of period	1,546			1,079
Cash and cash equivalents at end of period	$	1,144		$	1,592
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	$	(15,062	)	$	(15,718	)
Cash paid for income taxes, net	(9,699		)	(3,336		)
Supplemental disclosure of non-cash investing transactions:
Property, plant and equipment additions in accounts payable	$	21,867		$	10,220

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, 2017			Dec. 31, 2016
Assets
Current assets
Cash and cash equivalents	$	1,144		$	1,546
Accounts receivable, net	54,340			54,031
Accrued unbilled revenues	42,792			53,638
Inventories	15,640			18,309
Regulatory assets	18,161			18,162
Prepaid taxes	26,244			25,915
Prepayments and other	3,434			3,785
Total current assets	161,755			175,386
Property, plant and equipment, net	2,000,347			1,947,637
Other assets
Regulatory assets	274,107			286,188
Other investments	2,876			2,844
Other	1,143			785
Total other assets	278,126			289,817
Total assets	$	2,440,228		$	2,412,840
Liabilities and Equity
Current liabilities
Current portion of long-term debt	$	1,096		$	1,123
Short-term debt	46,000			60,000
Notes payable to affiliates	500			500
Accounts payable	48,670			41,068
Accounts payable to affiliates	53,294			29,037
Dividends payable to parent	13,840			10,729
Regulatory liabilities	24,140			17,428
Environmental liabilities	29,752			41,438
Accrued interest	8,083			8,012
Other	16,651			26,484
Total current liabilities	242,026			235,819
Deferred credits and other liabilities
Deferred income taxes	454,839			430,593
Deferred investment tax credits	7,775			8,037
Regulatory liabilities	152,588			148,189
Environmental liabilities	17,146			23,003
Customer advances	16,759			19,425
Pension and employee benefit obligations	46,281			55,164
Other	18,857			18,814
Total deferred credits and other liabilities	714,245			703,225
Commitments and contingencies
Capitalization
Long-term debt	662,306			661,946
Common stock — 1,000,000 shares authorized of $100 par value; 933,000 shares outstanding at June 30, 2017 and Dec. 31, 2016, respectively	93,300			93,300
Additional paid in capital	410,329			395,315
Retained earnings	318,117			323,368
Accumulated other comprehensive loss	(95		)	(133		)
Total common stockholder’s equity	821,651			811,850
Total liabilities and equity	$	2,440,228		$	2,412,840

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 June 30, 2017 and Dec. 31, 2016; the results of its operations, including the components of net income and comprehensive income, for the three and six months ended June 30, 2017 and 2016; and its cash flows for the six months ended June 30, 2017 and 2016. All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after June 30, 2017 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, 2016 balance sheet information has been derived from the audited 2016 consolidated financial statements included in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2016. 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, 2016, filed with the SEC on Feb. 24, 2017. 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, 2016, appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

2. Accounting Pronouncements

Recently Issued

Revenue Recognition— In May 2014, the Financial Accounting Standards Board (FASB) issued Revenue from Contracts with Customers, Topic 606 (Accounting Standards Update (ASU) No. 2014-09), which provides a new framework for the recognition of revenue. NSP-Wisconsin expects its adoption will result in increased disclosures regarding revenue, cash flows and obligations related to arrangements with customers, as well as separate presentation of alternative revenue programs. NSP-Wisconsin has not yet fully determined the impacts of adoption for several aspects of the standard, including a determination whether and how much an evaluation of the collectability of regulated electric and gas revenues will impact the amounts of revenue recognized upon delivery. NSP-Wisconsin currently expects to implement the standard on a modified retrospective basis, which requires application to contracts with customers effective Jan. 1, 2018, with the cumulative impact on contracts not yet completed as of Dec. 31, 2017 recognized as an adjustment to the opening balance of retained earnings.

Classification and Measurement of Financial Instruments — In January 2016, the FASB issued Recognition and Measurement of Financial Assets and Financial Liabilities, Subtopic 825-10 (ASU No. 2016-01), which eliminates the available-for-sale classification for marketable equity securities and also replaces the cost method of accounting for non-marketable equity securities with a model for recognizing impairments and observable price changes. Under the new standard, other than when the consolidation or equity method of accounting is utilized, changes in the fair value of equity securities are to be recognized in earnings. This guidance will be effective for interim and annual reporting periods beginning after Dec. 15, 2017. NSP-Wisconsin expects that the overall impacts of the Jan. 1, 2018 adoption will not be material.

7

Leases —In February 2016, the FASB issued Leases, Topic 842 (ASU No. 2016-02), which for lessees requires balance sheet recognition of right-of-use assets and lease liabilities for most leases. This guidance will be effective for interim and annual reporting periods beginning after Dec. 15, 2018. NSP-Wisconsin has not yet fully determined the impacts of implementation. However, adoption is expected to occur on Jan. 1, 2019 utilizing the practical expedients provided by the standard. As such, agreements entered prior to Jan. 1, 2017 that are currently considered leases are expected to be recognized on the consolidated balance sheet, including contracts for use of office space, equipment and natural gas storage assets, as well as certain purchased power agreements (PPAs) for natural gas-fueled generating facilities. NSP-Wisconsin expects that similar agreements entered after Dec. 31, 2016 will generally qualify as leases under the new standard, but has not yet completed its evaluation of certain other contracts, including arrangements for the secondary use of assets, such as land easements.

Presentation of Net Periodic Benefit Cost —In March 2017, the FASB issued Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost, Topic 715 (ASU No. 2017-07), which establishes that only the service cost element of pension cost may be presented as a component of operating income in the income statement. Also under the guidance, only the service cost component of pension cost is eligible for capitalization. NSP-Wisconsin has not yet fully determined the impacts of adoption of the standard, but expects that as a result of application of accounting principles for rate regulated entities, a similar amount of pension cost, including non-service components, will be recognized consistent with the current ratemaking treatment and that the impacts of adoption will be limited to changes in classification of non-service costs in the consolidated statement of income. This guidance will be effective for interim and annual reporting periods beginning after Dec. 15, 2017.

3. Selected Balance Sheet Data

(Thousands of Dollars)	June 30, 2017			Dec. 31, 2016
Accounts receivable, net (a)
Accounts receivable	$	58,587		$	58,896
Less allowance for bad debts	(4,247		)	(4,865		)
	$	54,340		$	54,031

^(a)  Accounts receivable, net includes an immaterial amount due from affiliates as of June 30, 2017 and Dec. 31, 2016, respectively.

(Thousands of Dollars)	June 30, 2017		Dec. 31, 2016
Inventories
Materials and supplies	$	7,117	$	6,582
Fuel	4,615		4,743
Natural gas	3,908		6,984
	$	15,640	$	18,309

(Thousands of Dollars)	June 30, 2017			Dec. 31, 2016
Property, plant and equipment, net
Electric plant	$	2,534,258		$	2,499,401
Natural gas plant	307,217			294,986
Common and other property	170,486			156,316
Construction work in progress	145,458			118,822
Total property, plant and equipment	3,157,419			3,069,525
Less accumulated depreciation	(1,157,072		)	(1,121,888		)
	$	2,000,347		$	1,947,637

4. Income Taxes

Except to the extent noted below, Note 6 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2016 appropriately represents, in all material respects, the current status of other income tax matters, and are incorporated herein by reference.

8

Federal Audits— 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 2009 through 2013 federal income tax returns, following extensions, expires in December 2017.

In 2012, the Internal Revenue Service (IRS) commenced an examination of tax years 2010 and 2011, including a 2009 carryback claim. The IRS has proposed an adjustment to the federal tax loss carryback claims that would result in $14 million of income tax expense for the 2009 through 2011 claims, and the 2013 through 2015 claims. In 2016 the IRS audit team and Xcel Energy presented their cases to the Office of Appeals; however, the outcome and timing of a resolution is uncertain. NSP-Wisconsin is not expected to accrue any income tax expense related to this adjustment.

In the third quarter of 2015, the IRS commenced an examination of tax years 2012 and 2013. In the second quarter of 2017, the IRS proposed an adjustment to tax year 2012 that may impact Xcel Energy’s net operating loss (NOL) and effective tax rate (ETR). Xcel Energy is evaluating the IRS’ proposal and the outcome and timing of a resolution is uncertain.

State Audits— NSP-Wisconsin is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of June 30, 2017, NSP-Wisconsin’s earliest open tax year that is subject to examination by state taxing authorities under applicable statutes of limitations is 2012. In 2016, Wisconsin began an audit of years 2012 and 2013. As of June 30, 2017, Wisconsin had not proposed any material adjustments, and there were no other state income tax audits in progress.

Unrecognized Benefits— The unrecognized tax benefit balance includes permanent tax positions, which if recognized would affect the annual 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, 2017		Dec. 31, 2016
Unrecognized tax benefit — Permanent tax positions	$	0.4	$	0.4
Unrecognized tax benefit — Temporary tax positions	5.1		4.9
Total unrecognized tax benefit	$	5.5	$	5.3

The unrecognized tax benefit amounts were reduced by the tax benefits associated with 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, 2017			Dec. 31, 2016
NOL and tax credit carryforwards	$	(1.3	)	$	(1.2	)

It is reasonably possible that NSP-Wisconsin’s amount of unrecognized tax benefits could significantly change in the next 12 months as the IRS Appeals and audit progress, the Wisconsin audit progresses, and other state audits resume. As the IRS Appeals and IRS and Wisconsin audits progress, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $2 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, 2017 and Dec. 31, 2016 were not material. No amounts were accrued for penalties related to unrecognized tax benefits as of June 30, 2017 or Dec. 31, 2016.

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, 2016 and in Note 5 to NSP-Wisconsin’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017, appropriately represent, in all material respects, the current status of other rate matters, and are incorporated herein by reference.

9

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

Wisconsin 2018 Electric and Natural Gas Rate Case— In May 2017, NSP-Wisconsin filed a request with the PSCW to increase electric rates by $24.7 million, or 3.6 percent, and natural gas rates by $12.0 million, or 10.1 percent, effective January 2018. The rate filing is based on a 2018 forecast test year, a return on equity (ROE) of 10.0 percent, an equity ratio of 52.53 percent and a forecasted average net investment rate base of approximately $1.2 billion for the electric utility and $138.4 million for the natural gas utility.

Key dates in the procedural schedule are as follows:

• Staff and intervenor testimony — Sept. 12, 2017;

• Rebuttal testimony — Sept. 26, 2017;

• Sur-rebuttal testimony — Oct. 3, 2017; and

• Hearing — Oct. 5, 2017.

A PSCW decision is anticipated in the fourth quarter of 2017.

Pending Regulatory Proceeding — Federal Energy Regulatory Commission (FERC)

Midcontinent Independent System Operator, Inc. (MISO) ROE Complaints — In November 2013, a group of customers filed a complaint at the FERC against MISO transmission owners (TOs), including NSP-Minnesota and NSP-Wisconsin. The complaint argued for a reduction in the ROE in transmission formula rates in the MISO region from 12.38 percent to 9.15 percent, and the removal of ROE adders (including those for Regional Transmission Organization (RTO) membership), effective Nov. 12, 2013.

In December 2015, an administrative law judge (ALJ) recommended the FERC approve a base ROE of 10.32 percent for the MISO TOs. The ALJ found the existing 12.38 percent ROE to be unjust and unreasonable. The recommended 10.32 percent ROE applied a FERC ROE policy adopted in a June 2014 order (Opinion 531). The FERC approved the ALJ recommended 10.32 percent base ROE in an order issued in September 2016. This ROE would be applicable for the 15-month refund period from Nov. 12, 2013 to Feb. 11, 2015, and prospectively from the date of the FERC order. The total prospective ROE would be 10.82 percent, including a 50 basis point adder for RTO membership. Various parties requested rehearing of the September 2016 order. The requests are pending FERC action.

In February 2015, a second complaint seeking to reduce the MISO ROE from 12.38 percent to 8.67 percent prior to any adder was filed with the FERC, resulting in a second period of potential refund from Feb. 12, 2015 to May 11, 2016. In June 2016, the ALJ recommended a ROE of 9.7 percent, applying the methodology adopted by the FERC in Opinion 531. A final FERC decision on the second ROE complaint was expected later in 2017, but in April 2017, the United States Court of Appeals for the District of Columbia Circuit (D.C. Circuit) by opinion, vacated and remanded Opinion 531. It is unclear how the D.C. Circuit’s opinion to vacate and remand Opinion 531 will affect the September 2016 FERC order or the timing and outcome of the second ROE complaint. The MISO TOs are evaluating the impact of the D.C. Circuit ruling on the November 2013 and February 2015 ROE complaints.

