Company Profile
Blackstone Valley Electric Company (Blackstone or the Company) is a retail
electric utility company. Blackstone supplies retail electric service to
approximately 84,000 customers in the cities of Central Falls, Pawtucket and
Woonsocket, and four surrounding towns in northern Rhode Island. Blackstone is
a wholly owned subsidiary of Eastern Utilities Associates (EUA). EUA owns
directly all of the shares of common stock of Blackstone, Eastern Edison
Company (Eastern Edison) and Newport Electric Corporation (Newport). Eastern
Edison and Newport are retail electric utility companies operating in
southeastern Massachusetts and south coastal Rhode Island, respectively.
Eastern Edison owns all of the permanent securities of Montaup Electric Company
(Montaup), a generation and transmission company, which supplies electricity to
Blackstone, to Eastern Edison, to Newport and to two unaffiliated utilities for
resale. EUA also owns directly all of the shares of common stock of EUA
Cogenex Corporation (EUA Cogenex), EUA Energy Investment Corporation (EUA
Energy), EUA Ocean State Corporation (EUA Ocean State) and EUA Service
Corporation (EUA Service). EUA Service provides various accounting, financial,
engineering, planning, data processing and other services to all EUA System
companies. EUA Cogenex is an energy services company. EUA Energy was
organized to invest in energy-related projects. EUA Ocean State owns a 29.9%
interest in OSP's two gas-fired generating units. The holding company system
of EUA, the three retail subsidiaries, Montaup, EUA Service, EUA Cogenex, EUA
Energy and EUA Ocean State is referred to as the EUA System.
MARKET FOR BLACKSTONE'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
All of Blackstone's common stock is owned beneficially and of record by
EUA.
The dividends paid on common stock during the past two years are as
follows:
Dividends Paid Dividends Paid
1995 Per Share 1994 Per Share
First Quarter $5.35 First Quarter $4.17
Second Quarter 5.69 Second Quarter 4.88
Third Quarter 5.74 Third Quarter 4.93
Fourth Quarter 5.74 Fourth Quarter 5.44
No dividends may be paid on the common stock unless full dividends on the
outstanding preferred stock for all past and the current quarterly dividend
periods have been paid or declared and set apart for payment. Blackstone's
First Mortgage Indenture and Deed of Trust securing its First Mortgage Bonds
contains provisions which restrict the payment by Blackstone of cash dividends
on its common stock. See Notes C and D of Notes to Financial Statements and
Management's Discussion and Analysis of Financial Condition and Review of
Operations under Financial Condition and Liquidity.
SELECTED FINANCIAL DATA
For the Years Ended December 31,
(In Thousands) 1995 1994 1993 1992 1991
_______________________________________________________________________
Operating Revenues $140,861 $140,611 $143,666 $138,604 $142,276
Net Earnings 4,009 3,438 4,069 2,583 3,192
Total Assets 123,978 121,413 114,552 115,698 117,936
Capitalization:
Long-Term Debt 36,500 38,000 39,500 39,500 39,500
Non-Redeemable
Preferred Stock 6,130 6,130 6,130 6,130 6,130
Common Equity 37,045 37,180 35,378 34,551 34,755
Total Capitalization $ 79,675 $ 81,310 $ 81,008 $ 80,181 $ 80,385
======== ======== ======== ======== ========
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND REVIEW OF
OPERATIONS
Overview
Blackstone's net earnings for 1995 increased $600,000 to $4.0 million
compared to 1994 net earnings despite a one-time charge of approximately
$550,000, on an after-tax basis, related to the voluntary retirement incentive
(VRI) offer effective June 1, 1995 (See below). Kilowatthour (KWH) sales of
electricity increased by 1.1% for 1995. Sales to residential customers
increased by 2.6% and sales to industrial customers were up 1.0% for 1995
largely due to colder weather in the fourth quarter as compared to 1994.
Blackstone's net earnings for 1994 decreased by $600,000 to $3.4 million
and reflect the impacts of increases in other operating and maintenance
expenses, and an increase in interest expense related to audits by the Internal
Revenue Service on prior year tax returns. Through the third quarter of 1994,
KWH sales were showing modest gains, but as a result of a poor fourth quarter
in which KWH sales dropped by 1.1%, due to unusually mild weather, overall 1994
KWH sales were flat.
Voluntary Retirement Incentive Offer
On March 15, 1995, EUA announced a corporate reorganization which, among
other things, consolidated management of Eastern Edison, Blackstone and
Newport. As part of the reorganization, a voluntary retirement incentive (VRI)
was offered to sixty-six professionals of the EUA System, including nine
employees of Blackstone. Forty-nine of those eligible for the program,
including five Blackstone employees, accepted the incentive and retired
effective June 1, 1995. The cost of this incentive program amounted to a
one-time $900,000 pre-tax ($550,000 after-tax) charge to Blackstone's second
quarter 1995 earnings. The estimated payback period is approximately 18
months.
Comparison of Financial Results
Operating Revenues - 1995 vs 1994
Operating Revenues for 1995 increased by approximately $0.3 million as
compared to those in 1994 primarily due to an increase in base revenues,
attributable to a 1.1% increase in KWH sales. Purchased power recoveries
increased by approximately $800,000 (see Operating Expenses below) offset by a
$700,000 decrease in transmission rental revenue.
Operating Revenues - 1994 vs 1993
Operating Revenues for 1994 declined by approximately $3.1 million or
2.1%. Base revenues, attributable to changes in KWH sales, did not
significantly change as compared to 1993, while the level of purchased power
expense recoveries decreased approximately $2.8 million. Stagnant base
revenues were the result of flat KWH sales in 1994 and the reduction in
purchased power expense recoveries is the result of the decrease in the
underlying expense, discussed below.
