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
Transition report pursuant to Section 13 or 15(d) of
the Securities Exchange Act of 1934
For Quarter Ended September 30, 1997 Commission File Number 10-3140
NORTHERN STATES POWER COMPANY, A WISCONSIN CORPORATION, MEETS THE
CONDITIONS SET FORTH IN GENERAL INSTRUCTION H (1) AND (2) OF FORM
10-Q AND IS THEREFORE FILING THIS FORM WITH THE REDUCED DISCLOSURE FORMAT.
Northern States Power Company
(Exact name of registrant as specified in its charter)
Wisconsin 39-0508315
(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
100 North Barstow Street, Eau Claire, Wisconsin 54703
(Address of principal executive officers) (Zip Code)
Registrant's telephone number, including area code (715) 839-2416
NONE
Former name, former address and former fiscal year, if changed since last
report
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 period that the Registrant was required to file such
reports), and (2) has been subject to such filing requirements
for the past 90 days.
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 November 14, 1997
Common Stock, $100 par value 862,000 Shares
All outstanding common stock is owned beneficially and of
record by Northern States Power Company, a Minnesota corporation.
PART 1. FINANCIAL INFORMATION
Item 1. Financial Statements
Northern States Power Company (Wisconsin)
Statements of Income (Unaudited)
Three Months Ended Nine Months Ended
September 30 September 30
1997 1996 1997 1996
(Thousands of dollars)
Operating revenues
Electric............................................. $95,800 $91,459 $284,834 $279,960
Gas.................................................. 8,541 8,907 61,552 60,814
Total.............................................. 104,341 100,366 346,386 340,774
Operating expenses
Purchased and interchange power...................... 44,332 42,375 135,131 133,357
Fuel for electric generation......................... 3,629 923 7,546 3,523
Gas purchased for resale............................. 5,230 5,360 41,442 39,758
Other operation...................................... 10,021 11,203 34,250 34,604
Maintenance.......................................... 5,185 4,439 14,469 14,434
Administrative and general........................... 4,563 5,486 13,690 16,389
Conservation and demand side management.............. 2,234 2,279 6,701 6,838
Depreciation and amortization........................ 9,465 9,034 28,242 26,547
Taxes: Property and general.......................... 3,423 3,552 10,640 10,798
Current income tax ....................... 4,501 3,172 14,867 14,210
Deferred income tax....................... 753 1,391 2,231 2,375
Investment tax credits recognized......... (220) (227) (660) (682)
Total.............................................. 93,116 88,987 308,549 302,151
Operating income...................................... 11,225 11,379 37,837 38,623
Other income (expense)
Merger costs - net of applicable income taxes........ - - (523) -
Other income and deductions - net of applicable
income taxes 818 82 1,132 314
Allowance for funds used during construction - equity 65 65 163 276
Total other income (expense) - net.................. 883 147 772 590
Income before interest charges........................ 12,108 11,526 38,609 39,213
Interest charges
Interest on long-term debt........................... 4,080 3,968 12,238 11,910
Other interest and amortization...................... (126) 863 1,111 2,429
Allowance for funds used during construction - debt.. (89) (104) (235) (276)
Total.............................................. 3,865 4,727 13,114 14,063
Net Income ........................................... $8,243 $6,799 $25,495 $25,150
Statements of Retained Earnings (Unaudited)
Balance at beginning of period........................ $238,005 $227,197 $234,751 $221,638
Net income for period................................. 8,243 6,799 25,495 25,150
Dividends paid to parent.............................. (7,000) (6,396) (20,998) (19,188)
Balance at end of period.............................. $239,248 $227,600 $239,248 $227,600
The Notes to Financial Statements are an integral part of the Statements of
Income and Retained Earnings.
