FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549-1004
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 1995
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OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
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Commission File Number 1-5324
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NORTHEAST UTILITIES
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(Exact Name of registrant as specified in its charter)
MASSACHUSETTS 04-2147929
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(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
174 BRUSH HILL AVENUE, WEST SPRINGFIELD, MASSACHUSETTS (01090-0010)
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(Address of principal executive offices) (Zip Code)
(413) 785-5871
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(Registrant's telephone number, including area code)
Not Applicable
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Former name, former address, and formal 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 sorter 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
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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 31, 1995
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Common Shares, $5.00 par value 126,350,006 shares
NORTHEAST UTILITIES AND SUBSIDIARIES
TABLE OF CONTENTS
Page No.
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Part I. Financial Information
Item 1. Financial Statements
Consolidated Balance Sheets -
June 30, 1995 and December 31, 1994 2
Consolidated Statements of Income -
Three and Six Months Ended June 30,
1995 and 1994 4
Consolidated Statements of Cash Flows -
Six Months Ended June 30, 1995 and 1994 5
Notes to Consolidated Financial Statements 6
Report of Independent Public Accountants 9
Item 2. Management's Discussion and Analysis
of Financial Condition and Results
of Operations 10
Part II. Other Information
Item 1. Legal Proceedings 17
Item 4. Submission of Matters to a Vote
by Security Holders 17
Item 5. Other Information 18
Item 6. Exhibits and Reports on Form 8-K 20
Signatures 21
PART I. FINANCIAL INFORMATION
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
June 30, December 31,
1995 1994
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(Thousands of Dollars)
ASSETS
------
Utility Plant, at original cost:
Electric................................................ $ 9,400,210 $ 9,334,912
Other................................................... 158,516 157,632
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9,558,726 9,492,544
Less: Accumulated provision for depreciation......... 3,446,432 3,293,660
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6,112,294 6,198,884
Construction work in progress........................... 177,019 179,724
Nuclear fuel, net....................................... 218,569 224,839
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Total net utility plant............................. 6,507,882 6,603,447
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Other Property and Investments:
Nuclear decommissioning trusts, at market............... 290,978 240,229
Investments in regional nuclear generating
companies, at equity................................... 81,901 82,464
Investments in transmission companies, at equity........ 25,126 26,106
Other, at cost.......................................... 52,965 40,896
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450,970 389,695
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Current Assets:
Cash and special deposits............................... 31,325 34,579
Receivables, net........................................ 325,401 357,322
Accrued utility revenues................................ 127,581 142,788
Fuel, materials, and supplies, at average cost.......... 202,051 190,062
Prepayments and other................................... 65,991 54,886
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752,349 779,637
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Deferred Charges:
Regulatory assets:
Income taxes,net...................................... 1,117,415 1,124,119
Unamortized PSNH acquisition costs.................... 633,942 678,974
Deferred costs--nuclear plants........................ 197,188 233,145
Unrecovered contract obligation--Yankee Atomic
Electric Company..................................... 148,887 157,147
Recoverable energy costs, net......................... 323,281 268,982
Deferred demand-side-management costs................. 109,341 116,133
Cogeneration costs-CL&P............................... 75,354 36,821
Other................................................. 116,164 109,043
Unamortized debt expense................................ 38,722 33,517
Other .................................................. 46,995 54,220
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2,807,289 2,812,101
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Total Assets.............................................. $ 10,518,490 $ 10,584,880
============ ============
See accompanying notes to consolidated financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
June 30, December 31,
1995 1994
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(Thousands of Dollars)
CAPITALIZATION AND LIABILITIES
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Capitalization:
Common shareholders' equity:
Common shares, $5 par value--authorized
225,000,000 shares; 134,715,095 shares issued and
125,835,783 shares outstanding in 1995 and
134,210,226 shares issued and 124,962,981 shares
outstanding in 1994..................................... $ 673,576 $ 671,051
Capital surplus, paid in................................. 918,122 904,371
Deferred benefit plan--employee stock
ownership plan......................................... (205,532) (213,324)
Retained earnings........................................ 965,102 946,988
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Total common shareholders' equity................. 2,351,268 2,309,086
Preferred stock not subject to mandatory redemption........ 169,700 234,700
Preferred stock subject to mandatory redemption............ 306,250 375,250
Long-term debt............................................. 3,693,416 3,942,005
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Total capitalization.............................. 6,520,634 6,861,041
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Minority Interest in Consolidated Subsidiaries............... 100,040 -
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Obligations Under Capital Leases............................. 176,243 166,018
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Current Liabilities:
Notes payable to banks..................................... 147,500 180,000
Commercial paper........................................... 10,000 10,000
Long-term debt and preferred stock--current
portion................................................... 348,963 174,948
Obligations under capital leases--current
portion................................................... 63,614 73,103
Accounts payable........................................... 235,092 280,942
Accrued taxes.............................................. 44,608 57,532
Accrued interest........................................... 69,992 70,639