As of June 30, 2017, NSP-Minnesota has processed refunds for the Nov. 12, 2013 to Feb. 11, 2015 complaint period based on the 10.32 percent ROE provided in the September 2016 FERC order. NSP-Minnesota has also recognized a current liability representing the best estimate of the final ROE for the Feb. 12, 2015 to May 11, 2016 complaint period.

6. Commitments and Contingencies

Except to the extent noted below and in Note 5 above, the circumstances set forth in Notes 10 and 11 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2016 and in Notes 5 and 6 the consolidated financial statements included in NSP-Wisconsin’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016, 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.

10

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 has a stated maximum amount. The guarantee contains no recourse provisions and requires no collateral. These agreements have expiration dates through 2020.

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

(Millions of Dollars)	June 30, 2017		Dec. 31, 2016
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under this guarantee	—		0.1

Environmental Contingencies

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

In 2012, NSP-Wisconsin agreed to remediate the Phase I Project Area (which includes the Upper Bluff and Kreher Park areas of the Site), under a settlement agreement with the United States Environmental Protection Agency (EPA).

NSP-Wisconsin performed a wet dredge pilot study in 2016 and demonstrated that a wet dredge remedy can meet the performance standards for remediation of the Phase II Project Area (the Sediments). As a result, the EPA authorized NSP-Wisconsin to extend the wet dredge pilot to additional areas of the Site. In January 2017, NSP-Wisconsin agreed to remediate the Sediments, under a settlement agreement with the EPA. The settlement was approved by the U.S. District Court for the Western District of Wisconsin NSP-Wisconsin has initiated field activities to perform a full scale wet dredge remedy of the Sediments in 2017, with performance of restoration activities in 2018.

The current cost estimate for the entire site is approximately $160.0 million, of which approximately $113.2 million has been spent. At June 30, 2017 and Dec. 31, 2016, NSP-Wisconsin had recorded a total liability of $46.8 million and $64.3 million, respectively, for the entire site.

NSP-Wisconsin has deferred the unrecovered portion of the estimated Site remediation costs as a regulatory asset. The PSCW has authorized NSP-Wisconsin rate recovery for all remediation costs incurred at the Site. In 2012, the PSCW agreed to allow NSP-Wisconsin to pre-collect certain costs, to amortize costs over a ten-year period and to apply a three percent carrying cost to the unamortized regulatory asset. In May 2017, NSP-Wisconsin filed a natural gas rate case which included recovery of additional expenses associated with remediating the Site. If approved, the annual recovery of MGP clean-up costs would increase from $12.4 million in 2017 to $18.1 million in 2018.

Other MGP Sites — In addition to the site in Ashland, Wis., NSP-Wisconsin has identified one site where former MGP disposal activities may have resulted in site contamination and is under current investigation. There are other parties that may have responsibility for some portion of any remediation. NSP-Wisconsin anticipates that the majority of the investigation or remediation at this site will continue through at least 2018. NSP-Wisconsin had accrued $0.1 million for this site at June 30, 2017 and Dec. 31, 2016. There may be insurance recovery and/or recovery from other PRPs to offset any costs incurred. NSP-Wisconsin anticipates that any significant amounts incurred will be recovered from customers.

11

Environmental Requirements

Water and Waste

Federal Clean Water Act (CWA) Waters of the United States Rule — In 2015, the EPA and the U.S. Army Corps of Engineers (Corps) published a final rule that significantly expands the types of water bodies regulated under the CWA and broadens the scope of waters subject to federal jurisdiction. The final rule will subject more utility projects to federal CWA jurisdiction, thereby potentially delaying the siting of new generation projects, pipelines, transmission lines and distribution lines, as well as increasing project costs and expanding permitting and reporting requirements. In October 2015, the U.S. Court of Appeals for the Sixth Circuit issued a nationwide stay of the final rule and subsequently ruled that it, rather than the federal district courts, had jurisdiction over challenges to the rule.  In January 2017, the U.S. Supreme Court agreed to resolve the dispute as to which court should hear challenges to the rule. A ruling is expected by the end of 2017.

In February 2017, President Trump issued an executive order requiring the EPA and the Corps to review and revise the final rule. On June 27, 2017, the agencies issued a proposed rule that rescinds the 2015 final rule and reinstates the prior 1986 definition of “Water of the U.S.”

Air

Greenhouse Gas (GHG) Emission Standard for Existing Sources (Clean Power Plan or CPP) — In 2015, the EPA issued its final rule for existing power plants.  Among other things, the rule requires that state plans include enforceable measures to ensure emissions from existing power plants achieve the EPA’s state-specific interim (2022-2029) and final (2030 and thereafter) emission performance targets. 

The CPP was challenged by multiple parties in the D.C. Circuit Court.  In February 2016, the U.S. Supreme Court issued an order staying the final CPP rule. In September 2016, the D.C. Circuit Court heard oral arguments in the consolidated challenges to the CPP. The stay will remain in effect until the D.C. Circuit Court reaches its decision and the U.S. Supreme Court either declines to review the lower court’s decision or reaches a decision of its own.

In March 2017, President Trump signed an executive order requiring the EPA Administrator to review the CPP rule and if appropriate, publish proposed rules suspending, revising or rescinding it. Accordingly, the EPA has requested that the D.C. Circuit Court hold the litigation in abeyance until the EPA completes its work under the executive order. The D.C. Circuit granted the EPA’s request to hold the litigation in abeyance until June 27, 2017, and is considering briefs by the parties on whether the court should remand the challenges to the EPA rather than holding them in abeyance, to determine whether and how the court continues or ends the stay that currently applies to the CPP. On June 9, 2017, the EPA submitted a proposed rule to the Office of Management and Budget entitled “Review of the Clean Power Plan.”

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.

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Employment, Tort and Commercial Litigation

Gas Trading Litigation — e prime, inc. (e prime) is a wholly owned subsidiary of Xcel Energy. e prime was in the business of natural gas trading and marketing but has not engaged in natural gas trading or marketing activities since 2003.  Thirteen lawsuits were commenced against e prime and Xcel Energy (and NSP-Wisconsin, in two instances) between 2003 and 2009 alleging fraud and anticompetitive activities in conspiring to restrain the trade of natural gas and manipulate natural gas prices.

The cases were consolidated in U.S. District Court in Nevada. Five of the cases have since been settled and seven remain active, which includes one multi-district litigation (MDL) matter consisting of a Colorado class (Breckenridge), a Wisconsin class (NSP-Wisconsin), a Kansas class, and two other cases identified as “Sinclair Oil” and “Farmland.” In November 2016, the MDL judge dismissed e prime and Xcel Energy from the Farmland lawsuit, and Farmland has appealed the dismissal. Motions for summary judgment were filed by defendants, including e prime, in all of the remaining lawsuits. In March 2017, the U.S. District Court issued an order dismissing the claims against e prime in the Sinclair Oil lawsuit and denied plaintiffs motions for class certification in the other lawsuits. The U.S. District Court did not grant e prime’s summary judgment motions in the Wisconsin or Colorado cases. There are currently additional motions brought by e prime for reconsideration and summary judgment pending in the U.S. District Court. Xcel Energy, NSP-Wisconsin and e prime have concluded that a loss is remote.

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, 2017			Year Ended Dec. 31, 2016
Borrowing limit	$	150		$	150
Amount outstanding at period end	46			60
Average amount outstanding	26			15
Maximum amount outstanding	49			64
Weighted average interest rate, computed on a daily basis	1.15		%	0.69		%
Weighted average interest rate at period end	1.36			0.95

Letters of Credit— NSP-Wisconsin uses letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations. At June 30, 2017 and Dec. 31, 2016, 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, 2017, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility (a)		Drawn(b)		Available
$	150	$	46	$	104

^(a)  This credit facility expires in June 2021.

^(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, 2017 and Dec. 31, 2016.

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, 2017			Dec. 31, 2016
Notes payable to affiliates	$	0.5		$	0.5
Weighted average interest rate at period end	1.55		%	0.95		%

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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.

Level 2 — Pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable as of the reporting date.  The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts or priced with models using highly observable inputs.

Level 3 — Significant inputs to pricing have little or no observability as of the reporting date.  The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation.

Specific valuation methods include the following:

Cash equivalents— The fair values of cash equivalents are generally based on cost plus accrued interest; money market funds are measured using quoted net asset values.

Interest rate derivatives— The fair values of interest rate derivatives are based on broker quotes that utilize current market interest rate forecasts.

Commodity derivatives— The methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2 classification.  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, for trading purposes and 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, 2017, 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, including forecasted amounts for unsettled hedges, as applicable.

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, as well as for trading purposes. This could include the purchase or sale of natural gas to generate electric energy and natural gas for resale.

The following table details the gross notional amounts of commodity options at June 30, 2017 and Dec. 31, 2016:

(Amounts in Thousands)(a)(b)	June 30, 2017	Dec. 31, 2016
Million British thermal units of natural gas	123	255

^(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.

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Impact of Derivative Activities on Income and Accumulated Other Comprehensive Loss — 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, 2017 and 2016, and $0.1 million of net losses reclassified from accumulated other comprehensive loss into earnings during the six months ended June 30, 2017 and 2016.

During the three and six months ended June 30, 2017, changes in the fair value of natural gas commodity derivatives resulted in immaterial and $0.1 million of net losses recognized as regulatory assets and liabilities, respectively. For the three and six months ended June 30, 2016, changes in the fair value of natural gas commodity derivatives resulted in $0.1 million of net gains and $0.1 million of net losses 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 $0.2 million and $0.6 million were recognized for the six months ended June 30, 2017 and 2016, respectively, 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. There were no losses or gains and immaterial natural gas commodity derivatives settlement losses recognized during the three months ended June 30, 2017 and 2016, respectively.

NSP-Wisconsin had no derivative instruments designated as fair value hedges during the three and six months ended June 30, 2017 and 2016. Therefore, no gains or losses from fair value hedges or related hedged transactions were recognized for these periods.

Consideration of Credit Risk and Concentrations—NSP-Wisconsin continuously monitors the creditworthiness of the counterparties to its interest rate derivatives and commodity derivative contracts prior to settlement, and assesses each counterparty’s ability to perform on the transactions set forth in the contracts. Given this assessment, as well as an assessment of the impact of NSP-Wisconsin’s own credit risk when determining the fair value of derivative liabilities, the impact of credit risk was immaterial to the fair value of unsettled 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.

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

	June 30, 2017
	Fair Value						Fair Value Total		Counterparty Netting(a)		Total(b)
(Thousands of Dollars)	Level 1		Level 2		Level 3
Current derivative assets
Natural gas commodity	$	—	$	71	$	—	$	71	$	—	$	71

	Dec. 31, 2016
	Fair Value						Fair Value Total		Counterparty Netting(a)		Total(b)
(Thousands of Dollars)	Level 1		Level 2		Level 3
Current derivative assets
Natural gas commodity	$	—	$	149	$	—	$	149	$	—	$	149

^(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, 2017 and Dec. 31, 2016.  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 prepayments and other current assets balance of $3.4 million and $3.8 million at June 30, 2017 and Dec. 31, 2016, respectively, in the consolidated balance sheets.

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Fair Value of Long-Term Debt

As of June 30, 2017 and Dec. 31, 2016, other financial instruments for which the carrying amount did not equal fair value were as follows:

	June 30, 2017				Dec. 31, 2016
(Thousands of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	663,402	$	747,072	$	663,069	$	730,284

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, 2017 and Dec. 31, 2016, 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, Net

Other income, net consisted of the following:

	Three Months Ended June 30						Six Months Ended June 30
(Thousands of Dollars)	2017			2016			2017			2016
Interest income	$	61		$	14		$	204		$	138
Other nonoperating income	75			108			230			266
Insurance policy (expense) income	(49		)	(42		)	(98		)	128
Other nonoperating expense	(4		)	(3		)	(7		)	(6		)
Other income, net	$	83		$	77		$	329		$	526

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, transmits and distributes electricity primarily in portions of Wisconsin and Michigan. 

• NSP-Wisconsin’s regulated natural gas utility segment purchases, transports, stores and distributes natural gas primarily 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 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 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.

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(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2017
Operating revenues (a)	$	210,742	$	19,027		$	257	$	—		$	230,026
Intersegment revenues	123		68			—		(191		)	—
Total revenues	$	210,865	$	19,095		$	257	$	(191	)	$	230,026
Net income (loss)	$	14,516	$	(973	)	$	698	$	—		$	14,241

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other			Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2016
Operating revenues (a)	$	202,879	$	16,005		$	289		$	—		$	219,173
Intersegment revenues	98		122			—			(220		)	—
Total revenues	$	202,977	$	16,127		$	289		$	(220	)	$	219,173
Net income (loss)	$	15,098	$	(2,465	)	$	(8	)	$	—		$	12,625

^(a)  Operating revenues include $43 million of affiliate electric revenue for the three months ended June 30, 2017 and 2016.