Northern States Power Company (Wisconsin)
Balance Sheets (Unaudited)
September 30, December 31,
1997 1996
ASSETS (Thousands of dollars)
Utility Plant
Electric........................................................ $919,821 $894,143
Gas............................................................. 103,945 99,817
Other........................................................... 69,346 67,262
Total....................................................... 1,093,112 1,061,222
Accumulated provision for depreciation........................ (419,310) (395,619)
Net utility plant........................................... 673,802 665,603
Current Assets
Cash............................................................ 31 208
Accounts receivable - net....................................... 29,152 40,250
Fuel inventories - at average cost.............................. 12,826 7,780
Other materials and supplies inventories - at average cost...... 5,933 5,918
Unbilled utility revenues....................................... 10,493 21,074
Prepayments and other........................................... 11,325 11,703
Total current assets.......................................... 69,760 86,933
Other Assets
Regulatory assets............................................... 35,825 37,102
Other investments............................................... 5,705 5,287
Federal income tax receivable................................... 3,307 3,307
Nonutility property - net of accumulated depreciation........... 2,768 2,799
Investments in unconsolidated affiliates........................ 2,070 2,146
Long-term prepayments and deferred charges...................... 7,263 5,954
Total other assets........................................... 56,938 56,595
TOTAL ASSETS................................................ $800,500 $809,131
LIABILITIES AND EQUITY
Capitalization
Common stock - authorized 870,000 shares of $100 par value,
issued shares: 1997 and 1996, 862,000...................... $86,200 $86,200
Premium on common stock....................................... 10,461 10,461
Retained earnings............................................. 239,248 234,751
Total common stock equity................................... 335,909 331,412
Long-term debt.................................................. 231,754 231,688
Total capitalization........................................ 567,663 563,100
Current Liabilities
Notes payable - parent company.................................. 29,200 39,300
Accounts payable................................................ 13,051 16,493
Payable to affiliate companies (principally parent)............. 16,405 15,544
Salaries, wages, and vacation pay accrued....................... 5,226 6,417
Taxes accrued................................................... 670 1,641
Interest accrued................................................ 4,408 4,459
Current deferred income taxes................................... 75 1,670
Other........................................................... 4,526 3,888
Total current liabilities................................... 73,561 89,412
Other Liabilities
Accumulated deferred income taxes............................... 103,673 100,898
Accumulated deferred investment tax credits..................... 19,195 20,024
Regulatory liabilities.......................................... 19,980 19,409
Customer advances............................................... 8,416 7,334
Benefit obligations and other................................... 8,012 8,954
Total other liabilities..................................... 159,276 156,619
Commitments and Contingent Liabilities (see Note 3)
TOTAL LIABILITIES AND EQUITY.............................. $800,500 $809,131
The Notes to Financial Statements are an integral part of the Balance Sheets.
Northern States Power Company (Wisconsin)
Statements of Cash Flows (Unaudited)
Nine Months Ended
September 30
1997 1996
(Thousands of dollars)
Cash Flows from Operating Activities:
Net Income.......................................................... $25,495 $25,150
Adjustments to reconcile net income to cash from operating activities:
Depreciation and amortization..................................... 29,131 27,216
Deferred income taxes............................................. 3,600 919
Deferred investment tax credits recognized........................ (660) (682)
Allowance for funds used during construction - equity............. (163) (276)
Cash provided by changes in working capital......................... 10,921 7,717
Cash used for changes in other assets and liabilities............... (2,542) (2,091)
Net cash provided by operating activities............................ 65,782 57,953
Cash Flows from Investing Activities:
Capital expenditures................................................ (36,514) (38,189)
Increase in construction payables................................... 1,919 464
Allowance for funds used during construction - equity............... 163 276
Other............................................................... (429) (137)
Net cash used for investing activities............................... (34,861) (37,586)
Cash Flows from Financing Activities:
Repayment of notes payable to parent - net.......................... (10,100) (1,100)
Dividends paid to parent............................................ (20,998) (19,188)
Net cash used for financing activities............................... (31,098) (20,288)
Net increase (decrease) in cash and cash equivalents................... (177) 79
Cash and cash equivalents at beginning of period....................... 208 247
Cash and cash equivalents at end of period............................. $31 $326
The Notes to Financial Statements are an integral part of the Statements of Cash
Flows.
Northern States Power Company (Wisconsin)
NOTES TO FINANCIAL STATEMENTS
The Company is a wholly owned subsidiary of Northern States Power Company,
a Minnesota corporation (NSPM).