Accrued pension benefits................................... 87,032 90,194
Other...................................................... 101,330 98,296
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1,108,131 1,035,654
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Deferred Credits:
Accumulated deferred income taxes.......................... 2,033,282 1,968,230
Accumulated deferred investment tax credits................ 182,866 188,005
Deferred contract obligation--Yankee Atomic
Electric Company......................................... 148,887 157,147
Other...................................................... 248,407 208,785
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2,613,442 2,522,167
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Commitments and Contingencies (Note 4)<F4>
Total Capitalization and Liabilities.............. $ 10,518,490 $ 10,584,880
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See accompanying notes to consolidated financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
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1995 1994 1995 1994
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(Thousands of Dollars, except share information)
Operating Revenues............................. $ 840,333 $ 854,627 $ 1,785,038 $ 1,820,801
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Operating Expenses:
Operation --
Fuel, purchased and net interchange power.... 200,293 182,194 437,937 407,768
Other........................................ 223,187 220,021 449,740 440,195
Maintenance................................... 67,736 76,957 127,878 145,591
Depreciation.................................. 85,749 80,375 173,502 163,782
Amortization of regulatory assets, net........ 30,269 51,107 60,170 101,838
Federal and state income taxes................ 57,264 60,380 128,515 151,365
Taxes other than income taxes................. 59,031 59,905 124,804 127,015
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Total operating expenses............... 723,529 730,939 1,502,546 1,537,554
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Operating Income............................... 116,804 123,688 282,492 283,247
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Other Income:
Deferred nuclear plants return--other
funds...................................... 2,619 6,936 7,296 13,994
Equity in earnings of regional nuclear
generating and transmission companies...... 3,880 3,743 6,217 7,107
Other, net................................... 2,006 3,993 (2,637) 6,684
Income taxes--credit......................... 3,680 1,786 9,451 3,481
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Other income, net...................... 12,185 16,458 20,327 31,266
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Income before interest charges......... 128,989 140,146 302,819 314,513
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Interest Charges:
Interest on long-term debt................... 80,375 77,779 160,579 156,833
Other interest............................... 1,173 2,408 2,772 3,068
Deferred nuclear plants return--borrowed
funds..................................... (3,325) (11,984) (11,649) (23,816)
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Interest charges, net.................. 78,223 68,203 151,702 136,085
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Income after interest charges........... 50,766 71,943 151,117 178,428
Preferred Dividends of Subsidiaries............ 8,368 10,798 22,435 21,395
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Net Income..................................... $ 42,398 $ 61,145 $ 128,682 $ 157,033
============== ============= ============= =============
Earnings Per Common Share...................... $ 0.34 $ 0.49 $ 1.03 $ 1.26
============== ============= ============= =============
Common Shares Outstanding (average)............ 125,776,304 124,586,316 125,448,064 124,480,229
============== ============= ============= =============
See accompanying notes to consolidated financial statements.
NORTHEAST UTILITIES and SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Six Months Ended
June 30,
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1995 1994
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(Thousands of Dollars)
Operating Activities:
Income before preferred dividends of subsidiaries......... $ 151,117 $ 178,428
Adjustments to reconcile to net cash
from operating activities:
Depreciation............................................ 173,502 163,782
Deferred income taxes and investment tax credits, net... 85,173 69,685
Deferred nuclear plants return, net of amortization..... 42,737 20,937
Recoverable energy costs, net of amortization........... (57,207) (37,633)
Amortization of PSNH acquisition costs.................. 28,111 28,327
Deferred demand-side management, net of amortization.... 6,792 3,687
Other sources of cash................................... 84,928 10,672
Other uses of cash...................................... (59,529) (40,217)
Changes in working capital:
Receivables and accrued utility revenues................ 47,128 24,887
Fuel, materials, and supplies........................... (11,989) (5,248)
Accounts payable........................................ (45,850) (23,673)
Accrued taxes........................................... (12,924) 17,195
Other working capital (excludes cash)................... (8,972) (10,718)
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Net cash flows from operating activities.................... 423,017 400,111
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Financing Activities:
Issuance of common shares................................. 18,464 7,230
Issuance of long-term debt................................ - 485,000
Issuance of Monthly Income
Preferred Securities..................................... 100,000 -
Net (decrease) increase in short-term debt................ (32,500) 129,000
Reacquisitions and retirements of long-term debt.......... (81,048) (757,573)
Reacquisitions and retirements of preferred stock......... (133,175) (1,500)
Cash dividends on preferred stock......................... (22,435) (21,394)
Cash dividends on common shares........................... (110,313) (109,519)
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Net cash flows used for financing activities................ (261,007) (268,756)
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Investment Activities:
Investment in plant:
Electric and other utility plant........................ (110,387) (123,721)
Nuclear fuel............................................ (11,766) 8,816
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Net cash flows used for investments in plant.............. (122,153) (114,905)
Other investment activities, net.......................... (43,111) (18,002)
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Net cash flows used for investments......................... (165,264) (132,907)
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Net Decrease In Cash For The Period......................... (3,254) (1,552)
Cash and special deposits - beginning of period............. 34,579 32,008
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Cash and special deposits - end of period................... $ 31,325 $ 30,456
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See accompanying notes to consolidated financial statements.