Expenses - 1995 vs 1994
Purchased Power expense, which is recovered through Blackstone's purchased
power adjustment clause and represented 72% of total 1995 operating expense,
increased approximately $800,000 or less than 1.0% as compared to 1994. The
average cost of fuel increased 14.1% in 1995 compared to 1994. This increase
was partially offset by a wholesale rate decrease by the company's supplier,
Montaup effective May 21, 1994.
Other Operation and Maintenance expenses are comprised of two components,
Direct Controllable and Indirect. Direct Controllable expenses include expense
items such as salaries, fringe benefits, insurance, maintenance, etc. Indirect
expenses include items over which the Company has limited short-term control
including expenses related to accounting standards such as Statement of
Financial Accounting Standard No. 106, "Employers' Accounting for Post-
Retirement Benefits Other Than Pensions" (FAS106).
Other Operation and Maintenance expenses for 1995 decreased by
approximately $2.0 million or 9.3% when compared to 1994. This decrease is
primarily due to the Company's continued strict attention to cost control
including on-going savings related to the VRI, lower rent expense related to
the March 1995 purchase of the Company's general office and operations
buildings which were previously leased and decreased FAS106 expenses.
Net interest charges for 1995 decreased by approximately $400,000 or 8.7%.
This decrease was primarily due to decreased customer deposits interest and
Internal Revenue Service (IRS) audits of prior years' consolidated income tax
returns, which together aggregate over $300,000.
Taxes Other than Income for 1995 decreased by $400,000 or 4.0% compared to
1994 due primarily to a 1% decrease in Rhode Island Gross Receipts Tax to
industrial customers.
Expenses - 1994 vs 1993
Purchased Power expense, decreased approximately $2.8 million or 2.9% from
1993. This decrease was due primarily to a wholesale rate reduction
implemented May 21, 1994 by Montaup, Blackstone's supplier.
Other Operation and Maintenance expenses in 1994 increased by
approximately $300,000 or 2.9% as compared to 1993. Increased controllable
expenses primarily consisting of distribution costs caused this increase.
Net Interest Charges for 1994 increased by approximately $500,000 or
11.8%. Approximately $200,000 of the increase was as a result of interest
incurred related to an IRS audit of prior years' consolidated income tax
returns. The remaining $200,000 was primarily due to an increase in EUA
Service allocated interest expense. Prior to July 1, 1993, allocated EUA
Service interest expense was recorded as other operating expenses by
Blackstone.
Effective Income Tax Rate
Blackstone's 1995 effective income tax rate increased from approximately
34.1% to 35.4% when compared to 1994 due primarily to decreased consolidated
tax benefits.
Financial Condition and Liquidity
The Company is required to make capital expenditures in order to meet the
needs of its existing and future customers. For 1995, 1994 and 1993, the
Company's cash construction expenditures were $5.1 million, $5.7 million and
$5.3 million, respectively. In 1995 and 1994, internally generated funds
provided over 100% of cash construction requirements.
Cash Construction expenditures are expected to be $4.3 million in 1996,
$4.5 million in 1997 and $4.6 million in 1998 and are expected to be financed
with internally generated funds. Traditionally, construction requirements in
excess of internally generated funds are obtained through short-term borrowings
which are ultimately funded with permanent capital.
EUA System companies, including Blackstone, maintain short-term lines of
credit with various banks aggregating approximately $150 million. At December
31, 1995, unused short-term lines of credit amounted to approximately $111
million. These credit lines are available to other EUA System companies under
joint credit line arrangements. Blackstone had $1.3 million of short-term
borrowings outstanding at year end 1995, and zero at year-end 1994.
Blackstone's requirements for sinking fund payments and redemption of
securities for each of the five years following 1995 is $1.5 million.
Electric Utility Industry Restructuring
The electric industry is in a period of transition from a traditional rate
regulated environment to a competitive marketplace. While competition in the
wholesale electric market is not new, electric utilities are facing impending
competition in the retail sector.
In 1995, Eastern Edison, Blackstone and Newport participated with
collaborative groups in their respective states consisting of other utilities,
industrial users, environmental groups and consumer advocates in submitting
similar sets of interdependent principles with their respective state
regulatory commissions addressing electric utility industry restructuring.
These filings were intended to be statements of the consensus position by the
signatories of the principles that should underlie any electric industry
restructuring proposal and include but are not limited to principles addressing
stranded cost recovery, unbundling of services and demand side management
programs. Each set of principles was submitted on the condition they be
approved in full by the respective Commissions.
The Rhode Island Public Utilities Commission (RIPUC) accepted all but one
of the principles submitted by the Rhode Island Collaborative with minor
modifications to certain language in others and added a new principle which
supports negotiation (as opposed to litigation) to resolve conflicts as
restructuring moves forward and directed the Rhode Island Collaborative to
proceed with negotiations on the issues presented in the principles and to
submit a progress report, which was submitted in February 1996. The one
principle that was not accepted provided for subsidization of renewable energy
sources.
In February 1996 a bill was introduced in the Rhode Island legislature
that, if enacted, would allow customer choice of electricity supplier
commencing January 1, 1998 for large industrial customers and phasing in all
customers by January 1, 2001. The proposed legislation also provides for
recovery of "stranded investments" through a transition charge initially set at
three cents per KWH.
EUA believes that the development of the proposed legislation should have
been conducted in a public forum so that all interested stakeholders could have
participated. EUA believes that competition, if done right, can benefit
customers, however, there are substantial issues about the proposed legislation
which EUA is currently reviewing.