In the opinion of management, the accompanying unaudited financial
statements contain all adjustments necessary to present fairly the financial
position of Northern States Power Company, a Wisconsin corporation (the
Company), as of Sept. 30, 1997 and Dec. 31, 1996, the results of its operations
for the three and nine months ended Sept. 30, 1997 and 1996 and its cash flows
for the nine months ended Sept. 30, 1997 and 1996. Due to the seasonality of
the Company's electric and gas sales, operating results on a quarterly and year-
to-date basis are not necessarily an appropriate base from which to project
annual results.
The accounting policies followed by the Company are set forth in Note 1 to
the Company's financial statements in its Annual Report on Form 10-K for the
year ended Dec. 31, 1996 (1996 Form 10-K). The following notes should be read
in conjunction with such policies and other disclosures in the Form 10-K.
1. Business Developments
Termination of Proposed Merger - As discussed in the Company's Form 8-K filed
on May 19, 1997, NSPM and Wisconsin Energy Corporation (WEC) announced on May
16, 1997 that they have mutually agreed to terminate their plans to merge the
two companies. As a result of the merger termination, the Company's second
quarter and year-to-date operating results for 1997 include a charge to
nonoperating expense of approximately $900,000 for deferred merger related
costs.
Union Agreements - A new three-year collective-bargaining agreement was
ratified by the Company's union membership on April 10, 1997. All provisions of
this new agreement are effective retroactively to Jan. 1, 1997. The prior
agreement had expired Dec. 31, 1996, but was extended to April 30, 1997.
New Natural Gas System - Through a competitive bidding process, the Company
has been selected to build, own, and operate a natural gas system at Fort McCoy,
a regional U.S. Army training center near Sparta, Wis. The total project cost
is expected to be approximately $2.5 million and estimated annual revenue is
$1.7 million. The 10-year contract with the U.S. Army includes renewal
provisions. The Company has contracted with Northern Natural Gas Company for
gas transportation services for the project and, on Oct. 24, 1997, Northern
Natural Gas Company filed its application with the Federal Energy Regulatory
Commission (FERC) to upgrade their facilities that will be used to supply the
project. Assuming timely approval of this filing, the Company anticipates that
gas will flow through the pipeline by mid-December 1997 to buildings that
currently have natural gas service and that additional load will be added
throughout the winter as the training center's propane gas equipment is
converted to use natural gas. The project is expected to be complete in the
second quarter of 1998. The Company has received an order from the Public
Service Commission of Wisconsin (PSCW) allowing the Company to treat the
investment as utility property. PSCW approval to include the Northern Natural
Gas contract in the Purchased Gas Adjustment clause is pending.
Upgraded Bond Ratings - On July 15, 1997, Moody's Investors Service upgraded
the credit ratings of the Company's First Mortgage Bonds from A1 to Aa3, and its
unsecured Pollution Control Bonds from A2 to A1. The Company's financial and
competitive position were among the factors cited for the upgrade. These
ratings reflect the views of Moody's Investors Service and an explanation of the
significance of these ratings may be obtained from them. A security rating is
not a recommendation to buy, sell or hold securities and is subject to revision
or withdrawal at any time by the rating agency.
Wheaton Plant Conversion - During the third quarter of 1997, the Company
converted units 2 and 4 of the Wheaton generating facility to operate on both
oil and natural gas. Previously, the units operated on oil exclusively.
Approximately $2.3 million of the expected total capital cost of $2.7 million
had been spent through Sept. 30, 1997. The conversion was prompted by an
opportunity to decrease the cost of producing electricity and reduce plant
emissions.
Tax Dispute Settlement - In September 1997 the Company received $825,000 of a
$1.8 million refund of tax and interest due from the State of Wisconsin which
resulted from a favorable court decision regarding a disputed tax issue. The
Company expects to receive the balance of the refund by year end 1997.
2. Regulation and Rate Matters
1997 Rate Filings - On June 9, 1997 the Company filed for a fuel cost
surcharge to its retail electric rates under the fuel rules provisions of the
Wisconsin Statutes. The surcharge was requested because fuel and purchased power
costs had risen beyond the amount included in the Company's current rates due to
unplanned and extended outages at NSPM's nuclear generating stations and higher
than projected wheeling costs associated with power purchases.