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2017
Operating revenues (a)	$	427,051	$	67,374	$	532	$	—		$	494,957
Intersegment revenues	219		182		—		(401		)	—
Total revenues	$	427,270	$	67,556	$	532	$	(401	)	$	494,957
Net income	$	29,986	$	5,572	$	1,102	$	—		$	36,660

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2016
Operating revenues (a)	$	414,403	$	59,025	$	595	$	—		$	474,023
Intersegment revenues	207		202		—		(409		)	—
Total revenues	$	414,610	$	59,227	$	595	$	(409	)	$	474,023
Net income	$	26,599	$	3,627	$	30	$	—		$	30,256

^(a)  Operating revenues include $85 million and $84 million of affiliate electric revenue for the six months endedJune 30, 2017 and 2016, respectively.

11. Benefit Plans and Other Postretirement Benefits

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2017			2016			2017			2016
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	1,155		$	1,104		$	7		$	6
Interest cost	1,555			1,704			148			163
Expected return on plan assets	(2,295		)	(2,289		)	(8		)	(6		)
Amortization of prior service cost (credit)	34			28			(88		)	(88		)
Amortization of net loss	1,461			1,348			109			83
Net benefit cost recognized for financial reporting	$	1,910		$	1,895		$	168		$	158

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	Six Months Ended June 30
	2017			2016			2017			2016
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	2,309		$	2,208		$	14		$	12
Interest cost	3,109			3,408			296			326
Expected return on plan assets	(4,590		)	(4,578		)	(16		)	(12		)
Amortization of prior service cost (credit)	69			56			(176		)	(176		)
Amortization of net loss	2,923			2,696			218			166
Net benefit cost recognized for financial reporting	$	3,820		$	3,790		$	336		$	316

In January 2017, contributions of $150.0 million were made across four of Xcel Energy’s pension plans, of which $9.0 million was attributable to NSP-Wisconsin. Xcel Energy does not expect additional pension contributions during 2017.

12. Other Comprehensive Income

Changes in accumulated other comprehensive loss, net of tax, for the three and six months ended June 30, 2017 and 2016 were as follows:

	Gains and Losses on Cash Flow Hedges
(Thousands of Dollars)	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016
Accumulated other comprehensive loss at April 1	$	(114	)	$	(190	)
Losses reclassified from net accumulated other comprehensive loss	19			19
Net current period other comprehensive income	19			19
Accumulated other comprehensive loss at June 30	$	(95	)	$	(171	)

	Gains and Losses on Cash Flow Hedges
(Thousands of Dollars)	Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
Accumulated other comprehensive loss at Jan. 1	$	(133	)	$	(209	)
Losses reclassified from net accumulated other comprehensive loss	38			38
Net current period other comprehensive income	38			38
Accumulated other comprehensive loss at June 30	$	(95	)	$	(171	)

Reclassifications from accumulated other comprehensive loss for the three and six months ended June 30, 2017 and 2016 were as follows:

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Three Months Ended June 30, 2017				Three Months Ended June 30, 2016
Losses on cash flow hedges:
Interest rate derivatives	$	31		(a)	$	31		(a)
Total, pre-tax	31				31
Tax benefit	(12		)		(12		)
Total amounts reclassified, net of tax	$	19			$	19

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	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Six Months Ended June 30, 2017				Six Months Ended June 30, 2016
Losses on cash flow hedges:
Interest rate derivatives	$	62		(a)	$	63		(a)
Total, pre-tax	62				63
Tax benefit	(24		)		(25		)
Total amounts reclassified, net of tax	$	38			$	38

^(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 herein, 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 expressly disclaim any obligation to update any forward-looking information. The following factors, in addition to those discussed elsewhere in this Quarterly Report on Form 10-Q and in other securities filings (including NSP-Wisconsin’s Annual Report on Form 10-K for the fiscal year ended Dec. 31, 2016 and subsequent securities filings), could cause actual results to differ materially from management expectations as suggested by such forward-looking information: 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; cyber security threats and data security breaches; 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; financial or regulatory accounting policies imposed by regulatory bodies; outcomes of regulatory proceedings; availability or cost of capital; and employee work force factors.

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Results of Operations

NSP-Wisconsin’s net income was approximately $36.7 million for 2017 year-to-date compared with approximately $30.3 million for the same period of 2016. The increase is due to higher electric margins primarily driven by rate increases partially offset by additional depreciation.

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)	2017			2016
Electric revenues	$	427		$	414
Electric fuel and purchased power	(215		)	(213		)
Electric margin	$	212		$	201

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

June 30, 2017:

Electric Revenues

(Millions of Dollars)	2017 vs. 2016
Retail rate increase	$	7
Fuel and purchased power cost recovery	5
Other, net	1
Total increase in electric revenues	$	13

Electric Margin

(Millions of Dollars)	2017 vs. 2016
Retail rate increase	$	7
Interchange agreement billings with NSP-Minnesota	6
Other, net	(2		)
Total increase in electric margin	$	11

Natural Gas Revenues and Margin

Total natural gas expense 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)	2017			2016
Natural gas revenues	$	67		$	59
Cost of natural gas sold and transported	(35		)	(30		)
Natural gas margin	$	32		$	29

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The following tables summarize the components of the changes in natural gas revenues and natural gas margin for the six months endedJune 30, 2017:

Natural Gas Revenues

(Millions of Dollars)	2017 vs. 2016
Purchased natural gas adjustment clause recovery	$	5
Retail rate increase	2
Estimated impact of weather	1
Total increase in natural gas revenues	$	8

Natural Gas Margin

(Millions of Dollars)	2017 vs. 2016
Retail rate increase	$	2
Estimated impact of weather	1
Total increase in natural gas margin	$	3

Non-Fuel Operating Expenses and Other Items

Depreciation and Amortization — Depreciation and amortization increased $6.5 million, or 13.5 percent, for 2017 year-to-date. The increase was primarily attributable to capital investments.

Income Taxes — Income tax expense increased $3.7 million for 2017 year-to-date. The increase in income tax expense was primarily due to higher pretax earnings in 2017. The ETR was 38.0 percent for 2017 year-to-date, compared with 38.3 percent for the same period in 2016.

Public Utility Regulation

Except to the extent noted below, the circumstances set forth in Public Utility Regulation included in Item 1 of NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2016 and Public Utility Regulation included in Item 2 of NSP-Wisconsin’s

Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017, appropriately represent, in all material respects, the current status of public utility regulation and are incorporated herein by reference.

NSP-Wisconsin / American Transmission Company, LLC (ATC) - La Crosse to Madison, Wis. Transmission Line — In 2013, NSP-Wisconsin and ATC jointly filed an application with the PSCW for a certificate of public convenience and necessity (CPCN) for a new 345 kilovolt transmission line that would extend from La Crosse, Wis. to Madison, Wis.  NSP-Wisconsin’s half of the line will be shared with three co-owners, Dairyland Power Cooperative, WPPI Energy and Southern Minnesota Municipal Power Agency-Wisconsin.

In 2015, the PSCW issued its order approving a CPCN and route for the project. Two groups have appealed the CPCN order to the La Crosse County Circuit Court (Circuit Court). In May 2017, the Circuit Court determined that the project was necessary, allowing construction to continue on a seven mile segment near La Crosse, Wis. The parties have appealed various aspects of the case to the Wisconsin Court of Appeals, which is currently pending. The CPCN remains in full effect unless one of the parties seeks and receives a stay from the court and posts a bond to cover damages the utilities may incur due to delay. The 180-mile project is expected to cost approximately $541 million. NSP-Wisconsin’s portion of the investment, which includes allowance for funds used during construction, is estimated to be approximately $200 million. Construction on the line began in January 2016, with completion anticipated by late 2018.

2016 Electric Fuel Cost Recovery — NSP-Wisconsin’s electric fuel costs for the year ended Dec. 31, 2016 were lower than authorized in rates and outside the two percent annual tolerance band established in the Wisconsin fuel cost recovery rules, primarily due to lower sales volume and lower purchased power costs coupled with moderate weather. Under the fuel cost recovery rules, NSP-Wisconsin may retain the amount of over-recovery up to two percent of authorized annual fuel costs, or approximately $3.4 million. However, NSP-Wisconsin must defer the amount of over-recovery in excess of the two percent annual tolerance band for future refund to customers. In July 2017, the PSCW required NSP-Wisconsin to provide a refund of $9.5 million to customers, which is expected to start in September 2017.

21

2017 Electric Fuel Cost Recovery — NSP-Wisconsin’s electric fuel costs for the six months ended June 30, 2017 were lower than authorized in rates and outside the two percent annual tolerance band established in the Wisconsin fuel cost recovery rules, primarily due to lower sales volume and lower purchased power costs coupled with moderate weather and generation sales into the MISO market.  Under the fuel cost recovery rules, NSP-Wisconsin may retain the amount of over-recovery up to two percent of authorized annual fuel costs, or approximately $3.7 million.  However, NSP-Wisconsin must defer the amount of over-recovery in excess of the two percent annual tolerance band for future refund to customers.  Accordingly, NSP-Wisconsin recorded a deferral of approximately $3.0 million through June 30, 2017.  The amount of the deferral could increase or decrease based on actual fuel costs incurred for the remainder of the year.  In the first quarter of 2018, NSP-Wisconsin will file a reconciliation of 2017 fuel costs with the PSCW.  The amount of any potential refund is subject to review and approval by the PSCW, which is not expected until mid-2018.

Summary of Recent Federal Regulatory Developments

FERC

The FERC has jurisdiction over rates for electric transmission service in interstate commerce and electricity sold at wholesale, hydro facility licensing, natural gas transportation, asset transactions and mergers, 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, 2016 and Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017. In addition to the matters discussed below, see Note 5 to the consolidated financial statements for a discussion of other regulatory matters.

Status of FERC Commissioners — The FERC is normally comprised of five commissioners appointed by the President and confirmed by the Senate. There is currently only one sitting commissioner.  Without three commissioners, the FERC does not have a quorum to act on contested matters. The lack of a quorum could affect the timing of FERC decisions on proposed rules or pending, newly submitted and future filings involving, among other things, contested electric rate matters and CPCNs for construction of interstate natural gas pipeline facilities to serve the utility subsidiaries.  NSP-Wisconsin does not expect any disruption in operations or material delay in decisions on contested matters pending before the FERC. President Trump has submitted nominations to fill three of the vacant seats and has indicated his intent to submit one additional nomination. The three submitted nominations are pending confirmation by the full Senate.

FERC ROE Policy — In June 2014, the FERC adopted a two-step ROE methodology for electric utilities in an order issued in a complaint proceeding involving New England Transmission Owners (NETOs). The issue of how to apply the FERC ROE methodology has been contested in various complaint proceedings, including two ROE complaints involving the MISO TOs, which includes NSP-Minnesota and NSP-Wisconsin. In April 2017, the D.C. Circuit vacated and remanded the June 2014 ROE order. The D.C. Circuit found that the FERC had not properly determined that the ROE authorized for NETOs prior to June 2014 was unjust and unreasonable. The D.C. Circuit also found that the FERC failed to justify the new ROE methodology. The FERC has yet to act on the D.C. Circuit’s decision and cannot act without a quorum. See Note 5 to the consolidated financial statements for discussion of the D.C. Circuit’s decision and the impact on the MISO ROE Complaints.

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 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, 2017, 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.

22

Internal Control Over Financial Reporting

In 2016, NSP-Wisconsin implemented the general ledger modules, as well as initiated deployment of work management systems modules, of a new enterprise resource planning system to improve certain financial and related transaction processes. NSP-Wisconsin is continuing to implement additional modules including the conversion of existing work management systems to this same system during 2017. In connection with this ongoing implementation, NSP-Wisconsin is updating its internal control over financial reporting, as necessary, to accommodate modifications to its business processes and accounting systems. NSP-Wisconsin does not believe that this implementation will have an adverse effect on its internal control over financial reporting.

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

Part II — OTHER INFORMATION

Item 1 — LEGAL PROCEEDINGS

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.

Additional Information

See Note 6 to the consolidated financial statements for further discussion of legal claims and environmental proceedings. See Part I Item 2 and Note 5 to the consolidated financial statements for a discussion of proceedings involving utility rates and other regulatory matters.

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, 2016, which is incorporated herein by reference. There have been no material changes from the risk factors previously disclosed in the Form 10-K.