NORTHEAST UTILITIES AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
1. General
The accompanying unaudited consolidated financial statements should be read in
conjunction with the Annual Report of Northeast Utilities
(the company or NU) on Form 10-K for the year ended December 31, 1994 (1994 Form
10-K). In the opinion of the company, the accompanying financial statements
contain all adjustments necessary to present fairly the financial position as of
June 30, 1995, the results of operations for the three and six months ended June
30, 1995 and 1994, and the statements of cash flows for the six months ended
June 30, 1995 and 1994. The results of operations for the three and six months
ended June 30, 1995 and 1994 are not necessarily indicative of the results
expected for a full year.
Certain reclassifications of prior period data have been made to conform with
the current period presentation.
2. Accounting for Long-Lived Assets
The company's accounting policies and the accompanying consolidated financial
statements conform to generally accepted accounting principles applicable to
rate-regulated enterprises and reflect the effects of the ratemaking process in
accordance with Statement of Financial Accounting Standards No. 71, "Accounting
for Certain Types of Regulation" (SFAS 71). In the event that any portion of
the company's operations is no longer subject to the provisions of SFAS 71, as a
result of a change in the cost-of-service based regulatory structure or the
effects of competition, the company would be required to write off related
regulatory assets and liabilities. In addition, the company would be required
to determine any impairment to other assets and write down these assets to their
fair value.
Statement of Financial Accounting Standards No. 121, "Accounting for the
Impairment of Long-Lived Assets and Long-Lived Assets to be Disposed Of" (SFAS
121), issued in March 1995 and effective January 1, 1996, establishes accounting
standards for the impairment of long-lived assets. SFAS 121 requires that
regulatory assets which are no longer probable of recovery through future
revenues be charged to earnings. Based upon the current regulatory environment
in the company's service area, it is not expected that SFAS 121 would have a
material impact on the financial position or results of operations of the
company upon adoption. This conclusion may change in the future as competitive
factors influence wholesale and retail pricing in the electric utility industry,
or if the cost-of-service based regulatory structure were to change.
3. Derivative Financial Instruments
The Connecticut Light and Power Company (CL&P), a wholly owned subsidiary of NU,
uses fuel-swap agreements with financial institutions to hedge against well-
defined fuel-price risk created by negotiated energy contracts. CL&P does not
use these agreements for trading purposes. Those fuel swap agreements minimize
exposure associated with rising fuel prices and effectively fix CL&P's cost of
fuel for these negotiated energy contracts. Under the swap agreements, CL&P
exchanges monthly payments based on the differential between a fixed or variable
price for the associated fuel. These swap agreements have been made with
various financial institutions, each of which is rated "A" or better by
Standards & Poor's rating group. CL&P is exposed to credit risk on its fuel
swaps if the counterparties fail to perform their obligations. However,
management anticipates that the counterparties will be able to fully satisfy
their obligations under the contracts.
As of August 10, 1995, CL&P had outstanding fuel-swap agreements with a total
notional value of approximately $257 million. As of July 31, 1995, the fuel-
swaps outstanding on that date had a negative mark-to-market position of
approximately $3 million.
For further information on Derivative Financial Instruments, see the Notes to
Consolidated Financial Statements in NU's March 31, 1995 Form 10-Q and in its
1994 Form 10-K.
4. Commitments and Contingencies
Construction Program: For information regarding the construction program, see
the Notes to Consolidated Financial Statements in NU's 1994 Form 10-K.
Nuclear Performance: For further information regarding the performance of the
NU system's nuclear units, see "Management's Discussion and Analysis of
Financial Condition and Results of Operations" in NU's March 31, 1995 Form 10-Q,
and the Notes to Consolidated Financial Statements in NU's 1994 Form 10-K.
PSNH Rate Agreement: Effective June 1, 1995, the sixth of seven successive 5.5
percent annual increases went into effect for PSNH's base retail rates. For
further information regarding the PSNH Rate Agreement, see the Notes to
Consolidated Financial Statements in NU's 1994 Form 10-K.
Environmental Matters: For additional information regarding environmental
matters, see the Notes to Consolidated Financial Statements in NU's March 31,
1995 Form 10-Q and 1994 Form 10-K.
Nuclear Insurance Contingencies: For information regarding nuclear insurance
contingencies, see the Notes to Consolidated Financial Statements in NU's 1994
Form 10-K.
Purchased Power Arrangements: For information regarding purchased power
arrangements, see the Notes to Consolidated Financial Statements in NU's 1994
Form 10-K.