The Massachusetts Department of Public Utilities (MDPU) issued an order
enumerating principles, similar to those submitted by the Massachusetts
Collaborative, that describe the key characteristics of a restructured electric
industry and provides for, among other things, customer choice of electric
service providers, services, pricing options and payment terms, an opportunity
for customers to share in the benefits of increased competition, full and fair
competition in the generation markets and incentive regulation for distribution
services where competition cannot exist. This order sets out principles for
the transition from a regulated to a competitive industry structure and
identifies conditions for the transition process which will require investor-
owned utilities to unbundle rates, provide consumers with accurate price
signals and allow customers choice of generation services. The order also
provides for the principle of recovery of net, non-mitigable stranded costs by
investor-owned utilities resulting from the industry restructuring.
Each Massachusetts investor-owned utility is required to file
restructuring proposals for moving from the current regulated industry
structure to a competitive generation market. The schedule for the filing
requirement is staggered. The initial group of utilities was required to file
their proposals in February 1996. The second group is required to file within
three months of the MDPU's orders on the first group of submissions. Eastern
Edison Company filed its proposal, "Choice and Competition" (see below) with the
first group of proposals and is awaiting MDPU review.
In January 1996, EUA unveiled its preliminary proposal for a restructured
electric utility industry called "Choice and Competition" and began discussions
with the Rhode Island and Massachusetts Collaboratives. The plan proposes,
among other things: choice of power supplier by all customers as early as
January 1998; open access transmission services; performance based rates for
electric distribution services; all utility generation competing for power
sales and; a transition charge allowing regional utilities the opportunity to
recover, among other things, the costs of past commitments to nuclear and
independent power. The company believes the plan, which requires participation
by all New England parties, satisfies the principles adopted in both Rhode
Island and Massachusetts, and provides a fair and equitable transition to a
competitive electric utility marketplace for all parties.
Historically, electric rates have been designed to recover a utility's
full costs of providing electric service including recovery of investment in
plant assets. Also, in a regulated environment, electric utilities are subject
to certain accounting rules that are not applicable to other industries. These
accounting rules allow regulated companies, in appropriate circumstances, to
establish regulatory assets and liabilities, which defer the current financial
impact of certain costs that are expected to be recovered in future rates. EUA
believes that its Core Electric operations continue to meet the criteria
established in these accounting standards. Effects of legislation and/or
regulatory initiatives or EUA's own initiatives such as "Choice and
Competition" could ultimately cause EUA's Core Electric companies to no longer
follow these accounting rules. In such an event, a non-cash write-off of
regulatory assets and liabilities could be required at that time.
In addition, if legislative or regulatory changes and/or competition result in
electric rates which do not fully recover the company's costs, a write-down of
plant assets could be required pursuant to Financial Accounting Standard No.
121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to be Disposed Of" (FAS121) issued in March 1995, effective for fiscal
year 1996. See "Notes to Consolidated Financial Statements", Note A for
further discussion of FAS121.
Environmental Matters
Blackstone and other companies owning generating units from which power is
obtained are subject, like other electric utilities, to environmental and land
use regulations at the federal, state and local levels. The federal
Environmental Protection Agency (EPA), and certain state and local authorities,
have jurisdiction over releases of pollutants, contaminants and hazardous
substances into the environment and have broad authority to set rules and
regulations in connection therewith, such as the Clean Air Act Amendments of
1990, which could require installation of pollution control devices and
remedial actions. In 1994, an environmental audit program designed to ensure
compliance with environmental laws and regulations and to identify and reduce
liability was instituted by EUA.
Because of the nature of Blackstone's business, various by-products and
substances are produced or handled which are classified as hazardous under the
rules and regulations promulgated by such authorities. Blackstone generally
provides for the disposal of such substances through licensed contractors, but
these statutory provisions generally impose potential joint and several
responsibility on the generators of the wastes for cleanup costs. Blackstone
has been notified with respect to a number of sites where they may be
responsible for such costs, including sites where they may have joint and
several liability with other responsible parties. It is the policy of the EUA
System companies to notify liability insurers and to initiate claims, however,
Blackstone is unable to predict whether liability, if any, will be assumed by,
or can be enforced against, the insurance carriers in these matters.
As of December 31, 1995, Blackstone had incurred costs of approximately
$4.1 million, in connection with these sites. These amounts have been financed
primarily by internally generated cash. Blackstone is currently recovering
certain of its incurred environmental costs in rates. As a result of the
recoverability in current rates of environmental costs, and the uncertainty
regarding both its estimated liability, as well as potential contributions from
insurance carriers, Blackstone does not believe that the ultimate impact of
environmental costs will be material to their financial position and thus, no
loss provision is required at this time.
Blackstone estimates that additional costs of up to $2.5 million may be
incurred at these sites through 1997 by it and the other responsible parties.
Estimates beyond 1997 cannot be made since site studies, which are the basis of
these estimates, have not been completed.
In addition to the previously discussed costs, Blackstone is currently
litigating responsibility for clean-up costs and related interest aggregating
$5.9 million incurred by the Commonwealth of Massachusetts at a site in which
Blackstone has been named as the responsible party. See Note H of "Notes to
Consolidated Financial Statements" for further discussion.
A number of scientific studies in the past several years have examined the
possibility of health effects from electric and magnetic fields (EMF) that are
found everywhere there is electricity. Research to date has not conclusively
established a direct causal relationship between EMF exposure and human health.
Additional studies, which are intended to provide a better understanding of the
subject, are continuing. Management cannot predict the ultimate outcome of the
EMF issue.
The Company occasionally makes forward-looking projections of expected
future performance or statements of our plans and objectives. These forward-
looking statements may be contained in filings with the Securities and Exchange
Commission, press releases and oral statements. Actual results could differ
materially from these statements, therefore, no assurances can be given that
such forward-looking statements and estimates will be achieved.