Item 6 — EXHIBITS

*	Indicates incorporation by reference
+	Executive Compensation Arrangements and Benefit Plans Covering Executive Officers and Directors

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 Northern States Power Co. (a Wisconsin corporation) as Amended and Restated on Sept. 26, 2013. (Exhibit 3.02 to Form 10-Q/A for the quarter ended Sept. 30, 2013 (file no. 001-03140)).
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, 2017 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 Consolidated Financial Statements, and (vi) document and entity information.

23

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)
July 28, 2017	By:	/s/ JEFFREY S. SAVAGE
		Jeffrey S. Savage
		Senior Vice President, Controller
		(Principal Accounting Officer)
		/s/ ROBERT C. FRENZEL
		Robert C. Frenzel
		Executive Vice President, Chief Financial Officer and Director
		(Principal Financial Officer)

24

EX-31.01

Exhibit 31.01

CERTIFICATION

I, Ben Fowke, 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: July 28, 2017

/s/ BEN FOWKE

Ben Fowke

Chairman, Chief Executive Officer and Director

(Principal Executive Officer)

1

EX-31.02

Exhibit 31.02

CERTIFICATION

I, Robert C. Frenzel, 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: July 28, 2017

/s/ ROBERT C. FRENZEL

Robert C. Frenzel

Executive Vice President, Chief Financial Officer and Director

(Principal Financial Officer)

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, 2017, 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: July 28, 2017

/s/ BEN FOWKE

Ben Fowke

Chairman, Chief Executive Officer and Director

(Principal Executive Officer)

/s/ ROBERT C. FRENZEL

Robert C. Frenzel

Executive Vice President, Chief Financial Officer and Director

(Principal Financial Officer)

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 of cost or 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, 2016, 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

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Jul. 28, 2017
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, 2017
Document Fiscal Year Focus	2017
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

XML

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Operating revenues
Electric	$ 210,742	$ 202,879	$ 427,051	$ 414,403
Natural gas	19,027	16,005	67,374	59,025
Other	257	289	532	595
Total operating revenues	230,026	219,173	494,957	474,023
Operating expenses
Electric fuel and purchased power, non-affiliates	3,583	3,651	6,456	7,632
Purchased power, affiliates	101,793	96,853	208,251	205,567
Cost of natural gas sold and transported	8,563	6,465	34,550	29,883
Operating and maintenance expenses	49,210	50,516	99,072	99,135
Conservation expenses	3,177	3,094	6,231	6,160
Depreciation and amortization	27,628	23,720	54,677	48,169
Taxes (other than income taxes)	7,005	7,096	13,878	14,251
Total operating expenses	200,959	191,395	423,115	410,797
Operating income	29,067	27,778	71,842	63,226
Other income, net	83	77	329	526
Allowance for funds used during construction — equity	1,751	918	3,038	1,728
Interest charges and financing costs
Interest charges — includes other financing costs of $461, $461, $917 and $923, respectively	8,656	8,583	17,338	17,187
Allowance for funds used during construction — debt	(749)	(392)	(1,299)	(739)
Total interest charges and financing costs	7,907	8,191	16,039	16,448
Income before income taxes	22,994	20,582	59,170	49,032
Income taxes	8,753	7,957	22,510	18,776
Net income	$ 14,241	$ 12,625	$ 36,660	$ 30,256

XML

CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Interest charges and financing costs
Other financing costs	$ 461	$ 461	$ 917	$ 923

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Comprehensive income:
Net income	$ 14,241	$ 12,625	$ 36,660	$ 30,256
Derivative instruments:
Reclassification of losses to net income, net of tax of $12, $12, $24 and $25, respectively	19	19	38	38
Other comprehensive income	19	19	38	38
Comprehensive income	$ 14,260	$ 12,644	$ 36,698	$ 30,294

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Derivative instruments:
Reclassification of losses to net income, tax	$ 12	$ 12	$ 24	$ 25

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Operating activities
Net income	$ 36,660	$ 30,256
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	55,434	48,929
Deferred income taxes	22,588	15,188
Amortization of investment tax credits	(262)	(264)
Allowance for equity funds used during construction	(3,038)	(1,728)
Net derivative losses	115	138
Other, net	(1,505)	0
Changes in operating assets and liabilities:
Accounts receivable	(295)	4,599
Accrued unbilled revenues	10,846	6,072
Inventories	2,669	5,429
Other current assets	(58)	329
Accounts payable	28,882	12,907
Net regulatory assets and liabilities	(3,112)	1,555
Other current liabilities	(9,191)	589
Pension and other employee benefit obligations	(8,735)	(6,848)
Change in other noncurrent assets	(359)	(393)
Change in other noncurrent liabilities	(2,696)	555
Net cash provided by operating activities	127,943	117,313
Investing activities
Utility capital/construction expenditures	(90,735)	(87,791)
Allowance for equity funds used during construction	3,038	1,728
Other, net	(33)	687
Net cash used in investing activities	(87,730)	(85,376)
Financing activities
Repayments of short-term borrowings, net	(14,000)	(2,000)
Repayments of long-term debt	(27)	(29)
Capital contributions from (to) parent	12,282	(1,545)
Dividends paid to parent	(38,800)	(27,850)
Other, net	(70)	0
Net cash used in financing activities	(40,615)	(31,424)
Net change in cash and cash equivalents	(402)	513
Cash and cash equivalents at beginning of period	1,546	1,079
Cash and cash equivalents at end of period	1,144	1,592
Supplemental disclosure of cash flow information:
Cash paid for interest (net of amounts capitalized)	(15,062)	(15,718)
Cash paid for income taxes, net	(9,699)	(3,336)
Supplemental disclosure of non-cash investing transactions:
Property, plant and equipment additions in accounts payable	$ 21,867	$ 10,220

XML

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Current assets
Cash and cash equivalents	$ 1,144	$ 1,546
Accounts receivable, net	54,340	54,031
Accrued unbilled revenues	42,792	53,638
Inventories	15,640	18,309
Regulatory assets	18,161	18,162
Prepaid taxes	26,244	25,915
Prepayments and other	3,434	3,785
Total current assets	161,755	175,386
Property, plant and equipment, net	2,000,347	1,947,637
Other assets
Regulatory assets	274,107	286,188
Other investments	2,876	2,844
Other	1,143	785
Total other assets	278,126	289,817
Total assets	2,440,228	2,412,840
Current liabilities
Current portion of long-term debt	1,096	1,123
Short-term debt	46,000	60,000
Notes payable to affiliates	500	500
Accounts payable	48,670	41,068
Accounts payable to affiliates	53,294	29,037
Dividends payable to parent	13,840	10,729
Regulatory liabilities	24,140	17,428
Environmental liabilities	29,752	41,438
Accrued interest	8,083	8,012
Other	16,651	26,484
Total current liabilities	242,026	235,819
Deferred credits and other liabilities
Deferred income taxes	454,839	430,593
Deferred investment tax credits	7,775	8,037
Regulatory liabilities	152,588	148,189
Environmental liabilities	17,146	23,003
Customer advances	16,759	19,425
Pension and employee benefit obligations	46,281	55,164
Other	18,857	18,814
Total deferred credits and other liabilities	714,245	703,225
Commitments and contingencies
Capitalization
Long-term debt	662,306	661,946
Common stock — 1,000,000 shares authorized of $100 par value; 933,000 shares outstanding at June 30, 2017 and Dec. 31, 2016, respectively	93,300	93,300
Additional paid in capital	410,329	395,315
Retained earnings	318,117	323,368
Accumulated other comprehensive loss	(95)	(133)
Total common stockholder’s equity	821,651	811,850
Total liabilities and equity	$ 2,440,228	$ 2,412,840

XML

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - $ / shares	Jun. 30, 2017	Dec. 31, 2016
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

XML

Management's Opinion

6 Months Ended

Jun. 30, 2017

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, 2017 and Dec. 31, 2016; the results of its operations, including the components of net income and comprehensive income, for the three and six months ended June 30, 2017 and 2016; and its cash flows for the six months ended June 30, 2017 and 2016. All adjustments are of a normal, recurring nature, except as otherwise disclosed. Management has also evaluated the impact of events occurring after June 30, 2017 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, 2016 balance sheet information has been derived from the audited 2016 consolidated financial statements included in the NSP-Wisconsin Annual Report on Form 10-K for the year ended Dec. 31, 2016. 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, 2016, filed with the SEC on Feb. 24, 2017. 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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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2017

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, 2016, appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference.

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Accounting Pronouncements

6 Months Ended

Jun. 30, 2017

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Accounting Pronouncements

Accounting Pronouncements

Recently Issued

Revenue Recognition— In May 2014, the Financial Accounting Standards Board (FASB) issued Revenue from Contracts with Customers, Topic 606 (Accounting Standards Update (ASU) No. 2014-09), which provides a new framework for the recognition of revenue. NSP-Wisconsin expects its adoption will result in increased disclosures regarding revenue, cash flows and obligations related to arrangements with customers, as well as separate presentation of alternative revenue programs. NSP-Wisconsin has not yet fully determined the impacts of adoption for several aspects of the standard, including a determination whether and how much an evaluation of the collectability of regulated electric and gas revenues will impact the amounts of revenue recognized upon delivery. NSP-Wisconsin currently expects to implement the standard on a modified retrospective basis, which requires application to contracts with customers effective Jan. 1, 2018, with the cumulative impact on contracts not yet completed as of Dec. 31, 2017 recognized as an adjustment to the opening balance of retained earnings.

Classification and Measurement of Financial Instruments — In January 2016, the FASB issued Recognition and Measurement of Financial Assets and Financial Liabilities, Subtopic 825-10 (ASU No. 2016-01), which eliminates the available-for-sale classification for marketable equity securities and also replaces the cost method of accounting for non-marketable equity securities with a model for recognizing impairments and observable price changes. Under the new standard, other than when the consolidation or equity method of accounting is utilized, changes in the fair value of equity securities are to be recognized in earnings. This guidance will be effective for interim and annual reporting periods beginning after Dec. 15, 2017. NSP-Wisconsin expects that the overall impacts of the Jan. 1, 2018 adoption will not be material.

Leases —In February 2016, the FASB issued Leases, Topic 842 (ASU No. 2016-02), which for lessees requires balance sheet recognition of right-of-use assets and lease liabilities for most leases. This guidance will be effective for interim and annual reporting periods beginning after Dec. 15, 2018. NSP-Wisconsin has not yet fully determined the impacts of implementation. However, adoption is expected to occur on Jan. 1, 2019 utilizing the practical expedients provided by the standard. As such, agreements entered prior to Jan. 1, 2017 that are currently considered leases are expected to be recognized on the consolidated balance sheet, including contracts for use of office space, equipment and natural gas storage assets, as well as certain purchased power agreements (PPAs) for natural gas-fueled generating facilities. NSP-Wisconsin expects that similar agreements entered after Dec. 31, 2016 will generally qualify as leases under the new standard, but has not yet completed its evaluation of certain other contracts, including arrangements for the secondary use of assets, such as land easements.

Presentation of Net Periodic Benefit Cost —In March 2017, the FASB issued Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost, Topic 715 (ASU No. 2017-07), which establishes that only the service cost element of pension cost may be presented as a component of operating income in the income statement. Also under the guidance, only the service cost component of pension cost is eligible for capitalization. NSP-Wisconsin has not yet fully determined the impacts of adoption of the standard, but expects that as a result of application of accounting principles for rate regulated entities, a similar amount of pension cost, including non-service components, will be recognized consistent with the current ratemaking treatment and that the impacts of adoption will be limited to changes in classification of non-service costs in the consolidated statement of income. This guidance will be effective for interim and annual reporting periods beginning after Dec. 15, 2017.

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Selected Balance Sheet Data

6 Months Ended

Jun. 30, 2017

Balance Sheet Related Disclosures [Abstract]

Selected Balance Sheet Data

Selected Balance Sheet Data

(Thousands of Dollars)	June 30, 2017			Dec. 31, 2016
Accounts receivable, net (a)
Accounts receivable	$	58,587		$	58,896
Less allowance for bad debts	(4,247		)	(4,865		)
	$	54,340		$	54,031

^(a)  Accounts receivable, net includes an immaterial amount due from affiliates as of June 30, 2017 and Dec. 31, 2016, respectively.