Hydro-Quebec: For information regarding Hydro-Quebec, see the Notes to
Consolidated Financial Statements in NU's 1994 Form 10-K.
5. Workforce Reduction
For information regarding the NU system's workforce reduction program, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" in this Form 10-Q.
Report of Independent Public Accountants
----------------------------------------
To Northeast Utilities:
We have reviewed the accompanying consolidated balance sheet of Northeast
Utilities (a Massachusetts trust) and subsidiaries as of June 30, 1995, and the
related consolidated statements of income for the three and six-month periods
ended June 30, 1995 and 1994, and the consolidated statements of cash flows for
the six-month periods ended June 30, 1995 and 1994. These financial statements
are the responsibility of the company's management.
We conducted our review in accordance with standards established by the American
Institute of Certified Public Accountants. A review of interim financial
information consists principally of applying analytical procedures to financial
data and making inquiries of persons responsible for financial and accounting
matters. It is substantially less in scope than an audit conducted in
accordance with generally accepted auditing standards, the objective of which is
the expression of an opinion regarding the financial statements taken as a
whole. Accordingly, we do not express such an opinion.
Based on our review, we are not aware of any material modifications that should
be made to the financial statements referred to above for them to be in
conformity with generally accepted accounting principles.
/s/ Arthur Andersen LLP
Arthur Andersen LLP
Hartford, Connecticut
August 8, 1995
NORTHEAST UTILITIES AND SUBSIDIARIES
Management's Discussion and Analysis of Financial
Condition and Results of Operations
This section contains management's assessment of Northeast Utilities' (NU or the
company) financial condition and the principal factors having an impact on the
results of operations. This discussion should be read in conjunction with the
company's consolidated financial statements and footnotes and Management's
Discussion and Analysis in the 1994 Form 10-K and the First Quarter 1995 Form
10-Q.
FINANCIAL CONDITION
Overview
The company's earnings decreased to $1.03 per common share for the six months
ended June 30, 1995, from $1.26 for the same period in 1994. Earnings per share
decreased to $0.34 for the three months ended
June 30, 1995, from $0.49 for the same period in 1994. The decrease in earnings
from 1994 for the six-month period is primarily attributable to lower retail
kilowatt-hour sales as a result of mild weather in the first quarter of 1995 and
higher fuel and purchased-power costs, partially offset by the continued
deferral of cogeneration expenses in Connecticut and a reduction in maintenance
costs. NU's retail kilowatt-hour sales through June 1995 were down by 2.9
percent from 1994, which had colder than normal weather in the first quarter.
The decrease in earnings for the three-month period is primarily attributable to
higher fuel and purchased-power costs and lower revenues from wholesale sales.
Workforce Reductions
In July, 1995, NU announced a program aimed at reducing the nuclear
organization's total workforce by approximately 250 employees by the end of
January 1996. An early retirement program is available to approximately 155
eligible employees of NU's subsidiaries, who will be at least age 55 with ten
years of service as of January 1, 1996. The employees have until September 15,
1995, to make their decisions. The balance of the workforce reduction will be
achieved through attrition and layoffs. The estimated cost of the early
retirements and layoffs could be in the range of $10 to $12 million.
Retail Wheeling and Utility Restructuring
See "Part II. Item 5. Other Information" for updated information concerning
retail wheeling and utility restructuring.
Regulatory Matters
Connecticut
On June 30, 1995, the Department of Public Utility Control (DPUC) approved a
transaction between The Connecticut Light and Power Company (CL&P) and the
O'Brien EPA cogeneration facility (O'Brien) which allows CL&P to terminate its
existing agreement to purchase power from O'Brien and, in turn, enter into an
agreement to purchase an equivalent amount of power at lower rates from Citizens
Lehman Power LP. CL&P will apply 100% of the savings from the new agreements to
reduce the balance of deferred cogeneration expenses ($73 million as of June 30,
1995). The savings are estimated to be $59 million over 15 years with $39
million of the savings anticipated in the first 5 years. The transaction is
expected to close in August 1995.
New Hampshire
Effective June 1, 1995, Public Service Company of New Hampshire (PSNH) put into
effect the sixth of seven successive 5.5 percent annual retail rate increases
called for by the 1989 Rate Agreement. This action followed the failure of
negotiations with the Governor and the Attorney General of New Hampshire to
amend the 1989 Rate Agreement to address the future levels of PSNH's rates as
well as other items concerning the transition to a more competitive environment.
Furthermore, administrative decisions of the New Hampshire Public Utilities
Commission (NHPUC), legislation enacted by the New Hampshire legislature, and
comments by the Governor of New Hampshire have brought into question the future
regulatory environment in New Hampshire. PSNH plans to appeal the recent NHPUC
decision relating to the exclusivity of electric utility franchises in New
Hampshire and continues to evaluate other options for protecting its interests.
See "Part II. Item 5. Other Information" for more information regarding recent
legislation and the Freedom Electric Power Company decision.