Effective Sept. 25, 1997 the PSCW authorized the implementation of a fuel
cost surcharge factor of $0.00043 per kilowatt-hour (Kwh) for all Wisconsin
retail electric customers, which is expected to produce approximately $500,000
of additional electric revenue in 1997. The surcharge represents less than 1
percent of current rates and is the first rate increase requested since January
1993. The surcharge will continue in effect on an interim basis until the next
rate order is issued and is subject to refund pending final PSCW review.
In its order regarding the Company's 1997 rates, the PSCW denied current
rate recovery of the federal government's assessment for the decommissioning and
decontamination of federal uranium enrichment facilities based on a court
decision involving another utility that these assessments were unlawful. The
PSCW, however, did state that they would allow future rate recovery of these
costs with interest if the courts ultimately decided the assessments must be
paid. While the case was under appeal, the Company continued to pay the
assessments and defer the cost as a regulatory wasset. $414,000 had been
deferred at Sept. 30, 1997.
On May 6, 1997, the United States Court of Appeals reversed the lower
court's earlier decision that these assessments were unlawful. Accordingly, the
Company has requested recovery of current and deferred assessments in its 1998
retail electric rate filing.
1998 Rate Filings - The Company filed retail electric and gas rate cases with
the PSCW on Nov. 14, 1997 for the test year 1998. The Company requested a 4.3%
increase, approximately $12.7 million annually, in retail electric rates and a
1.9% or $1.7 million decrease in retail gas rates. The Company has requested
that these changes take effect during the second quarter of 1998.
Network Transmission Service Costs (NTS) - In July 1997, the Company received
authorization from the PSCW to defer its share of network transmission service
(NTS) costs incurred after May 23, 1997. Beginning in the third quarter of
1997, the Company began deferring these costs, including a retroactive
adjustment to May 23, 1997. Through Sept. 30, 1997, $1.4 million of NTS costs
had been deferred. Recovery of deferred NTS costs will be sought in the
Company's 1998 retail electric rate case.
Under NTS, participating utilities share the annual transmission cost for their
combined joint-use systems, net of related transmission revenues, based upon
each company's share of the total network load. NSPM and the Company offered
NTS service to qualifying transmission customers as a result of the FERC Order
No. 888. The Company's share of this expense is billed through the Interchange
Agreement with NSPM. NSPM and the Company plan to file later in 1997 a rate
application with the FERC to update rates for transmission service.
Wisconsin Purchased Gas Adjustment Clause - In March 1996, the PSCW conducted a
generic hearing to consider alternative incentive-based gas cost recovery
mechanisms to replace the current purchased gas adjustment clause (PGA). In
November 1996, the PSCW issued an order with general guidelines for incentive-
based gas cost recovery mechanisms as well as "modified one-for-one" gas cost
recovery mechanisms. All major gas utilities in Wisconsin were required to file
a proposal to replace their current PGA. On Sept. 29, 1997 the Company filed
its proposal with the PSCW.
In the Company's proposal, allowable gas commodity cost recovery would be based
on a benchmark index which is, in turn, based on the market price of gas. The
allowable cost recovery of the remaining components of the cost of gas (for
example, fixed pipeline transportation costs, supply reservation costs, and
other costs approved by the FERC) would be based on actual costs incurred, as is
the case with the Company's current PGA.
The PSCW's decision is expected in April 1998. If the Company's proposal is
approved, the financial impact of the new gas cost recovery mechanism will be
substantially the same as with the current PGA. Approximately 70 percent of the
Company's gas revenues represent recovery of gas costs through the PGA
mechanism.
Michigan Power Supply Cost Recovery Factor (PSCR) - On Aug. 25, 1997, the
Michigan Public Service Commission (MPSC) approved the Company's application to
reinstate a PSCR for Michigan electric customers in 1998. On Sept. 29, 1997,
the Company filed its request for a 1998 PSCR of $.00172 per Kwh or about
$250,000. The Company had suspended the PSCR during 1997 while the merger
between NSPM and WEC was pending. The PSCR provides for recovery of power supply
costs for electric customers based on a twelve-month projection of costs. After
each twelve-month period is completed, a reconciliation is submitted to the MPSC
and any over-recovery of costs is refunded and any under-recovery of costs is
billed, including interest.