Managements' Discussion and Analysis of Financial Condition and Review of
Operations provides a summary of information regarding the Company's financial
condition and results of operation and should be read in conjunction with the
Consolidated Financial Statements and Notes to Consolidated Financial
Statements in arriving at a complete understanding of such matters.
Blackstone Valley Electric Company
Statement of Income
Years Ended December 31,
(In Thousands)
1995 1994 1993
Operating Revenues $ 140,861 $ 140,611 $ 143,666
Operating Expenses:
Purchased Power (princ. from an affiliate) 95,725 94,970 97,804
Other Operation and Maintenance 10,938 13,405 12,712
Voluntary Retirement Incentive 912
Affiliated Company Transactions 8,280 7,787 8,220
Depreciation 5,501 5,303 5,122
Taxes - Other than Income 8,821 9,202 9,508
Income and Deferred Taxes 2,347 1,885 1,988
Total Operating Expenses 132,524 132,552 135,354
Operating Income 8,337 8,059 8,312
Allowance for Other Funds Used During
Construction 33 39 43
Other Income (Deductions) - Net (38) 78 (18)
Income Before Interest Charges 8,332 8,176 8,337
Interest Charges:
Interest on Long-Term Debt 3,481 3,476 3,449
Other Interest Expense 612 1,009 568
Allowance for Borrowed Funds Used
During Construction (Credit) (59) (36) (38)
Net Interest Charges 4,034 4,449 3,979
Net Income 4,298 3,727 4,358
Preferred Dividend Requirements 289 289 289
Net Earnings Applicable to Common Stock $ 4,009 $ 3,438 $ 4,069
Statement of Retained Earnings
1994 1993
1995 (Restated) (Restated)
Retained Earnings - Beginning of Year $ 10,069 $ 10,204 $ 9,378
Net Income 4,298 3,727 4,358
Total 14,367 13,931 13,736
Dividends Paid:
Preferred 289 289 289
Common 4,144 3,573 3,243
Retained Earnings - End of Year $ 9,934 $ 10,069 $ 10,204
The accompanying notes are an integral part of the financial statements.
Blackstone Valley Electric Company
Statement of Cash Flows
Years Ended December 31,
(In Thousands)
1995 1994 1993
CASH FLOW FROM OPERATING ACTIVITIES:
Net Income $ 4,298 $ 3,727 $ 4,358
Adjustments to Reconcile Net Income
to Net Cash Provided from Operating Activities:
Depreciation and Amortization 5,953 6,157 5,918
Deferred Taxes 1,200 176 397
Investment Tax Credit, Net (183) 253 (176)
Allowance for Funds Used During Construction (34) (39) (43)
Other - Net 643 (6,072) (30)
Net Changes in Operating Assets and Liabilities:
Accounts Receivable (2,324) (603) 372
Materials and Supplies (172) (27) 124
Accounts Payable 7,540 1,484 (2,399)
Accrued Taxes 337 (1,280) (83)
Other - Net (7,239) 5,454 436
Net Cash Provided from Operating Activities 10,019 9,230 8,874
CASH FLOW FROM INVESTING ACTIVITIES:
Construction Expenditures (5,064) (5,653) (5,344)
Net Cash (Used in) Investing Activities (5,064) (5,653) (5,344)
CASH FLOW FROM FINANCING ACTIVITIES:
Redemptions:
Long-Term Debt (1,500)
Premium on Reacquisition
and Financing Expenses (100)
Common Share Dividends Paid (4,144) (3,573) (3,243)
Preferred Dividends Paid (289) (289) (289)
Net Increase in Short-Term Debt 1,259
Net Cash (Used in) Financing Activities (4,674) (3,862) (3,632)
Net Increase (Decrease) in Cash 281 (285) (102)
Cash and Temporary Cash Investments at
Beginning of Year 472 757 859
Cash and Temporary Cash Investments at
End of Year $ 753 $ 472 $ 757
Cash paid during the year for:
Interest (Net of Amounts Capitalized) $ 3,565 $ 3,506 $ 3,480
Income Taxes $ 690 $ 1,836 $ 2,430
The accompanying notes are an integral part of the financial statements.
Blackstone Valley Electric Company
Balance Sheet
December 31,
(In Thousands)
ASSETS
1994
1995 (Restated)
Utility Plant and Other Investments:
Utility Plant $ 136,503 $ 133,415
Less Accumulated Provision for Depreciation 48,023 44,112
Net Utility Plant 88,480 89,303
Non-Utility Property - Net 47 48
Total Utility Plant and Other Investments 88,527 89,351
Current Assets:
Cash and Temporary Cash Investments 753 472
Accounts Receivable:
Customers, Net 11,254 11,002
Accrued Unbilled Revenue 1,339 1,217
Others 4,726 2,736
Associated Companies 429 470
Plant Materials and Operating Supplies (at average cost) 939 767
Other Current Assets 393 422
Total Current Assets 19,833 17,086
Other Assets (Note A) 15,618 14,976
Total Assets $ 123,978 $ 121,413
LIABILITIES AND CAPITALIZATION
Capitalization:
Common Equity $ 37,045 $ 37,180
Non-Redeemable Preferred Stock 6,130 6,130
Long-Term Debt 36,500 38,000
Total Capitalization 79,675 81,310
Current Liabilities:
Long-Term Debt Due Within One Year 1,500 1,500
Notes Payable 1,259
Accounts Payable:
Public 282 603
Associated Companies 17,371 9,509
Customer Deposits 992 1,210
Taxes Accrued 1,777 1,441
Dividends Accrued 72 72
Interest Accrued 981 1,070
Other Current Liabilities 431 7,391
Total Current Liabilities 24,665 22,796
Deferred Credits:
Unamortized Investment Credit 2,743 2,927
Other Deferred Credits 7,979 6,814
Total Deferred Credits 10,722 9,741
Accumulated Deferred Taxes 8,916 7,566
Commitments and Contingencies (Note H)
Total Liabilities and Capitalization $ 123,978 $ 121,413
The accompanying notes are an integral part of the financial statements.