The costs associated with purchases by PSNH from certain nonutility generators
(NUGs) over the level assumed in rates are deferred and recovered over ten-year
periods through the Fuel and Purchased Power Adjustment Clause (FPPAC). At June
30, 1995, the unrecovered deferrals were approximately $185 million.
PSNH has reached tentative agreements with the six remaining wood-fired NUGs.
These agreements will result in significant savings to customers if contracts
are finalized and approved by the NHPUC.
Nuclear Performance
The composite capacity factor of the five nuclear generating units that the NU
system operates -- including the Connecticut Yankee nuclear unit (CY) -- was
61.7 percent for the six months ended June 30, 1995, as compared with 61.0
percent for the same period in 1994. The low capacity factor in 1995 is
primarily the result of the extended refueling and maintenance outage for
Millstone 2.
The Millstone Unit 2 refueling and maintenance outage extended into July 1995 in
order to complete previously identified work. The Nuclear Regulatory Commission
completed its assessment of the unit's readiness to restart in late June, and in
a letter dated July 20, 1995, concluded that the deficiencies responsible for
the extended shutdown had been addressed and sufficient progress had been
demonstrated to support safe restart of the unit.
Additional work identified during start-up testing has now been completed, and
the unit returned to service on August 4, 1995. However, on August 8, 1995,
the unit shut down due to a pipe break in the turbine building, and the unit's
return to service is under evaluation.
Total replacement power costs attributable to the extension of the outage for
CL&P and Western Massachussetts Electric Company (WMECO) are in the range of $10
million per month. In addition, operation and maintenance (O&M) costs to be
incurred during the outage are estimated to be $69 million, an increase of $36
million as a result of the extended outage. The recovery of the replacement
power and O&M costs is subject to prudence reviews in both Connecticut and
Massachusetts.
CL&P has a mechanism that has been in operation since 1979 designed to recover
or refund certain nonnuclear fuel costs if the nuclear units do not operate at a
predetermined capacity factor (the Generation Utilization Adjustment Clause or
GUAC).
On June 12, 1995, CL&P won its appeal in The Connecticut Superior Court of the
GUAC disallowance (approximately $8 million) that occurred for the 1992-1993
GUAC year. The DPUC, the Connecticut Office of Consumer Counsel(OCC) and the
Connecticut Industrial Energy Consumers have subsequently appealed that decision
to the Connecticut Appellate Court. The disallowed portion of the 1993-1994
GUAC balance (approximately $8 million) is also under appeal in Superior Court.
However, a decision has not been issued in that case.
In August 1995, CL&P filed its annual GUAC filing with the DPUC. Subject to
regulatory approval, CL&P proposed to bill the GUAC amount for the period over
eighteen months rather than twelve. The GUAC deferral for the GUAC year ended
July 31, 1995 was approximately $98 million. However, in calculating the
amount to be billed, CL&P is required by a previous order of the DPUC (which is
under appeal in the proceeding mentioned in the previous paragraph) to reduce
the GUAC deferral by the amount of the base fuel "overrecoveries." The
overrecovery amount for this GUAC period is estimated to be $25 million. The
amount proposed to be billed to customers over the eighteen-month period
commencing September 1, 1995, is, therefore, approximately $73 million. As of
June 30, 1995, CL&P has reserved approximately $25 million for such
"overrecoveries" against the deferred GUAC costs.
While the company is unable to predict the outcome of possible prudence reviews
of its nuclear operations or the GUAC overrecoveries issues, management believes
that the ultimate resolution of these matters will not have a material adverse
impact on the company's financial position or the results of its operations.
In June 1995, Maine Yankee Atomic Power Company (Maine Yankee) began an
operation to sleeve all 17,000 tubes in the plant's three steam generators.
Maine Yankee expects that the plant will return to service near the end of 1995.
The approximate cost to Maine Yankee of the sleeving operation has been
determined to be $40 million, which will be expensed. The company through CL&P,
WMECO, and PSNH will be billed by Maine Yankee for its pro rata share
(aggregating 20 percent) of these costs over the next six months, under its
power contracts. In addition, CL&P, WMECO, and PSNH will incur additional costs
for replacement power (estimated at $1 million per month) until Maine Yankee
returns to service.
LIQUIDITY AND CAPITAL RESOURCES
Cash provided from operations increased approximately $23 million for the first
six months of 1995, as compared to 1994, primarily due to payments received
under a new wholesale power contract in 1995. Cash used for financing
activities decreased approximately $8 million primarily due to the issuance of
additional common shares in 1995 as a result of the company's Employee Stock
Ownership Plans. Cash used for investments increased approximately $32 million
primarily due to higher investments in the decommissioning trust in 1995.