3. Commitments and Contingent Liabilities
Environmental Contingencies - As discussed in Note 8 to the Financial
Statements in the 1996 Form 10-K, the Company has been named as a potentially
responsible party in connection with environmental contamination at a site in
Ashland, Wis. With respect to developments since the 1996 Form 10-K was filed,
the Company began discussions with the Wisconsin Department of Natural Resources
in the third quarter of 1997 concerning other responsible parties and
remediation options for the Ashland site.
Network Transmission Costs - In October 1997, another regional utility
with integrated transmission facilities which participates in FERC's
transmission cost sharing network provided information to NSPM which, if
accurate and reliable, could increase the Company's annual NTS costs by
approximately $1 million, effective in 1997. NSPM intends to review and evaluate
the information provided, assess its reliability and compliance with FERC
guidelines and, if necessary, dispute amounts that they believe represent
increases due to inappropriately claimed facilities or inaccurate costs related
to claimed facilities These additional NTS costs have not been recognized in the
Sept. 30, 1997 financial statements. If any additional NTS costs are incurred,
they will be deferred as discussed in Note 2.
Item 2 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATION
Discussion of financial condition and liquidity is omitted per conditions
set forth in general instructions H (1) and (2) of Form 10-Q for wholly-owned
subsidiaries (reduced disclosure format).
The Company's net income for the quarter and nine months ended September
30, 1997 was $8.2 million and $25.5 million, respectively, an increase of $1.4
million and $0.3 million, respectively from the comparable periods a year ago.
The following analysis summarizes the specific revenue and expense items
impacting these results.
Except for the historical statements contained herein, the matters
discussed in the following discussion and analysis are forward-looking
statements that are subject to certain risks, uncertainties and assumptions.
Such forward-looking statements are intended to be identified in this document
by the words "anticipate", "estimate", "expect", "objective", "possible",
"potential" and similar expressions. Actual results may vary materially.
Factors that could cause actual results to differ materially include, but are
not limited to: general economic conditions, including their impact on capital
expenditures; business conditions in the energy industry; competitive factors;
unusual weather; changes in federal or state legislation; and the other risk
factors listed from time to time by the Company in reports filed with the SEC,
including Exhibit 99.01 to this report on Form 10-Q for the quarter ended
September 30, 1997.
Third Quarter 1997 Compared with Third Quarter 1996
Electric revenues in total increased $4.3 million or 4.7 percent for the third
quarter of 1997 compared with the third quarter of 1996. Sales to customers
increased $3.5 million mainly due to sales growth. On a weather-normalized
basis, sales increased 4.6 percent in the third quarter of 1997 compared to the
third quarter of 1996. The remaining $0.8 million increase in electric revenues
relates to higher Interchange Agreement billings to NSPM in 1997, reflecting an
increase in the Company's fuel expense.
Gas revenues for the third quarter of 1997 compared with the third quarter
of 1996 decreased $0.4 million or 4.1 percent primarily due to a change in the
proportion of gas sold between firm and interruptible classes in 1997.
Fuel for electric generation and Purchased and interchange power costs
combined increased $4.7 million or 10.8 percent for the third quarter of 1997
compared with the third quarter of 1996 primarily due to additional power
purchases from NSPM and the usage of higher cost peaking plants to support
increased sales levels.
Gas purchased for resale decreased $0.1 million or 2.4 percent in the third
quarter of 1997 compared with the third quarter of 1996 primarily due to larger
adjustments to match the cost of gas expense with the level of cost recovery in
customer rates.
Other operation, Maintenance, and Administrative and general expenses combined
decreased $1.4 million or 6.4 percent in the third quarter of 1997 compared with
the same period in 1996. Contributing to the decrease were lower employee
benefit expenses, lower fixed charges from NSPM relating to property insurance
and property taxes, and a retroactive adjustment for the deferral of NTS costs
incurred as a result of FERC Order No. 888 (as discussed in Note 2). Partially
offsetting these decreases were higher maintenance expenses in the transmission
and distribution area and higher customer service expenses in 1997.
Depreciation and amortization increased $0.4 million or 4.8 percent in the
third quarter of 1997 compared with the same period in 1996 due to increases in
the Company's plant in service.
Property and general taxes were approximately the same in both periods.
Income tax expense increased $0.7 million in the third quarter of 1997
compared with the third quarter of 1996 reflecting higher pretax operating
income in 1997.