Blackstone Valley Electric Company
Statement of Capitalization
December 31,
(In Thousands)
1994
1995 (Restated)
Common Stock, $50 par value, authorized 233,000
shares, issued and outstanding 184,062 shares $ 9,203 $ 9,203
Other Paid-in Capital 17,908 17,908
Retained Earnings 9,934 10,069
Total Common Equity 37,045 37,180
Non-Redeemable Cumulative Preferred Stock:
4.25%, $100 par value, 35,000 shares <F1> 3,500 3,500
5.60%, $100 par value, 25,000 shares <F1> 2,500 2,500
Premium 130 130
Total Non-Redeemable Cumulative Preferred Stock 6,130 6,130
Long-Term Debt:
First Mortgage Bonds:
9 1/2% due 2004 (Series B) 13,500 15,000
10.35% due 2010 (Series C) 18,000 18,000
Variable Rate Demand Bonds Due 2014 <F2> 6,500 6,500
38,000 39,500
Less Portion Due Within One Year 1,500 1,500
Total Long-Term Debt 36,500 38,000
Total Capitalization $ 79,675 $ 81,310
<FN>
<F1> Authorized and Outstanding.
<F2> Weighted average interest rate was 3.9% for 1995 and 2.9% for 1994.
</FN>
The accompanying notes are an integral part of the financial statements.
BLACKSTONE VALLEY ELECTRIC COMPANY
NOTES TO FINANCIAL STATEMENTS
December 31, 1995, 1994 and 1993
(A) Nature of Operations and Summary of Significant Accounting
Policies:
General: Blackstone Valley Electric Company (Blackstone or the Company) is
principally engaged in the distribution and sale of electric energy.
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates.
The accounting policies and practices of Blackstone are subject to
regulation by FERC and RIPUC with respect to its rates and accounting.
Blackstone conforms with generally accepted accounting principles, as applied
in the case of regulated public utilities, and conforms with the accounting
requirements and ratemaking practices of the RIPUC. A description of the
significant accounting policies follows.
Restatement: The Company has restated prior period balance sheets to
correct an error in the accrual of property tax expense. The Company had
previously over-accrued property tax expense. This correction increased
retained earnings by $1.9 million, lowered taxes accrued by $3.0 million and
increased accumulated deferred taxes by $1.1 million.
Reclassifications: Certain prior period amounts on the financial
statements have been reclassified to conform with current
presentation.
Transactions with Affiliates: The Company is a wholly-owned
subsidiary of EUA. In addition to its investment in the Company, EUA
has interests in other retail and wholesale utility companies, a
service corporation, and three other non-utility companies.
Transactions between Blackstone and other affiliated companies
include the following: purchased power costs billed by Montaup of
approximately $95,683,000 in 1995, $94,944,000 in 1994 and
$97,774,000 in 1993; accounting, engineering and other services
rendered by EUA Service of approximately $10,448,000 in 1995,
$9,524,000 in 1994 and $9,335,000 in 1993; and operating revenue from
the rental of transmission facilities to Montaup of approximately
$3,047,000 in 1995, $2,665,000 in 1994 and $2,884,000 in 1993.
Transactions with affiliated companies are subject to review by
applicable regulatory commissions.
Utility Plant and Depreciation: Utility plant is stated at
original cost. The cost of additions to utility plant includes
contracted work, direct labor and material, allocable overhead,
allowance for funds used during construction and indirect charges for
engineering and supervision. For financial statement purposes,
depreciation is computed on the straight-line method based on
estimated useful lives of the various classes of property.
Provisions for depreciation were equivalent to a composite rate of
approximately 3.9% in 1995, 1994, and 1993 based on the average
depreciable property balances at the beginning and end of each year.
Other Assets: The components of Other Assets at December 31,
1995 and 1994 are detailed as follows (in thousands):
1995 1994
Regulatory Assets:
Unamortized losses on reacquired debt $ 455 $ 486
Deferred SFAS 109 costs (Note B) 1,996 2,164
Deferred SFAS 106 costs (Note H) 1,017 1,017
Mendon Road Judgment (Note H) 6,591 5,857
Other regulatory assets 959 1,590
Total regulatory assets 11,018 11,114
Other deferred charges and assets:
Unamortized debt expenses 710 795
Other 3,890 3,067
Total Other Assets $15,618 $14,976
Regulatory Accounting: Blackstone is subject to certain
accounting rules that are not applicable to other industries. These
accounting rules allow regulated companies, in appropriate
circumstances, to establish regulatory assets and liabilities, which
defer the current financial impact of certain costs that are expected
to be recovered in future rates. Blackstone believes that its
operations continue to meet the criteria established in these
accounting standards. Effects of legislation and/or regulatory
initiatives or EUA's own initiatives such as "Choice and Competition"
could ultimately cause Blackstone to no longer follow these
accounting rules. In such an event, a non-cash write-off of
regulatory assets and liabilities could be required at that time.
Allowance for Funds Used During Construction (AFUDC): AFUDC
represents the estimated cost of borrowed and equity funds used to
finance the Company's construction program. In accordance with
regulatory accounting, AFUDC is capitalized, as a cost of utility
plant, in the same manner as certain general and administrative costs.