RESULTS OF OPERATIONS
Comparison of the Second Quarter of 1995 with the Second Quarter
-----------------------------------------------------------------
of 1994
-------
Operating revenues decreased approximately $14 million in the second quarter of
1995, as compared with 1994. The components of the change in operating revenues
are as follows:
Changes in Operating Revenues Increase/(Decrease)
----------------------------- -------------------
(Millions of Dollars)
Regulatory decisions $ 16
Wholesale revenues (10)
Fuel, purchased power, and
FPPAC cost recoveries (7)
Other (13)
----
Total revenue change $(14)
====
Revenues related to regulatory decisions increased primarily because of the
retail rate increase for CL&P in July 1994 and the June 1994 and 1995 retail
rate increases for PSNH, partially offset by the June 1994 retail rate reduction
for WMECO. Wholesale revenues decreased primarily due to capacity sales
contracts that expired at the end of 1994. Fuel, purchased-power, and FPPAC
cost recoveries decreased primarily due to lower revenues from sales to non-
affiliated utilities. Other includes additional negotiated rate reductions for
retail customers. Retail kilowatt-hour sales were unchanged from 1994 for the
quarter.
Fuel, purchased, and net interchange power expense increased approximately $18
million in the second quarter of 1995, as compared with 1994, primarily because
of a higher level of energy purchases from other utilities as a result of the
extended Millstone 2 outage and a $6 million increase in the reserve for
overrecoveries against deferred GUAC costs.
Other operation expense increased approximately $3 million and maintenance
expense decreased approximately $9 million. The increase in operation expense
is due primarily to higher capacity charges from the regional nuclear units
primarily due to Maine Yankee, which is in an extended refueling outage, and
Vermont Yankee, which began an outage in March 1995. The decrease in
maintenance expense is due primarily to lower maintenance costs at the nuclear
and fossil units and lower storm costs.
Amortization of regulatory assets, net decreased approximately $20 million in
the second quarter of 1995, as compared with 1994, primarily because of the
deferral of CL&P cogeneration expenses of $6 million a month which began in July
1994.
Federal and state income taxes decreased approximately $5 million in the second
quarter of 1995, as compared with 1994, primarily because of lower book taxable
income.
Deferred nuclear plants return decreased approximately $13 million in the second
quarter of 1995, as compared with 1994, primarily because the last 5 percent of
CL&P's Millstone 3 investment was phased into rates on January 1, 1995, an
additional 15 percent of NAEC's Seabrook 1 investment was phased into rates on
May 1, 1995, and a one-time adjustment to NAEC's Seabrook 1 deferred return of
approximately $5 million in June 1995.
Comparison of the First Six Months of 1995 with the First Six
-------------------------------------------------------------
Months of 1994
--------------
Operating revenues decreased approximately $36 million in the first six months
of 1995, as compared with 1994. The components of the change in operating
revenues are as follows:
Operating Revenues Increase/(Decrease)
----------------------------- -------------------
(Millions of Dollars)
Regulatory decisions $ 38
Retail Sales volume (39)
Fuel, purchased power, and
FPPAC cost recoveries (16)
Wholesale revenues (13)
Other (6)
----
Total revenue change $(36)
====
Revenues related to regulatory decisions increased primarily because of the
retail rate increase for CL&P in July 1994 and the June 1994 and 1995 retail
rate increases for PSNH, partially offset by the June 1994 retail rate reduction
for WMECO. Retail sales volume decreased 2.9 percent for the first six months
of 1995 from 1994 sales levels primarily due to mild weather in the first
quarter of 1995. Fuel, purchased-power, and FPPAC cost recoveries decreased
primarily due to lower revenues from sales to non-affiliated utilities.
Wholesale revenues decreased primarily due to capacity sales contracts expiring
at the end of 1994.
Fuel, purchased, and net interchange power expense increased approximately $30
million in the first six months of 1995, as compared with 1994, primarily
because of a higher level of energy purchases from other utilities as a result
of the extended Millstone 2 outage and a $12 million increase in the reserve for
overrecoveries against deferred GUAC costs.
Other operation expense increased approximately $10 million and maintenance
expense decreased approximately $18 million. The increase in operation expense
is due primarily to higher capacity charges from the regional nuclear units
primarily due to Maine Yankee which is in an extended refueling outage and
Vermont Yankee which began an outage in March 1995. The decrease in maintenance
expense is due primarily to lower maintenance costs at the nuclear and fossil
units and lower storm costs.
Amortization of regulatory assets, net decreased approximately $42 million in
the first six months of 1995, as compared with 1994, primarily because of the
deferral of CL&P cogeneration expenses of $6 million a month which began in July
1994.
Federal and state income taxes decreased approximately $29 million in the first
six months of 1995, as compared with 1994, primarily because of lower book
taxable income and a first quarter adjustment to the tax accrual for a favorable
tax ruling.
Deferred nuclear plants return decreased approximately $19 million in the first
six months of 1995, as compared with 1994, primarily because the last 5 percent
of CL&P's Millstone 3 investment was phased into rates on January 1, 1995, an
additional 15 percent of NAEC's Seabrook 1 investment was phased into rates on
May 1, 1995, and because of a one-time adjustment to NAEC's Seabrook 1 deferred
return of $5 million in June 1995.