(Thousands of Dollars)	June 30, 2017		Dec. 31, 2016
Inventories
Materials and supplies	$	7,117	$	6,582
Fuel	4,615		4,743
Natural gas	3,908		6,984
	$	15,640	$	18,309

(Thousands of Dollars)	June 30, 2017			Dec. 31, 2016
Property, plant and equipment, net
Electric plant	$	2,534,258		$	2,499,401
Natural gas plant	307,217			294,986
Common and other property	170,486			156,316
Construction work in progress	145,458			118,822
Total property, plant and equipment	3,157,419			3,069,525
Less accumulated depreciation	(1,157,072		)	(1,121,888		)
	$	2,000,347		$	1,947,637

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Income Taxes

6 Months Ended

Jun. 30, 2017

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

Except to the extent noted below, Note 6 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2016 appropriately represents, in all material respects, the current status of other income tax matters, and are incorporated herein by reference.

Federal Audits— 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 2009 through 2013 federal income tax returns, following extensions, expires in December 2017.

In 2012, the Internal Revenue Service (IRS) commenced an examination of tax years 2010 and 2011, including a 2009 carryback claim. The IRS has proposed an adjustment to the federal tax loss carryback claims that would result in $14 million of income tax expense for the 2009 through 2011 claims, and the 2013 through 2015 claims. In 2016 the IRS audit team and Xcel Energy presented their cases to the Office of Appeals; however, the outcome and timing of a resolution is uncertain. NSP-Wisconsin is not expected to accrue any income tax expense related to this adjustment.

In the third quarter of 2015, the IRS commenced an examination of tax years 2012 and 2013. In the second quarter of 2017, the IRS proposed an adjustment to tax year 2012 that may impact Xcel Energy’s net operating loss (NOL) and effective tax rate (ETR). Xcel Energy is evaluating the IRS’ proposal and the outcome and timing of a resolution is uncertain.

State Audits— NSP-Wisconsin is a member of the Xcel Energy affiliated group that files consolidated state income tax returns. As of June 30, 2017, NSP-Wisconsin’s earliest open tax year that is subject to examination by state taxing authorities under applicable statutes of limitations is 2012. In 2016, Wisconsin began an audit of years 2012 and 2013. As of June 30, 2017, Wisconsin had not proposed any material adjustments, and there were no other state income tax audits in progress.

Unrecognized Benefits— The unrecognized tax benefit balance includes permanent tax positions, which if recognized would affect the annual 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, 2017		Dec. 31, 2016
Unrecognized tax benefit — Permanent tax positions	$	0.4	$	0.4
Unrecognized tax benefit — Temporary tax positions	5.1		4.9
Total unrecognized tax benefit	$	5.5	$	5.3

The unrecognized tax benefit amounts were reduced by the tax benefits associated with 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, 2017			Dec. 31, 2016
NOL and tax credit carryforwards	$	(1.3	)	$	(1.2	)

It is reasonably possible that NSP-Wisconsin’s amount of unrecognized tax benefits could significantly change in the next 12 months as the IRS Appeals and audit progress, the Wisconsin audit progresses, and other state audits resume. As the IRS Appeals and IRS and Wisconsin audits progress, it is reasonably possible that the amount of unrecognized tax benefit could decrease up to approximately $2 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, 2017 and Dec. 31, 2016 were not material. No amounts were accrued for penalties related to unrecognized tax benefits as of June 30, 2017 or Dec. 31, 2016.

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Rate Matters Rate Matters

6 Months Ended

Jun. 30, 2017

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, 2016 and in Note 5 to NSP-Wisconsin’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2017, appropriately represent, in all material respects, the current status of other rate matters, and are incorporated herein by reference.

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

Wisconsin 2018 Electric and Natural Gas Rate Case— In May 2017, NSP-Wisconsin filed a request with the PSCW to increase electric rates by $24.7 million, or 3.6 percent, and natural gas rates by $12.0 million, or 10.1 percent, effective January 2018. The rate filing is based on a 2018 forecast test year, a return on equity (ROE) of 10.0 percent, an equity ratio of 52.53 percent and a forecasted average net investment rate base of approximately $1.2 billion for the electric utility and $138.4 million for the natural gas utility.

Key dates in the procedural schedule are as follows:

• Staff and intervenor testimony — Sept. 12, 2017;

• Rebuttal testimony — Sept. 26, 2017;

• Sur-rebuttal testimony — Oct. 3, 2017; and

• Hearing — Oct. 5, 2017.

A PSCW decision is anticipated in the fourth quarter of 2017.

Pending Regulatory Proceeding — Federal Energy Regulatory Commission (FERC)

Midcontinent Independent System Operator, Inc. (MISO) ROE Complaints — In November 2013, a group of customers filed a complaint at the FERC against MISO transmission owners (TOs), including NSP-Minnesota and NSP-Wisconsin. The complaint argued for a reduction in the ROE in transmission formula rates in the MISO region from 12.38 percent to 9.15 percent, and the removal of ROE adders (including those for Regional Transmission Organization (RTO) membership), effective Nov. 12, 2013.

In December 2015, an administrative law judge (ALJ) recommended the FERC approve a base ROE of 10.32 percent for the MISO TOs. The ALJ found the existing 12.38 percent ROE to be unjust and unreasonable. The recommended 10.32 percent ROE applied a FERC ROE policy adopted in a June 2014 order (Opinion 531). The FERC approved the ALJ recommended 10.32 percent base ROE in an order issued in September 2016. This ROE would be applicable for the 15-month refund period from Nov. 12, 2013 to Feb. 11, 2015, and prospectively from the date of the FERC order. The total prospective ROE would be 10.82 percent, including a 50 basis point adder for RTO membership. Various parties requested rehearing of the September 2016 order. The requests are pending FERC action.

In February 2015, a second complaint seeking to reduce the MISO ROE from 12.38 percent to 8.67 percent prior to any adder was filed with the FERC, resulting in a second period of potential refund from Feb. 12, 2015 to May 11, 2016. In June 2016, the ALJ recommended a ROE of 9.7 percent, applying the methodology adopted by the FERC in Opinion 531. A final FERC decision on the second ROE complaint was expected later in 2017, but in April 2017, the United States Court of Appeals for the District of Columbia Circuit (D.C. Circuit) by opinion, vacated and remanded Opinion 531. It is unclear how the D.C. Circuit’s opinion to vacate and remand Opinion 531 will affect the September 2016 FERC order or the timing and outcome of the second ROE complaint. The MISO TOs are evaluating the impact of the D.C. Circuit ruling on the November 2013 and February 2015 ROE complaints.

As of June 30, 2017, NSP-Minnesota has processed refunds for the Nov. 12, 2013 to Feb. 11, 2015 complaint period based on the 10.32 percent ROE provided in the September 2016 FERC order. NSP-Minnesota has also recognized a current liability representing the best estimate of the final ROE for the Feb. 12, 2015 to May 11, 2016 complaint period.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Except to the extent noted below and in Note 5 above, the circumstances set forth in Notes 10 and 11 to the consolidated financial statements included in NSP-Wisconsin’s Annual Report on Form 10-K for the year ended Dec. 31, 2016 and in Notes 5 and 6 the consolidated financial statements included in NSP-Wisconsin’s Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2016, 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 has a stated maximum amount. The guarantee contains no recourse provisions and requires no collateral. These agreements have expiration dates through 2020.

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

(Millions of Dollars)	June 30, 2017		Dec. 31, 2016
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under this guarantee	—		0.1

Environmental Contingencies

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

In 2012, NSP-Wisconsin agreed to remediate the Phase I Project Area (which includes the Upper Bluff and Kreher Park areas of the Site), under a settlement agreement with the United States Environmental Protection Agency (EPA).

NSP-Wisconsin performed a wet dredge pilot study in 2016 and demonstrated that a wet dredge remedy can meet the performance standards for remediation of the Phase II Project Area (the Sediments). As a result, the EPA authorized NSP-Wisconsin to extend the wet dredge pilot to additional areas of the Site. In January 2017, NSP-Wisconsin agreed to remediate the Sediments, under a settlement agreement with the EPA. The settlement was approved by the U.S. District Court for the Western District of Wisconsin NSP-Wisconsin has initiated field activities to perform a full scale wet dredge remedy of the Sediments in 2017, with performance of restoration activities in 2018.

The current cost estimate for the entire site is approximately $160.0 million, of which approximately $113.2 million has been spent. At June 30, 2017 and Dec. 31, 2016, NSP-Wisconsin had recorded a total liability of $46.8 million and $64.3 million, respectively, for the entire site.

NSP-Wisconsin has deferred the unrecovered portion of the estimated Site remediation costs as a regulatory asset. The PSCW has authorized NSP-Wisconsin rate recovery for all remediation costs incurred at the Site. In 2012, the PSCW agreed to allow NSP-Wisconsin to pre-collect certain costs, to amortize costs over a ten-year period and to apply a three percent carrying cost to the unamortized regulatory asset. In May 2017, NSP-Wisconsin filed a natural gas rate case which included recovery of additional expenses associated with remediating the Site. If approved, the annual recovery of MGP clean-up costs would increase from $12.4 million in 2017 to $18.1 million in 2018.

Other MGP Sites — In addition to the site in Ashland, Wis., NSP-Wisconsin has identified one site where former MGP disposal activities may have resulted in site contamination and is under current investigation. There are other parties that may have responsibility for some portion of any remediation. NSP-Wisconsin anticipates that the majority of the investigation or remediation at this site will continue through at least 2018. NSP-Wisconsin had accrued $0.1 million for this site at June 30, 2017 and Dec. 31, 2016. There may be insurance recovery and/or recovery from other PRPs to offset any costs incurred. NSP-Wisconsin anticipates that any significant amounts incurred will be recovered from customers.

Environmental Requirements

Water and Waste

Federal Clean Water Act (CWA) Waters of the United States Rule — In 2015, the EPA and the U.S. Army Corps of Engineers (Corps) published a final rule that significantly expands the types of water bodies regulated under the CWA and broadens the scope of waters subject to federal jurisdiction. The final rule will subject more utility projects to federal CWA jurisdiction, thereby potentially delaying the siting of new generation projects, pipelines, transmission lines and distribution lines, as well as increasing project costs and expanding permitting and reporting requirements. In October 2015, the U.S. Court of Appeals for the Sixth Circuit issued a nationwide stay of the final rule and subsequently ruled that it, rather than the federal district courts, had jurisdiction over challenges to the rule.  In January 2017, the U.S. Supreme Court agreed to resolve the dispute as to which court should hear challenges to the rule. A ruling is expected by the end of 2017.

In February 2017, President Trump issued an executive order requiring the EPA and the Corps to review and revise the final rule. On June 27, 2017, the agencies issued a proposed rule that rescinds the 2015 final rule and reinstates the prior 1986 definition of “Water of the U.S.”

Air

Greenhouse Gas (GHG) Emission Standard for Existing Sources (Clean Power Plan or CPP) — In 2015, the EPA issued its final rule for existing power plants.  Among other things, the rule requires that state plans include enforceable measures to ensure emissions from existing power plants achieve the EPA’s state-specific interim (2022-2029) and final (2030 and thereafter) emission performance targets. 

The CPP was challenged by multiple parties in the D.C. Circuit Court.  In February 2016, the U.S. Supreme Court issued an order staying the final CPP rule. In September 2016, the D.C. Circuit Court heard oral arguments in the consolidated challenges to the CPP. The stay will remain in effect until the D.C. Circuit Court reaches its decision and the U.S. Supreme Court either declines to review the lower court’s decision or reaches a decision of its own.

In March 2017, President Trump signed an executive order requiring the EPA Administrator to review the CPP rule and if appropriate, publish proposed rules suspending, revising or rescinding it. Accordingly, the EPA has requested that the D.C. Circuit Court hold the litigation in abeyance until the EPA completes its work under the executive order. The D.C. Circuit granted the EPA’s request to hold the litigation in abeyance until June 27, 2017, and is considering briefs by the parties on whether the court should remand the challenges to the EPA rather than holding them in abeyance, to determine whether and how the court continues or ends the stay that currently applies to the CPP. On June 9, 2017, the EPA submitted a proposed rule to the Office of Management and Budget entitled “Review of the Clean Power Plan.”

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.

Employment, Tort and Commercial Litigation

Gas Trading Litigation — e prime, inc. (e prime) is a wholly owned subsidiary of Xcel Energy. e prime was in the business of natural gas trading and marketing but has not engaged in natural gas trading or marketing activities since 2003.  Thirteen lawsuits were commenced against e prime and Xcel Energy (and NSP-Wisconsin, in two instances) between 2003 and 2009 alleging fraud and anticompetitive activities in conspiring to restrain the trade of natural gas and manipulate natural gas prices.