AFUDC is not an item of current cash income, but is recovered over
the service life of utility plant in the form of increased revenues
collected as a result of higher depreciation expense. The rate used
in calculating AFUDC was 8.6% in 1995, 10.0% in 1994 and 9.8% in
1993.
Operating Revenues: Revenues are based on billing rates
authorized by the RIPUC. The Company follows the policy of accruing
the estimated amount of unbilled base rate revenues for electricity
provided at the end of the month to more closely match costs and
revenues. In addition the Company also accrues the difference
between fuel and purchased power costs incurred and fuel and
purchased power costs billed to its customers.
Federal Income Taxes: The general policy of Blackstone with
respect to accounting for federal income taxes is to reflect in
income the estimated amount of taxes currently payable, as determined
from the EUA consolidated tax return on an allocated basis, and to
provide for deferred taxes on certain items subject to temporary
differences to the extent permitted by the regulatory commissions.
Blackstone has provided deferred income taxes on certain income
and expense items that are accounted for in different periods for
financial accounting purposes than for income tax purposes. Prior
to 1987, AFUDC and certain costs for pensions, employee benefits and
payroll-related insurances and payroll taxes applicable to
construction activity, which were included in utility plant, were
deducted currently for income tax purposes. Deferred taxes on these
amounts and on certain differences created by the use of different
depreciation methods in the years prior to 1981 have not been
provided. The tax benefits on these items have been flowed through
in accordance with approved rate orders of the RIPUC.
As permitted by the regulatory commissions, it is the policy of
the Company to defer recognition of annual investment tax credits and
to amortize these credits over the productive lives of the related
assets.
Cash and Temporary Cash Investments: Blackstone considers all
highly liquid investments and temporary cash investments with a
maturity of three months or less when acquired to be cash
equivalents.
New Accounting Standard: In March 1995, the Financial Accounting
Standards Board issued Statement of Financial Accounting Standard No.
121, "Accounting for the Impairment of Long-Lived Assets and for
Long-Lived Assets to be Disposed of" (FAS 121), effective for fiscal
year 1996. FAS 121 requires all regulatory assets, assets which were
established as a result of high probability of recovery in a
regulated environment, to continue to meet that high probability of
recovery at each balance sheet date. Based on the current regulatory
framework, management does not expect that adoption of this standard
will have a material effect on Blackstone's financial position or
results of operation. However, this assumption may change in the
future as changes are made in the current regulatory framework or as
competitive factors influence wholesale and retail pricing in the
electric utility industry.
(B) Income Taxes:
Components of income and deferred tax expense for the years 1995,
1994, and 1993 are as follows:
_________________________________________________________________
(In Thousands) 1995 1994 1993
Federal:
Current $1,329 $1,436 $1,751
Deferred 1,133 176 409
Investment Tax Credit, Net (184) 253 (176)
$2,278 1,865 1,984
State:
Current 1 20 15
Deferred 68 (11)
69 20 4
Charged to Operations 2,347 1,885 1,988
Charged to Other Income:
Current 3 46 (9)
Total $2,350 $1,931 $1,979
====== ====== ======
Total income tax expense was different than the amounts computed
by applying federal income tax statutory rates to book income subject
to tax for the following reasons:
__________________________________________________________________
(In Thousands) 1995 1994 1993
Federal Income Tax Computed
at Statutory Rates $2,327 $1,980 $2,217
(Decreases) Increases in Tax from:
Equity Component of AFUDC (12) (14) (15)
Consolidated Tax Savings (15) (125) (51)
Depreciation Differences 262 260 358
Amortization of ITC (184) (194) (176)
State Taxes, Net of Federal
Income Tax Benefit 45 13 3
Cost of Removal (67) (110) (245)
Other (6) 121 (113)
Total Income Tax Expense $2,350 $1,931 $1,978
====== ====== ======
Blackstone adopted Statement of Financial Accounting Standard
No. 109, "Accounting for Income Taxes" (FAS109) which required
recognition of deferred income taxes for temporary differences that
are reported in different years for financial reporting and tax
purposes using the liability method. Under the liability method,
deferred tax liabilities or assets are computed using the tax rates
that will be in effect when the temporary differences reverse.
Generally, for regulated companies, the change in tax rates may not
be immediately recognized in operating results because of rate making
treatment and provisions in the Tax Reform Act of 1986. At December
31, 1995 and 1994 no valuation allowance was deemed necessary for
total deferred tax assets. Total deferred tax assets and liabilities
for 1995 and 1994 are comprised as follows:
Deferred Tax Deferred Tax
Assets Liabilities
($000) ($000)
1995 1994 1995 1994
Plant Related Plant Related
Differences $1,730 $1,980 Differences $ 8,540 $8,192
Alternative Refinancing
Minimum Tax 0 69 Costs 155 165
Revenue Clauses 0 203 Pensions 556 536
Pensions 501 201
Other 609 642 Other 2,496 712
Total $2,840 $3,095 Total $11,747 $9,605
====== ====== ======= ======
Blackstone has recorded on its Balance Sheets as of December 31,
1995 and 1994 a regulatory liability to ratepayers of approximately
$3.4 million and $3.7 million, respectively. This amount primarily
represents excess deferred income taxes resulting from the reduction
in the federal income tax rate and also includes deferred taxes
provided on investment tax credits. Also at December 31, 1995 and
1994, a regulatory asset of approximately $2.0 million and $2.2
million, respectively, has been recorded, representing the cumulative
amount of federal income taxes on temporary depreciation differences
which were previously flowed through to ratepayers.