Other income decreased approximately $9 million in the first six months of 1995,
as compared with 1994, primarily because of an increase to the environmental
reserve, the write-down of CL&P's investment in Millstone 3 as a result of a
settlement agreement with the town of Wallingford, Connecticut, and the
amortization in 1994 of the customer portion of a 1993 property tax
disallowance.
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
1. On August 3, 1995, CL&P filed a petition for declaratory rulings with the
DPUC to determine whether Texas-Ohio Power Company (Texas-Ohio), which has built
a small cogeneration plant in Manchester, Connecticut, can sell electricity from
that plant to two CL&P retail customers in that town. On that same date, CL&P
also sought in Hartford Superior Court a temporary restraining order,
preliminary injunction and permanent injunction against Texas-Ohio selling
electricity to CL&P's retail customers.
2. On May 23, 1995, the U.S. Court of Appeals for the First Circuit affirmed
the Federal Energy Regulatory Commission's (FERC) order on the Seabrook Power
Contract. The court held that FERC had correctly applied the "public interest
standard" to modify terms of the contract. The order affects only future
changes to the Seabrook Power Contract, including changes to decommissioning
charges and rate of return.
For additional information on these proceedings, see "Item 3 - Legal
Proceedings" in NU's 1994 Form 10-K.
Item 4. Submission of Matters to a Vote of Security Holders{PRIVATE }
At the Annual Meeting of Shareholders of NU held on May 23, 1995, the
shareholders voted to fix the number of Trustees for the ensuing year at
thirteen. The vote fixing the number of Trustees was 107,521,831 votes in favor
and 2,707,017 votes against, with 2,741,364 abstentions and broker nonvotes.
At the Annual Meeting, the following thirteen nominees were elected to serve on
the Board of Trustees by the votes set forth below:
For Against Abstain
--- ------- -------
1. Alfred F. Boschulte 109,937,413 1,463,797 1,569,002
2. Cotton Mather Cleveland 110,289,041 1,112,168 1,569,002
3. George David 107,042,387 4,358,822 1,569,002
4. William B. Ellis 109,792,606 1,608,603 1,569,002
5. Bernard M. Fox 109,691,571 1,709,638 1,569,002
6. Gaynor N. Kelley 110,267,750 1,113,459 1,569,002
7. Elizabeth T. Kennan 110,202,379 1,198,830 1,569,002
8. Denham C. Lunt, Jr. 110,241,289 1,159,920 1,569,002
9. William J. Pape II 110,219,892 1,181,317 1,569,002
10. Robert E. Patricelli 110,270,267 1,130,942 1,569,002
11. Norman C. Rasmussen 110,268,270 1,132,939 1,569,002
12. John F. Swope 110,303,396 1,097,813 1,569,002
13. John F. Turner 109,997,715 1,403,494 1,569,002
NU's shareholders also ratified the Board of Trustees' selection of Arthur
Anderson LLP to serve as independent auditors of NU and its subsidiaries for
1995. The vote ratifying such selection was 109,127,834 votes in favor and
2,100,187 votes against, with 1,742,191 abstentions and broker nonvotes.
Item 5. Other Information
1. On June 20, 1995, the staff of the Securities and Exchange Commission
recommended "conditional repeal" of the Public Utility Holding Company Act of
1935 and substantial loosening of rules presently restricting NU's capital-
raising and diversification activities. Repeal is subject to approving
legislation in Congress, which has yet to be introduced. Comments on the rules
are due in September.
For additional information on this matter, see "Business - Public Utility
Regulation" in NU's 1994 Form 10-K.
2. On July 14, 1995, the Connecticut Department of Public Utility Control
(DPUC) issued its final decision in the Connecticut restructuring docket. The
decision stressed the importance of retaining the benefits of the existing
electric system, which it described as the "least costly and most reliable in
the world." The decision established thirteen principles to guide the
restructuring process in Connecticut. The decision also offered 25
recommendations for restructuring, which are generally consistent with NU's
"Path to a Competitive Future" restructuring proposal. One key conclusion was
that retail access could result in benefits to customers under certain
circumstances, but addressing the many transition issues must precede such
access. In addition, the decision concluded that utilities are entitled to a
reasonable opportunity to recover costs potentially stranded by the evolution
toward competitive markets.
For additional information on this matter, see "Business - Subsequent Events" in
NU's 1994 Form 10-K.
3. Under legislation effective June 19, 1995, the New Hampshire Public Utility
Commission (NHPUC) can approve a retail wheeling pilot program to begin no
earlier than January 1, 1996. The new law creates a legislative study committee
to investigate the future of the electric industry and state regulation, with a
scheduled report date of November 1995.