The cases were consolidated in U.S. District Court in Nevada. Five of the cases have since been settled and seven remain active, which includes one multi-district litigation (MDL) matter consisting of a Colorado class (Breckenridge), a Wisconsin class (NSP-Wisconsin), a Kansas class, and two other cases identified as “Sinclair Oil” and “Farmland.” In November 2016, the MDL judge dismissed e prime and Xcel Energy from the Farmland lawsuit, and Farmland has appealed the dismissal. Motions for summary judgment were filed by defendants, including e prime, in all of the remaining lawsuits. In March 2017, the U.S. District Court issued an order dismissing the claims against e prime in the Sinclair Oil lawsuit and denied plaintiffs motions for class certification in the other lawsuits. The U.S. District Court did not grant e prime’s summary judgment motions in the Wisconsin or Colorado cases. There are currently additional motions brought by e prime for reconsideration and summary judgment pending in the U.S. District Court. Xcel Energy, NSP-Wisconsin and e prime have concluded that a loss is remote.

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Borrowings and Other Financing Instruments

6 Months Ended

Jun. 30, 2017

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, 2017			Year Ended Dec. 31, 2016
Borrowing limit	$	150		$	150
Amount outstanding at period end	46			60
Average amount outstanding	26			15
Maximum amount outstanding	49			64
Weighted average interest rate, computed on a daily basis	1.15		%	0.69		%
Weighted average interest rate at period end	1.36			0.95

Letters of Credit— NSP-Wisconsin uses letters of credit, generally with terms of one year, to provide financial guarantees for certain operating obligations. At June 30, 2017 and Dec. 31, 2016, 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, 2017, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility (a)		Drawn(b)		Available
$	150	$	46	$	104

^(a)  This credit facility expires in June 2021.

^(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, 2017 and Dec. 31, 2016.

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, 2017			Dec. 31, 2016
Notes payable to affiliates	$	0.5		$	0.5
Weighted average interest rate at period end	1.55		%	0.95		%

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Fair Value of Financial Assets and Liabilities

6 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

Fair Value of Financial Assets and Liabilities

Fair Value of Financial Assets and Liabilities

Fair Value Measurements

The accounting guidance for fair value measurements and disclosures provides a single definition of fair value and requires certain disclosures about assets and liabilities measured at fair value.  A hierarchical framework for disclosing the observability of the inputs utilized in measuring assets and liabilities at fair value is established by this guidance. The three levels in the hierarchy are as follows:

Level 1 — Quoted prices are available in active markets for identical assets or liabilities as of the reporting date.  The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices.

Level 2 — Pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable as of the reporting date.  The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts or priced with models using highly observable inputs.

Level 3 — Significant inputs to pricing have little or no observability as of the reporting date.  The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation.

Specific valuation methods include the following:

Cash equivalents— The fair values of cash equivalents are generally based on cost plus accrued interest; money market funds are measured using quoted net asset values.

Interest rate derivatives— The fair values of interest rate derivatives are based on broker quotes that utilize current market interest rate forecasts.

Commodity derivatives— The methods used to measure the fair value of commodity derivative forwards and options utilize forward prices and volatilities, as well as pricing adjustments for specific delivery locations, and are generally assigned a Level 2 classification.  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, for trading purposes and 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, 2017, 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, including forecasted amounts for unsettled hedges, as applicable.

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, as well as for trading purposes. This could include the purchase or sale of natural gas to generate electric energy and natural gas for resale.

The following table details the gross notional amounts of commodity options at June 30, 2017 and Dec. 31, 2016:

(Amounts in Thousands)(a)(b)	June 30, 2017	Dec. 31, 2016
Million British thermal units of natural gas	123	255

^(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.

Impact of Derivative Activities on Income and Accumulated Other Comprehensive Loss — 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, 2017 and 2016, and $0.1 million of net losses reclassified from accumulated other comprehensive loss into earnings during the six months ended June 30, 2017 and 2016.

During the three and six months ended June 30, 2017, changes in the fair value of natural gas commodity derivatives resulted in immaterial and $0.1 million of net losses recognized as regulatory assets and liabilities, respectively. For the three and six months ended June 30, 2016, changes in the fair value of natural gas commodity derivatives resulted in $0.1 million of net gains and $0.1 million of net losses 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 $0.2 million and $0.6 million were recognized for the six months ended June 30, 2017 and 2016, respectively, 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. There were no losses or gains and immaterial natural gas commodity derivatives settlement losses recognized during the three months ended June 30, 2017 and 2016, respectively.

NSP-Wisconsin had no derivative instruments designated as fair value hedges during the three and six months ended June 30, 2017 and 2016. Therefore, no gains or losses from fair value hedges or related hedged transactions were recognized for these periods.

Consideration of Credit Risk and Concentrations—NSP-Wisconsin continuously monitors the creditworthiness of the counterparties to its interest rate derivatives and commodity derivative contracts prior to settlement, and assesses each counterparty’s ability to perform on the transactions set forth in the contracts. Given this assessment, as well as an assessment of the impact of NSP-Wisconsin’s own credit risk when determining the fair value of derivative liabilities, the impact of credit risk was immaterial to the fair value of unsettled 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.

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

	June 30, 2017
	Fair Value						Fair Value Total		Counterparty Netting(a)		Total(b)
(Thousands of Dollars)	Level 1		Level 2		Level 3
Current derivative assets
Natural gas commodity	$	—	$	71	$	—	$	71	$	—	$	71

	Dec. 31, 2016
	Fair Value						Fair Value Total		Counterparty Netting(a)		Total(b)
(Thousands of Dollars)	Level 1		Level 2		Level 3
Current derivative assets
Natural gas commodity	$	—	$	149	$	—	$	149	$	—	$	149

^(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, 2017 and Dec. 31, 2016.  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 prepayments and other current assets balance of $3.4 million and $3.8 million at June 30, 2017 and Dec. 31, 2016, respectively, in the consolidated balance sheets.

Fair Value of Long-Term Debt

As of June 30, 2017 and Dec. 31, 2016, other financial instruments for which the carrying amount did not equal fair value were as follows:

	June 30, 2017				Dec. 31, 2016
(Thousands of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	663,402	$	747,072	$	663,069	$	730,284

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, 2017 and Dec. 31, 2016, 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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Other Income, Net

6 Months Ended

Jun. 30, 2017

Other Income and Expenses [Abstract]

Other Income, Net

Other Income, Net

Other income, net consisted of the following:

	Three Months Ended June 30						Six Months Ended June 30
(Thousands of Dollars)	2017			2016			2017			2016
Interest income	$	61		$	14		$	204		$	138
Other nonoperating income	75			108			230			266
Insurance policy (expense) income	(49		)	(42		)	(98		)	128
Other nonoperating expense	(4		)	(3		)	(7		)	(6		)
Other income, net	$	83		$	77		$	329		$	526

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Segment Information

6 Months Ended

Jun. 30, 2017

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, transmits and distributes electricity primarily in portions of Wisconsin and Michigan. 

• NSP-Wisconsin’s regulated natural gas utility segment purchases, transports, stores and distributes natural gas primarily 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 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 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, 2017
Operating revenues (a)	$	210,742	$	19,027		$	257	$	—		$	230,026
Intersegment revenues	123		68			—		(191		)	—
Total revenues	$	210,865	$	19,095		$	257	$	(191	)	$	230,026
Net income (loss)	$	14,516	$	(973	)	$	698	$	—		$	14,241

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other			Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2016
Operating revenues (a)	$	202,879	$	16,005		$	289		$	—		$	219,173
Intersegment revenues	98		122			—			(220		)	—
Total revenues	$	202,977	$	16,127		$	289		$	(220	)	$	219,173
Net income (loss)	$	15,098	$	(2,465	)	$	(8	)	$	—		$	12,625

^(a)  Operating revenues include $43 million of affiliate electric revenue for the three months ended June 30, 2017 and 2016.

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2017
Operating revenues (a)	$	427,051	$	67,374	$	532	$	—		$	494,957
Intersegment revenues	219		182		—		(401		)	—
Total revenues	$	427,270	$	67,556	$	532	$	(401	)	$	494,957
Net income	$	29,986	$	5,572	$	1,102	$	—		$	36,660

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2016
Operating revenues (a)	$	414,403	$	59,025	$	595	$	—		$	474,023
Intersegment revenues	207		202		—		(409		)	—
Total revenues	$	414,610	$	59,227	$	595	$	(409	)	$	474,023
Net income	$	26,599	$	3,627	$	30	$	—		$	30,256

^(a)  Operating revenues include $85 million and $84 million of affiliate electric revenue for the six months endedJune 30, 2017 and 2016, respectively.

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Benefit Plans and Other Postretirement Benefits

6 Months Ended

Jun. 30, 2017

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
	2017			2016			2017			2016
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	1,155		$	1,104		$	7		$	6
Interest cost	1,555			1,704			148			163
Expected return on plan assets	(2,295		)	(2,289		)	(8		)	(6		)
Amortization of prior service cost (credit)	34			28			(88		)	(88		)
Amortization of net loss	1,461			1,348			109			83
Net benefit cost recognized for financial reporting	$	1,910		$	1,895		$	168		$	158

	Six Months Ended June 30
	2017			2016			2017			2016
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	2,309		$	2,208		$	14		$	12
Interest cost	3,109			3,408			296			326
Expected return on plan assets	(4,590		)	(4,578		)	(16		)	(12		)
Amortization of prior service cost (credit)	69			56			(176		)	(176		)
Amortization of net loss	2,923			2,696			218			166
Net benefit cost recognized for financial reporting	$	3,820		$	3,790		$	336		$	316

In January 2017, contributions of $150.0 million were made across four of Xcel Energy’s pension plans, of which $9.0 million was attributable to NSP-Wisconsin. Xcel Energy does not expect additional pension contributions during 2017.

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Other Comprehensive Income

6 Months Ended

Jun. 30, 2017

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, 2017 and 2016 were as follows:

	Gains and Losses on Cash Flow Hedges
(Thousands of Dollars)	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016
Accumulated other comprehensive loss at April 1	$	(114	)	$	(190	)
Losses reclassified from net accumulated other comprehensive loss	19			19
Net current period other comprehensive income	19			19
Accumulated other comprehensive loss at June 30	$	(95	)	$	(171	)

	Gains and Losses on Cash Flow Hedges
(Thousands of Dollars)	Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
Accumulated other comprehensive loss at Jan. 1	$	(133	)	$	(209	)
Losses reclassified from net accumulated other comprehensive loss	38			38
Net current period other comprehensive income	38			38
Accumulated other comprehensive loss at June 30	$	(95	)	$	(171	)

Reclassifications from accumulated other comprehensive loss for the three and six months ended June 30, 2017 and 2016 were as follows:

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Three Months Ended June 30, 2017				Three Months Ended June 30, 2016
Losses on cash flow hedges:
Interest rate derivatives	$	31		(a)	$	31		(a)
Total, pre-tax	31				31
Tax benefit	(12		)		(12		)
Total amounts reclassified, net of tax	$	19			$	19

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Six Months Ended June 30, 2017				Six Months Ended June 30, 2016
Losses on cash flow hedges:
Interest rate derivatives	$	62		(a)	$	63		(a)
Total, pre-tax	62				63
Tax benefit	(24		)		(25		)
Total amounts reclassified, net of tax	$	38			$	38

^(a)  Included in interest charges.

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Selected Balance Sheet Data (Tables)

6 Months Ended

Jun. 30, 2017

Balance Sheet Related Disclosures [Abstract]

Accounts Receivable, Net

(Thousands of Dollars)	June 30, 2017			Dec. 31, 2016
Accounts receivable, net (a)
Accounts receivable	$	58,587		$	58,896
Less allowance for bad debts	(4,247		)	(4,865		)
	$	54,340		$	54,031

Inventories

(Thousands of Dollars)	June 30, 2017		Dec. 31, 2016
Inventories
Materials and supplies	$	7,117	$	6,582
Fuel	4,615		4,743
Natural gas	3,908		6,984
	$	15,640	$	18,309

Property, Plant and Equipment, Net

(Thousands of Dollars)	June 30, 2017			Dec. 31, 2016
Property, plant and equipment, net
Electric plant	$	2,534,258		$	2,499,401
Natural gas plant	307,217			294,986
Common and other property	170,486			156,316
Construction work in progress	145,458			118,822
Total property, plant and equipment	3,157,419			3,069,525
Less accumulated depreciation	(1,157,072		)	(1,121,888		)
	$	2,000,347		$	1,947,637

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017		Dec. 31, 2016
Unrecognized tax benefit — Permanent tax positions	$	0.4	$	0.4
Unrecognized tax benefit — Temporary tax positions	5.1		4.9
Total unrecognized tax benefit	$	5.5	$	5.3

Tax Benefits Associated with NOL and Tax Credit Carryforwards

The unrecognized tax benefit amounts were reduced by the tax benefits associated with 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, 2017			Dec. 31, 2016
NOL and tax credit carryforwards	$	(1.3	)	$	(1.2	)

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Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Guarantees Issued and Outstanding

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

(Millions of Dollars)	June 30, 2017		Dec. 31, 2016
Guarantee issued and outstanding	$	1.0	$	1.0
Current exposure under this guarantee	—		0.1

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Borrowings and Other Financing Instruments (Tables)

6 Months Ended

Jun. 30, 2017

Borrowings and Other Financing Instruments [Abstract]

Credit Facilities

At June 30, 2017, NSP-Wisconsin had the following committed credit facility available (in millions of dollars):

Credit Facility (a)		Drawn(b)		Available
$	150	$	46	$	104

^(a)  This credit facility expires in June 2021.