(C) Capital Stock:
There were no changes in the number of shares of common or
preferred stock during the years ended December 31, 1995 and 1994.
In the event of involuntary liquidation, the holders of non-redeemable
preferred stock of Blackstone are entitled to $100 per share plus accrued
dividends. In the event of voluntary liquidation,
or if redeemed at the option of the Company, each share of the non-redeemable
preferred stock is entitled to accrued dividends and to: 4.25% issue, $104.40;
5.60% issue, $103.82.
Under the terms and provisions of the First Mortgage Indenture
and of the issues of preferred stock of Blackstone, certain
restrictions are placed upon the payment of dividends on common stock
by the Company. At the years ended December 31, 1995 and 1994, the
respective capitalization ratios were in excess of the minimum which
would make these restrictions effective.
(D) Retained Earnings:
Under the provisions of Blackstone's First Mortgage Indenture,
retained earnings in the amount of $4,937,576 were unrestricted as
to the payment of cash dividends on its common stock at December 31,
1995.
(E) Long-Term Debt:
Blackstone's First Mortgage Bonds are collateralized by
substantially all of its utility plant.
Blackstone's Variable Rate Demand Bonds are collateralized by an
irrevocable letter of credit which expires on January 21, 1997. The
letter of credit permits extensions on an annual basis upon mutual
agreement of the bank and Blackstone.
The aggregate amount of Blackstone's cash sinking fund
requirements and maturities for long-term debt for each of the five
years following 1995 is $1.5 million.
(F) Lines of Credit:
The EUA System Companies, which include Blackstone, maintain
short-term lines of credit with various banks aggregating
approximately $150 million. At December 31, 1995, unused short-term
lines of credit amounted to approximately $111 million. These credit
lines are available to other EUA System companies under joint credit
line arrangements. In accordance with informal agreements with
various banks, commitment fees are required to maintain certain lines
of credit. Blackstone had $1.3 million of short-term borrowings
outstanding at year end. During 1995, Blackstone's weighted average
interest rate for short-term borrowings was 6.1%.
(G) Fair Value of Financial Instruments:
The following methods were used to estimate the fair value of
each class of financial instruments for which it is practicable to
estimate.
Cash and Temporary Cash Investments: The carrying amount
approximates fair value because of the short-term maturity of those
instruments.
Long-Term Debt: The fair value of the Company's long-term debt
was based on quoted market prices for such securities.
The estimated fair values of the Company's financial instruments
at December 31, 1995 are as follows (dollars in thousands):
Carrying Fair
Amount Value
Cash and Temporary
Cash Investments $ 753 $ 753
Long-Term Debt $38,000 $39,366
(H) Commitments and Contingencies:
Pensions: Blackstone participates with other EUA System
companies in retirement plans which are non-contributory, defined
benefit plans covering substantially all of their employees
(Retirement Plan). Retirement Plan benefits are based on years of
service and average compensation over the four years prior to
retirement. It is the EUA System's policy to fund the Retirement
Plan on a current basis in amounts determined to meet the funding
standards established by the Employee Retirement Income Security Act
of 1974.
Net pension expense (income) for the Retirement Plan, including
amounts related to the 1995 voluntary retirement incentive, was
$271,682 in 1995, $38,487 in 1994 and $(175,796) in 1993 and included
the following components:
1995 1994 1993
Service cost - benefits earned
during the period $ 605,703 $ 696,133 $ 567,204
Interest cost on projected
benefit obligation 2,346,136 2,186,115 2,186,619
Act. loss (return) on assets (9,560,143) 396,900 (4,710,888)
Net amortization and deferrals 6,470,282 (3,240,661) 1,781,269
Net periodic pension
expense (income) $ (138,022) $ 38,487 $ (175,796)
Voluntary retirement incentive 409,704
Total periodic pension
expense (income) $ 271,682 $ 38,487 $ (175,796)
========== =========== ===========
Assumptions used to determine pension cost:
Discount Rate 8.25% 7.25% 8.75%
Compensation Increase Rate 4.75% 4.75% 6.00%
Long-Term Return on Assets 9.50% 9.50% 10.00%
The discount rate and compensation increase rate used to
determine pension costs were changed effective January 1, 1996 to
7.25% and 4.25%, respectively. The funded status of the Retirement
Plan cannot be presented separately for Blackstone as it participates
in the Retirement Plan with other subsidiaries of EUA.
The one-time voluntary retirement incentive also resulted in
approximately $310,000 of non-qualified pension benefits which were
expensed in 1995. At December 31, 1995, approximately $185,000 is
included in other liabilities for the unfunded benefits.
EUA also maintains non-qualified supplemental retirement plans
for certain officers of the EUA System (Supplemental Plans).
Benefits provided under the Supplemental Plans are based primarily
on compensation at retirement date. EUA maintains life insurance on
the participants of the Supplemental Plans to fund in whole, or in
part, its future liabilities under the Supplemental Plans. For the
years ended December 31, 1995, 1994 and 1993 expenses related to the
Supplemental Plans were approximately $306,000, $147,000 and
$568,000, respectively.
Post-Retirement Benefits: Retired employees are entitled to
participate in health care and life insurance benefit plans. Health
care benefits are subject to deductibles and other limitations.
Health care and life insurance benefits are partially funded by
Blackstone for all qualified employees.
Blackstone adopted FAS106, "Employers' Accounting for Post-Retirement
Benefits Other Than Pensions," as of January 1, 1993.