Other income (expense) - net increased $0.7 million in the third quarter
of 1997 as compared with the same quarter in 1996 due to recognition of tax
adjustments and interest income related to the settlement of the disputed tax
issue with the State of Wisconsin (as discussed in Note 1).
Interest charges decreased $0.9 million in the third quarter of 1997
compared with the third quarter of 1996 primarily due to the reversal of
previously recorded interest expense associated with the settlement of the
disputed tax issue with the State of Wisconsin (as discussed in Note 1).
First Nine Months of 1997 Compared with First Nine Months of 1996
Electric revenues in total increased $4.9 million or 1.7 percent for the
first nine months of 1997 compared with the first nine months of 1996. Sales to
customers increased $3.8 million largely due to sales growth, partially offset
by less favorable weather in 1997. On a weather-normalized basis, sales
increased 3.5 percent in the first nine months of 1997 compared with the first
nine months of 1996. The remaining $1.1 million increase in electric revenues
relates to higher Interchange Agreement billings to NSPM in 1997, reflecting an
increase in the Company's fuel expense.
Gas revenues for the first nine months of 1997 compared with the first nine
months of 1996 increased $0.7 million or 1.2 percent. Higher costs per unit of
purchased gas, as discussed below, were reflected in customer rates through the
purchased gas adjustment clause mechanism. However, gas sales decreased 2.4
percent largely due to less favorable weather in 1997.
Fuel for electric generation and Purchased and interchange power costs
combined increased $5.8 million or 4.2 percent for the first nine months of 1997
compared with the first nine months of 1996 primarily due to additional power
purchases from NSPM and the usage of higher cost peaking plants to support
increased sales levels.
Gas purchased for resale increased $1.7 million or 4.2 percent in the first
nine months of 1997 compared with the first nine months of 1996 primarily due to
higher costs per unit of purchased gas charged by suppliers. Partially
offsetting the increase in unit costs were reduced purchases in 1997 due to
lower gas sales.
Other operation, Maintenance, and Administrative and general expenses combined
decreased $3.0 million or 4.6 percent in the first nine months of 1997 compared
with the same period in 1996. Contributing to the decrease were lower employee
benefit expenses, lower fixed charges from NSPM relating to property insurance
and property taxes, and lower maintenance expenses in the transmission and
distribution area. Partially offsetting the decrease were $1.4 million of
network transmission service costs incurred as a result of FERC Order No. 888
(net of regulatory deferrals as discussed in Note 2) and higher customer service
expenses in 1997.
Depreciation and amortization increased $1.7 million or 6.4 percent in the
first nine months of 1997 compared with the same period in 1996 due to increases
in the Company's plant in service.
Property and general taxes were approximately the same during both periods.
Income tax expense increased $0.5 million in the first nine months of 1997
compared with the first nine months of 1996 reflecting higher pretax operating
income in 1997.
Other income (expense) - net increased $0.2 million in the first nine months
of 1997 compared with the same period in 1996 primarily due to recognition of
tax adjustments and interest income related to the settlement of the disputed
tax issue with the State of Wisconsin (as discussed in Note 1) and higher
subsidiary earnings. Partially offsetting the increased income was the write-
off of deferred merger costs (as discussed in Note 1).
Interest expense decreased $0.9 million or 6.7 percent in the first nine
months of 1997 compared with the first nine months of 1996 due to the reversal
of previously recorded interest expense related to the settlement of the
disputed tax issue with the State of Wisconsin (as discussed in Note 1) and
lower short term debt levels in 1997.
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
The following exhibits are filed with this report:
27.01 Financial Data Schedule for the nine months ended Sept. 30,
1997.
99.01 Statement pursuant to Private Securities Litigation Reform
Act of 1995.
(b) Reports on Form 8-K
None
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
(Registrant)
/s/
Roger D. Sandeen
Controller
(Principal Accounting Officer)
/s/
Neal A. Siikarla
Treasurer
(Principal Financial Officer)
Date: November 14, 1997
EXHIBIT INDEX
Method of Exhibit Description
Filing No.
DT 27.01 Financial Data Schedule
DT 99.01 Statement pursuant to Private
Securities Litigation Reform
Act of 1995
DT = Filed electronically with this direct transmission.