^(b)  Includes outstanding commercial paper.

Commercial Paper

Borrowings and Other Financing Instruments [Abstract]

Short-Term Borrowings

Commercial paper outstanding for NSP-Wisconsin was as follows:

(Amounts in Millions, Except Interest Rates)	Three Months Ended June 30, 2017			Year Ended Dec. 31, 2016
Borrowing limit	$	150		$	150
Amount outstanding at period end	46			60
Average amount outstanding	26			15
Maximum amount outstanding	49			64
Weighted average interest rate, computed on a daily basis	1.15		%	0.69		%
Weighted average interest rate at period end	1.36			0.95

Notes Payable To Affiliates

Borrowings and Other Financing 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, 2017			Dec. 31, 2016
Notes payable to affiliates	$	0.5		$	0.5
Weighted average interest rate at period end	1.55		%	0.95		%

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Fair Value of Financial Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

Gross Notional Amounts of Commodity Forwards and Options

The following table details the gross notional amounts of commodity options at June 30, 2017 and Dec. 31, 2016:

(Amounts in Thousands)(a)(b)	June 30, 2017	Dec. 31, 2016
Million British thermal units of natural gas	123	255

^(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.

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 and liabilities measured at fair value on a recurring basis:

	June 30, 2017
	Fair Value						Fair Value Total		Counterparty Netting(a)		Total(b)
(Thousands of Dollars)	Level 1		Level 2		Level 3
Current derivative assets
Natural gas commodity	$	—	$	71	$	—	$	71	$	—	$	71

	Dec. 31, 2016
	Fair Value						Fair Value Total		Counterparty Netting(a)		Total(b)
(Thousands of Dollars)	Level 1		Level 2		Level 3
Current derivative assets
Natural gas commodity	$	—	$	149	$	—	$	149	$	—	$	149

^(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, 2017 and Dec. 31, 2016.  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 prepayments and other current assets balance of $3.4 million and $3.8 million at June 30, 2017 and Dec. 31, 2016, respectively, in the consolidated balance sheets.

Carrying Amount and Fair Value of Long-term Debt

As of June 30, 2017 and Dec. 31, 2016, other financial instruments for which the carrying amount did not equal fair value were as follows:

	June 30, 2017				Dec. 31, 2016
(Thousands of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value
Long-term debt, including current portion	$	663,402	$	747,072	$	663,069	$	730,284

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Other Income, Net (Tables)

6 Months Ended

Jun. 30, 2017

Other Income and Expenses [Abstract]

Other Income, Net

Other income, net consisted of the following:

	Three Months Ended June 30						Six Months Ended June 30
(Thousands of Dollars)	2017			2016			2017			2016
Interest income	$	61		$	14		$	204		$	138
Other nonoperating income	75			108			230			266
Insurance policy (expense) income	(49		)	(42		)	(98		)	128
Other nonoperating expense	(4		)	(3		)	(7		)	(6		)
Other income, net	$	83		$	77		$	329		$	526

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Segment Information (Tables)

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Results from Operations by Reportable Segment

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other		Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2017
Operating revenues (a)	$	210,742	$	19,027		$	257	$	—		$	230,026
Intersegment revenues	123		68			—		(191		)	—
Total revenues	$	210,865	$	19,095		$	257	$	(191	)	$	230,026
Net income (loss)	$	14,516	$	(973	)	$	698	$	—		$	14,241

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas			All Other			Reconciling Eliminations			Consolidated Total
Three Months Ended June 30, 2016
Operating revenues (a)	$	202,879	$	16,005		$	289		$	—		$	219,173
Intersegment revenues	98		122			—			(220		)	—
Total revenues	$	202,977	$	16,127		$	289		$	(220	)	$	219,173
Net income (loss)	$	15,098	$	(2,465	)	$	(8	)	$	—		$	12,625

^(a)  Operating revenues include $43 million of affiliate electric revenue for the three months ended June 30, 2017 and 2016.

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2017
Operating revenues (a)	$	427,051	$	67,374	$	532	$	—		$	494,957
Intersegment revenues	219		182		—		(401		)	—
Total revenues	$	427,270	$	67,556	$	532	$	(401	)	$	494,957
Net income	$	29,986	$	5,572	$	1,102	$	—		$	36,660

(Thousands of Dollars)	Regulated Electric		Regulated Natural Gas		All Other		Reconciling Eliminations			Consolidated Total
Six Months Ended June 30, 2016
Operating revenues (a)	$	414,403	$	59,025	$	595	$	—		$	474,023
Intersegment revenues	207		202		—		(409		)	—
Total revenues	$	414,610	$	59,227	$	595	$	(409	)	$	474,023
Net income	$	26,599	$	3,627	$	30	$	—		$	30,256

^(a)  Operating revenues include $85 million and $84 million of affiliate electric revenue for the six months endedJune 30, 2017 and 2016, respectively.

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Benefit Plans and Other Postretirement Benefits (Tables)

6 Months Ended

Jun. 30, 2017

Compensation and Retirement Disclosure [Abstract]

Components of Net Periodic Benefit Cost

Components of Net Periodic Benefit Cost

	Three Months Ended June 30
	2017			2016			2017			2016
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	1,155		$	1,104		$	7		$	6
Interest cost	1,555			1,704			148			163
Expected return on plan assets	(2,295		)	(2,289		)	(8		)	(6		)
Amortization of prior service cost (credit)	34			28			(88		)	(88		)
Amortization of net loss	1,461			1,348			109			83
Net benefit cost recognized for financial reporting	$	1,910		$	1,895		$	168		$	158

	Six Months Ended June 30
	2017			2016			2017			2016
(Thousands of Dollars)	Pension Benefits						Postretirement Health Care Benefits
Service cost	$	2,309		$	2,208		$	14		$	12
Interest cost	3,109			3,408			296			326
Expected return on plan assets	(4,590		)	(4,578		)	(16		)	(12		)
Amortization of prior service cost (credit)	69			56			(176		)	(176		)
Amortization of net loss	2,923			2,696			218			166
Net benefit cost recognized for financial reporting	$	3,820		$	3,790		$	336		$	316

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Other Comprehensive Income (Tables)

6 Months Ended

Jun. 30, 2017

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, 2017 and 2016 were as follows:

	Gains and Losses on Cash Flow Hedges
(Thousands of Dollars)	Three Months Ended June 30, 2017			Three Months Ended June 30, 2016
Accumulated other comprehensive loss at April 1	$	(114	)	$	(190	)
Losses reclassified from net accumulated other comprehensive loss	19			19
Net current period other comprehensive income	19			19
Accumulated other comprehensive loss at June 30	$	(95	)	$	(171	)

	Gains and Losses on Cash Flow Hedges
(Thousands of Dollars)	Six Months Ended June 30, 2017			Six Months Ended June 30, 2016
Accumulated other comprehensive loss at Jan. 1	$	(133	)	$	(209	)
Losses reclassified from net accumulated other comprehensive loss	38			38
Net current period other comprehensive income	38			38
Accumulated other comprehensive loss at June 30	$	(95	)	$	(171	)

Reclassifications out of Accumulated Other Comprehensive Loss

Reclassifications from accumulated other comprehensive loss for the three and six months ended June 30, 2017 and 2016 were as follows:

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Three Months Ended June 30, 2017				Three Months Ended June 30, 2016
Losses on cash flow hedges:
Interest rate derivatives	$	31		(a)	$	31		(a)
Total, pre-tax	31				31
Tax benefit	(12		)		(12		)
Total amounts reclassified, net of tax	$	19			$	19

	Amounts Reclassified from Accumulated Other Comprehensive Loss
(Thousands of Dollars)	Six Months Ended June 30, 2017				Six Months Ended June 30, 2016
Losses on cash flow hedges:
Interest rate derivatives	$	62		(a)	$	63		(a)
Total, pre-tax	62				63
Tax benefit	(24		)		(25		)
Total amounts reclassified, net of tax	$	38			$	38

^(a)  Included in interest charges.

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Selected Balance Sheet Data, Accounts Receivable (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Accounts Receivable, Net
Accounts receivable	$ 58,587	$ 58,896
Less allowance for bad debts	(4,247)	(4,865)
Accounts receivable, net	$ 54,340	$ 54,031

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Selected Balance Sheet Data, Inventory (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Public Utilities, Inventory [Line Items]
Inventories	$ 15,640	$ 18,309
Materials and supplies
Public Utilities, Inventory [Line Items]
Inventories	7,117	6,582
Fuel
Public Utilities, Inventory [Line Items]
Inventories	4,615	4,743
Natural gas
Public Utilities, Inventory [Line Items]
Inventories	$ 3,908	$ 6,984

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Selected Balance Sheet Data, Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 3,157,419	$ 3,069,525
Less accumulated depreciation	(1,157,072)	(1,121,888)
Property, plant and equipment, net	2,000,347	1,947,637
Electric plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	2,534,258	2,499,401
Natural gas plant
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	307,217	294,986
Common and other property
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	170,486	156,316
Construction work in progress
Public Utility, Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 145,458	$ 118,822

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Income Taxes (Details) - USD ($)	6 Months Ended	9 Months Ended	12 Months Ended
	Jun. 30, 2017	Sep. 30, 2015	Dec. 31, 2016	Dec. 31, 2012
Unrecognized Tax Benefits [Abstract]
Unrecognized tax benefit — Permanent tax positions	$ 400,000		$ 400,000
Unrecognized tax benefit — Temporary tax positions	5,100,000		4,900,000
Total unrecognized tax benefit	5,500,000		5,300,000
NOL and tax credit carryforwards	(1,300,000)		(1,200,000)
Upper bound of decrease in unrecognized tax benefit that is reasonably possible	2,000,000
Amounts accrued for penalties related to unrecognized tax benefits	0		$ 0
Internal Revenue Service (IRS)
Tax Audits [Abstract]
Year(s) under examination		2012 and 2013		2010 and 2011
Year of carryback claim under examination				2009
Potential Tax Adjustments	$ 14,000,000
Earliest year subject to examination	2009
State Jurisdiction (Wisconsin)
Tax Audits [Abstract]
Year(s) under examination			2012 and 2013
Earliest year subject to examination	2012

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Rate Matters Rate Matters (Details) - USD ($) $ in Millions	1 Months Ended						6 Months Ended
	May 31, 2017	Sep. 30, 2016	Jun. 30, 2016	Dec. 31, 2015	Feb. 28, 2015	Nov. 30, 2013	Jun. 30, 2017
NSP-Wisconsin | Public Service Commission of Wisconsin (PSCW) | PSCW Proceeding - Wisconsin 2018 Electric and Natural Gas Rate Case - Electric Rates 2018 [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 24.7
Public Utilities, Requested Rate Increase (Decrease), Percentage	3.60%
Public Utilities, Requested Rate Base, Amount	$ 1,200.0
NSP-Wisconsin | Public Service Commission of Wisconsin (PSCW) | PSCW Proceeding - Wisconsin 2018 Electric and Natural Gas Rate Case - Gas Rates 2018 [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 12.0
Public Utilities, Requested Rate Increase (Decrease), Percentage	10.10%
Public Utilities, Requested Rate Base, Amount	$ 138.4
NSP-Wisconsin | Public Service Commission of Wisconsin (PSCW) | PSCW Proceeding - Wisconsin 2018 Electric and Natural Gas Rate Case [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage	10.00%
Public Utilities, Requested Equity Capital Structure, Percentage	52.53%
NSP-Minnesota | FERC Proceeding, MISO ROE Complaint
Public Utilities, General Disclosures [Line Items]
Public Utilities, Base Return On Equity Charged To Customers Through Transmission Formula Rates					12.38%	12.38%
Public Utilities, ROE Applicable To Transmission Formula Rates In The Regional Transmission Operator's Region, Recommended By Third Parties					8.67%	9.15%
NSP-Minnesota | Federal Energy Regulatory Commission (FERC) | FERC Proceeding, MISO ROE Complaint
Public Utilities, General Disclosures [Line Items]
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, Approved		10.32%		10.32%
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, Recommended				10.32%
Public Utilities, Length of Refund Period, In Months		15 months
Public Utilities, ROE Applicable To Transmission Formula Rates In The MISO Region, with RTO Adder, Approved							10.82%
Public Utilities, ROE Basis Point Adder, Approved							50
NSP-Minnesota | Administrative Law Judge | FERC Proceeding, MISO ROE Complaint
Public Utilities, General Disclosures [Line Items]
Public Utilities, ROE Applicable To Transmission Formula Rates In The Regional Transmission Operator's Region, Recommended By Third Parties			9.70%