The bill also permits economic development and business retention rates to
be offered to new or expanding business and to manufacturers threatening to
leave the state or close their operations. PSNH filed economic development and
business retention rate tariffs on June 26, 1995. On July 14, 1995, the NHPUC
suspended the tariffs and denied PSNH's requests to approve the new rates on a
temporary basis.
For additional information on this matter, see "Business - Competition and
Marketing - Retail Marketing" in NU's 1994 Form 10-K.
4. On June 6, 1995, in a 2-1 decision involving Freedom Electric Power
Company's (FEPCo) petition to serve selected large PSNH customers, the NHPUC
found that electric utility franchises in New Hampshire are not exclusive as a
matter of law. The NHPUC also found that the approval of competition in PSNH's
territory in no way affected the State of New Hampshire's commitment to the 1989
Rate Agreement with PSNH because rates were not being affected. PSNH plans to
appeal this decision.
On July 14, 1995, FEPCo filed a petition for declaratory ruling with the
FERC requesting a ruling that FEPCo is entitled to wheeling services from PSNH.
For additional information on this proceeding, see "Business - Competition and
Marketing - Retail Marketing" in NU's 1994 Form 10-K.
5. On May 23, 1995, the NHPUC denied PSNH's motion for rehearing in PSNH's
least cost planning proceeding. In an April 1995 decision, the NHPUC had
required PSNH to conduct future resource planning based on only the economics of
PSNH, rather than the combined NU system.
For additional information on this proceeding, see "Other Information" in NU's
1995 Form 10-Q for the quarter ended March 31, 1995.
6. In June 1995, the State of South Carolina withdrew from membership in the
Southeast Interstate Low-Level Radioactive Waste Management Compact and
re-opened its Barnwell low-level radioactive waste (LLRW) disposal facility to
low-level waste generators from states situated outside that compact's region.
NU is arranging for disposal of its LLRW at Barnwell, and shipments are
presently scheduled to begin in mid-August. NU continues to explore other LLRW
disposal options.
For additional information on this matter, see "Business - Electric Operations -
Nuclear Generation - Low Level Radioactive Waste" in NU's 1994 Form 10-K.
7. On June 22, 1995, The United States Court of Federal Claims held in Yankee
------
Atomic Electric Company v. The United States that as applied to Yankee Atomic
--------------------------------------------
Electric Company (YAEC), the Uranium Enrichment Decontamination and
Decommissioning Fund, which pursuant to the 1992 Energy Policy Act imposes an
annual "special assessment" on domestic utilities, is an unlawful add-on to the
bargained-for contract price for enriched uranium. As a result, the federal
government must refund the approximately $3.0 million that YAEC has paid into
the fund since its inception. NU is evaluating the applicability of this
decision to the $21 million that the System companies have already paid into the
fund, and whether this alters the System companies' obligation to pay such
special assessments in the future. This decision is subject to appeal.
For additional information on this proceeding, see "Business - Electric
Operations - Nuclear Generation - Decommissioning" in NU's 1994 Form 10-K.
8. On May 25, 1995, approximately 370 union employees of WMECO and Holyoke
Water Power Company (HWP) initiated a strike against their respective companies.
The strike has had no material financial effect on NU to date.
For additional information on this proceeding, see "Business - Employees" in
NU's 1994 Form 10-K.
9. On August 1, 1995, pursuant to a management succession plan that was
introduced on January 29, 1992, William B. Ellis resigned as Chairman of NU's
Board of Trustees, and Bernard M. Fox assumed that position. Mr. Ellis also
resigned from the Board of Directors of NU's electric operating and certain
other of its subsidiaries.
For more information regarding this matter, see "Item 5. Other Events" in NU's
Form 8-K, dated January 29, 1992.
Item 6. Exhibits and Reports on Form 8-K
(a) Listing of Exhibits:
Exhibit
Number Description
------- -----------
15 Letter regarding unaudited financial information
27 Financial Data Schedule
(b) Reports on Form 8-K:
No reports on Form 8-K have been filed during this reporting period.
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 hereunto duly authorized.
NORTHEAST UTILITIES
-------------------
Registrant
Date August 11, 1995 By /s/ Bernard M. Fox
------------------ ----------------------------------
Bernard M. Fox
President and Chief
Executive Officer
Date August 11, 1995 By /s/ John W. Noyes
------------------ ----------------------------------
John W. Noyes
Vice President and Controller
Exhibit 15
August 8, 1995
To Northeast Utilities:
We are aware that Northeast Utilities has incorporated by reference in its
Registration Statement No. 33-34622, No. 33-40156, and No. 33-44814 its
Form 10-Q for the quarter ended June 30, 1995 which includes our report dated
August 8, 1995 covering the unaudited interim financial information contained
therein. Pursuant to Regulation C of the Securities Act of 1933, that report is
not considered a part of the registration statement prepared or certified by our
firm within the meaning of Sections 7 and 11 of the Act.
Very truly yours,
/s/ Arthur Andersen LLP
Arthur Andersen LLP