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Commitments and Contingencies, Guarantees and Indemnifications (Details) - USD ($)	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Guarantor Obligations [Line Items]
Assets Held As Collateral	$ 0	$ 0
Payment or Performance Guarantee | Customer Loans for Farm Rewiring Program
Guarantor Obligations [Line Items]
Payment Guarantee Expiration (year)	2020
Guarantee issued and outstanding	$ 1,000,000	1,000,000
Current exposure under this guarantee	$ 0	$ 100,000

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Commitments and Contingencies, Environmental Contingencies - Site Contingencies (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2017 USD ($) Site	Dec. 31, 2016 USD ($)
Ashland MGP Site
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Number of properties not owned included in superfund site | Site	2
Current Cost Estimate for Site Remediation	$ 160.0
Estimated amount spent on cleanup	113.2
Accrual for Environmental Loss Contingencies, Gross	$ 46.8	$ 64.3
Approved amortization period for recovery of remediation costs in natural gas rates (in years)	10 years
Carrying cost percentage to be applied to unamortized regulatory asset	3.00%
Other MGP Sites [Member]
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 0.1
Number of identified MGP sites under current investigation and/or remediation in addition to those separately disclosed	1
PSCW Proceeding - Gas Rate Case 2017 - Gas Rates 2017 [Member] | Ashland MGP Site
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Public Utilities, Approved annual recovery collected through base rates		$ 12.4
PSCW Proceeding - Gas Rate Case 2017 - Gas Rates 2018 [Member] | Ashland MGP Site
Ashland Manufactured Gas Plant (MGP) Site [Abstract]
Public Utilities, Requested annual recovery collected through base rates	$ 18.1

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Commitments and Contingencies Commitments and Contingencies - Legal Contingencies (Details) - Gas Trading Litigation	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2009
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number	7	13
Loss Contingency, Claims Settled, Number	5
Loss Contingency, Multi-District Litigation Claims, Number	1
Loss Contingency, Subset of Cases within Multi-District Litigation, Number	2
NSP-Wisconsin
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number		2

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Borrowings and Other Financing Instruments, Commercial Paper (Details) - USD ($)	3 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Short-term Debt [Line Items]
Amount outstanding at period end	$ 46,000,000	$ 60,000,000
Commercial Paper
Short-term Debt [Line Items]
Borrowing limit	150,000,000	150,000,000
Amount outstanding at period end	46,000,000	60,000,000
Average amount outstanding	26,000,000	15,000,000
Maximum amount outstanding	$ 49,000,000	$ 64,000,000
Weighted average interest rate, computed on a daily basis (percentage)	1.15%	0.69%
Weighted average interest rate at period end (percentage)	1.36%	0.95%

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Borrowings and Other Financing Instruments, Letters of Credit (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Amount outstanding at period end	$ 46,000	$ 60,000
Letter of Credit
Line of Credit Facility [Line Items]
Amount outstanding at period end	$ 0	$ 0
Letter of Credit | Letter of Credit
Line of Credit Facility [Line Items]
Term of letters of credit (in years)	1 year

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Borrowings and Other Financing Instruments, Credit Facility (Details) - Credit Facility - USD ($)		6 Months Ended
		Jun. 30, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Credit Facility	[1]	$ 150,000,000
Drawn	[2]	46,000,000
Available		$ 104,000,000
Maturity Date		Jun. 30, 2021
Direct advances on the credit facility outstanding		$ 0	$ 0

[1] This credit facility expires in June 2021.

[2] Includes outstanding commercial paper.

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Borrowings and Other Financing Instruments, Intercompany Borrowing Arrangement and Other Short-Term Borrowings (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Short-term Debt [Line Items]
Notes payable to affiliates	$ 500	$ 500
Notes Payable To Affiliates
Short-term Debt [Line Items]
Notes payable to affiliates	$ 500	$ 500
Weighted average interest rate at period end (percentage)	1.55%	0.95%

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Fair Value of Financial Assets and Liabilities, Derivative Instruments (Details) MMBTU in Thousands, $ in Millions		Jun. 30, 2017 USD ($) MMBTU	Dec. 31, 2016 MMBTU
Interest Rate Swap
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)
Natural Gas Commodity (in million British thermal units)
Gross Notional Amounts of Commodity Options [Abstract]
Derivative, Nonmonetary Notional amount | MMBTU	[1],[2]	123	255

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

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

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Fair Value of Financial Assets and Liabilities, Impact of Derivative Activity (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Financial Impact of Qualifying Fair Value Hedges on Earnings [Abstract]
Derivative instruments designated as fair value hedges	$ 0	$ 0	$ 0	$ 0
Recognized gains (losses) from fair value hedges or related hedged transactions	$ 0	0	0	0
Other Derivative Instruments | Natural Gas Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Pre-tax fair value gains (losses) recognized during the period in regulatory (assets) and liabilities		$ 100,000	(100,000)	(100,000)
Pre-tax (gains) losses reclassified into income during the period from regulatory assets and (liabilities)			200,000	600,000
Cash Flow Hedges | Designated as Hedging Instrument | Interest Rate
Derivative Instruments, Gain (Loss) [Line Items]
Interest Rate Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net			$ (100,000)	$ (100,000)

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Fair Value of Financial Assets and Liabilities, Derivative Assets and Liabilities at Fair Value (Details) - USD ($) $ in Thousands		Jun. 30, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Prepayments and other		$ 3,434	$ 3,785
Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	71	149
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	[2]	0	0
Fair Value Measured on a Recurring Basis | Level 1 | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0	0
Fair Value Measured on a Recurring Basis | Level 2 | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		71	149
Fair Value Measured on a Recurring Basis | Level 3 | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		0	0
Estimate of Fair Value Measurement [Member] | Fair Value Measured on a Recurring Basis
Derivatives, Fair Value [Line Items]
Prepayments and other		3,400	3,800
Estimate of Fair Value Measurement [Member] | Fair Value Measured on a Recurring Basis | Other Current Assets | Other Derivative Instruments | Natural Gas Commodity
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		$ 71	$ 149

[1] Included in prepayments and other current assets balance of $3.4 million and $3.8 million at June 30, 2017 and Dec. 31, 2016, respectively, in the consolidated balance sheets.

[2] 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, 2017 and Dec. 31, 2016. 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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Fair Value of Financial Assets and Liabilities, Fair Value of Long-Term Debt (Details) - USD ($) $ in Thousands		Jun. 30, 2017	Dec. 31, 2016
Carrying Amount
Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, including current portion	[1]	$ 663,402	$ 663,069
Fair Value
Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, including current portion	[1]	$ 747,072	$ 730,284

[1] {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOjg1MjVjM2MwMjhlODQxY2Y4YzZhOTNiNmQyMjNhYjM2fFRleHRTZWxlY3Rpb246OTlCQ0ZBQ0IxOTEwNUE1Mjk0NTdENDUxRThFQkVFN0QM}

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Other Income, Net (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Other Income and Expenses [Abstract]
Interest income	$ 61	$ 14	$ 204	$ 138
Other nonoperating income	75	108	230	266
Insurance policy (expense) income	(49)	(42)	(98)	128
Other nonoperating expense	(4)	(3)	(7)	(6)
Other income, net	$ 83	$ 77	$ 329	$ 526

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Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended				6 Months Ended
	Jun. 30, 2017		Jun. 30, 2016		Jun. 30, 2017		Jun. 30, 2016
Segment Reporting Information [Line Items]
Operating revenues	$ 230,026		$ 219,173		$ 494,957		$ 474,023
Net income (loss)	14,241		12,625		36,660		30,256
Affiliate electric revenue	43,000		43,000		85,000		84,000
Regulated Electric
Segment Reporting Information [Line Items]
Operating revenues	210,865		202,977		427,270		414,610
Net income (loss)	14,516		15,098		29,986		26,599
Regulated Natural Gas
Segment Reporting Information [Line Items]
Operating revenues	19,095		16,127		67,556		59,227
Net income (loss)	(973)		(2,465)		5,572		3,627
All Other
Segment Reporting Information [Line Items]
Operating revenues	257		289		532		595
Net income (loss)	698		(8)		1,102		30
Operating Segments
Segment Reporting Information [Line Items]
Operating revenues	230,026	[1]	219,173	[1]	494,957	[2]	474,023	[2]
Operating Segments | Regulated Electric
Segment Reporting Information [Line Items]
Operating revenues	210,742	[1]	202,879	[1]	427,051	[2]	414,403	[2]
Operating Segments | Regulated Natural Gas
Segment Reporting Information [Line Items]
Operating revenues	19,027		16,005		67,374		59,025
Operating Segments | All Other
Segment Reporting Information [Line Items]
Operating revenues	257		289		532		595
Intersegment Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(191)		(220)		(401)		(409)
Net income (loss)	0		0		0		0
Intersegment Eliminations | Regulated Electric
Segment Reporting Information [Line Items]
Operating revenues	123		98		219		207
Intersegment Eliminations | Regulated Natural Gas
Segment Reporting Information [Line Items]
Operating revenues	68		122		182		202
Intersegment Eliminations | All Other
Segment Reporting Information [Line Items]
Operating revenues	$ 0		$ 0		$ 0		$ 0

[1] (a) Operating revenues include $43 million of affiliate electric revenue for the three months ended June 30, 2017 and 2016.

[2] (a) Operating revenues include $85 million and $84 million of affiliate electric revenue for the six months ended June 30, 2017 and 2016, respectively.

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Benefit Plans and Other Postretirement Benefits (Details) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Jan. 31, 2017 USD ($) Plan	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)
Pension Benefits
Components of Net Periodic Benefit Cost [Abstract]
Service cost		$ 1,155	$ 1,104	$ 2,309	$ 2,208
Interest cost		1,555	1,704	3,109	3,408
Expected return on plan assets		(2,295)	(2,289)	(4,590)	(4,578)
Amortization of prior service cost (credit)		34	28	69	56
Amortization of net loss		1,461	1,348	2,923	2,696
Net benefit cost recognized for financial reporting		1,910	1,895	3,820	3,790
Total contributions to the pension plans during the period	$ 9,000
Postretirement Health Care Benefits
Components of Net Periodic Benefit Cost [Abstract]
Service cost		7	6	14	12
Interest cost		148	163	296	326
Expected return on plan assets		(8)	(6)	(16)	(12)
Amortization of prior service cost (credit)		(88)	(88)	(176)	(176)
Amortization of net loss		109	83	218	166
Net benefit cost recognized for financial reporting		$ 168	$ 158	$ 336	$ 316
Xcel Energy Inc. | Pension Benefits
Components of Net Periodic Benefit Cost [Abstract]
Total contributions to the pension plans during the period	$ 150,000
Number of Xcel Energy's pension plans to which contributions were made | Plan	4

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Other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period			$ 811,850
Accumulated other comprehensive loss at end of period	$ 821,651		821,651
Gains and Losses on Cash Flow Hedges
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Accumulated other comprehensive loss at beginning of period	(114)	$ (190)	(133)	$ (209)
Losses reclassified from net accumulated other comprehensive loss	19	19	38	38
Net current period other comprehensive income	19	19	38	38
Accumulated other comprehensive loss at end of period	$ (95)	$ (171)	$ (95)	$ (171)

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Other Comprehensive Income (Reclassification from AOCI) (Details) - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total, pre-tax		$ (22,994)	$ (20,582)	$ (59,170)	$ (49,032)
Tax benefit		8,753	7,957	22,510	18,776
Gains and Losses on Cash Flow Hedges | Amounts Reclassified from Accumulated Other Comprehensive Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total, pre-tax		31	31	62	63
Tax benefit		(12)	(12)	(24)	(25)
Total, net of tax		19	19	38	38
Gains and Losses on Cash Flow Hedges | Interest Rate Derivatives | Amounts Reclassified from Accumulated Other Comprehensive Loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest charges	[1]	$ 31	$ 31	$ 62	$ 63

[1] Included in interest charges.