This standard establishes accounting and reporting standards for such
post-retirement benefits as health care and life insurance. Under
FAS106 the present value of future benefits is recorded as a periodic
expense over employee service periods through the date they become
fully eligible for benefits. With respect to periods prior to
adopting FAS106, EUA elected to recognize accrued costs (the
Transition Obligation) over a period of 20 years, as permitted by
FAS106. The resultant annual expense, including amortization of the
Transition Obligation and net of capitalized and deferred amounts,
was approximately $1.3 million in 1995, $1.5 million in 1994 and $1.3
million in 1993. The total cost of Post-Retirement Benefits other
than Pensions for 1995, 1994 and 1993 includes the following
components (in thousands):
1995 1994 1993
Service cost $ 191 $ 299 $ 266
Interest cost 1,170 1,323 1,504
Actual return on plan assets (111) (20) (10)
Amortization of transition obligation 829 866 866
Net other amortization & deferrals (239) (10) (3)
Net periodic post-retirement benefit costs 1,840 2,458 2,623
Voluntary Retirement Incentive 90
Total periodic post-retirement benefit costs $1,930 $2,458 $2,623
Assumptions:
Discount rate 8.25% 7.25% 8.75%
Health care cost trend rate-near-term 11.00% 13.00% 13.00%
Health care cost trend rate-long-term 5.00% 5.00% 6.25%
Compensation increase rate 4.75% 4.75% 6.00%
Rate of return on plan assets 5.50% 5.50% 5.50%
Reconciliation of funded status:
1995 1994 1993
Accumulated post-retirement benefit obligation (APBO):
Retirees $(8,235) $ (7,498) $ (8,783)
Active employees fully eligible for benefits (2,825) (2,589) (3,327)
Other active employees (3,052) (4,093) (4,622)
Total $(14,112) $(14,180) (16,732)
Fair Value of assets (primarily
notes and bonds) 924 364 84
Unrecognized transition obligation 12,083 13,328 14,068
Unrecognized net (gain) loss (2,217) (2,358) 956
(Accrued) prepaid post-retirement
benefit cost $ (3,322) $(2,846) $ (1,624)
The discount rate and compensation increase rate used to determine post-
retirement benefit costs were changed effective January 1, 1996 to 7.25% and
4.25%, respectively and were used to calculate the funded status of Post-
Retirement benefits at December 31, 1995.
Increasing the assumed health care cost trend rate by 1% each year would
increase the total post-retirement benefit cost for 1995 by approximately
$177,000 and increase the total accumulated post-retirement benefit obligation
by $1.5 million.
Blackstone has also established an irrevocable external Voluntary
Employee's Beneficiary Association (VEBA) Trust Fund as required by the
aforementioned regulatory decisions. Contributions to the VEBA fund commenced
in March 1993 and totaled approximately $1.1 million during 1995, $800,000
during 1994 and $600,000 during 1993.
Environmental Matters:
The Comprehensive Environmental Response, Compensation Liability Act of
1980, as amended by the Superfund Amendments and Reauthorization Act of 1986,
and certain similar state statutes authorize various governmental authorities
to seek court orders compelling responsible parties to take cleanup action at
disposal sites which have been determined by such governmental authorities to
present an imminent and substantial danger to the public and to the environment
because of an actual or threatened release of hazardous substances. Because of
the nature of Blackstone's business, various by-products and substances are
produced or handled which are classified as hazardous under the rules and
regulations promulgated by the EPA as well as state and local authorities.
Blackstone generally provides for the disposal of such substances through
licensed contractors, but these statutory provisions generally impose potential
joint and several responsibility on the generators of the wastes for cleanup
costs. Blackstone has been notified with respect to a number of sites where
they may be responsible for such costs, including sites where they may have
joint and several liability with other responsible parties. It is the policy
of Blackstone to notify liability insurers and to initiate claims. However, it
is not possible at this time to predict whether liability, if any, will be
assumed by, or can be enforced against, the insurance carriers in these
matters.
On December 13, 1994, the United States District Court for the District of
Massachusetts (District Court) issued a judgment against Blackstone, finding
Blackstone liable to the Commonwealth of Massachusetts (Commonwealth) for the
full amount of response costs incurred by the Commonwealth in the cleanup of a
by-product of manufactured gas at a site at Mendon Road in Attleboro,
Massachusetts. The judgment also found Blackstone liable for interest and
litigation expenses calculated to the date of judgment. The total liability is
approximately $5.9 million, including approximately $3.6 million in interest
which has accumulated since 1985. Due to the uncertainty of the ultimate
outcome of this proceeding and anticipated recoverability, Blackstone recorded
the $5.9 million District Court judgment as a deferred debit. This amount is
included with Other Assets at December 31, 1995 and 1994.
Blackstone filed a Notice of Appeal of the District Court's judgment and
filed its brief with the United States Court of Appeals for the First Circuit
(First Circuit) on February 24, 1995. On October 6, 1995 the First Circuit
vacated the District Court's judgment and ordered the District Court to refer
the matter to the EPA to determine whether the chemical substance, ferric
ferrocyanide (FFC), contained within the by-product is a hazardous substance.
On January 20, 1995, Blackstone entered into an escrow agreement with the
Commonwealth whereby Blackstone deposited $5.9 million with an escrow agent who
transferred the funds into an interest bearing money market account. The
distribution of the proceeds of the escrow account will be determined upon the
final resolution of the judgment. No additional interest expense will accrue
on the judgment amount.
On January 28, 1994, Blackstone filed a complaint in the District Court,
seeking, among other relief, contribution and reimbursement from Stone &
Webster Inc., of New York City and several of its affiliated companies (Stone &
Webster), and Valley Gas Company of Cumberland, Rhode Island (Valley) for any
damages incurred by Blackstone regarding the Mendon Road site. On November 7,
1994, the court denied motions to dismiss the complaint which were filed by
Stone & Webster and Valley. This proceeding was stayed in December 1995
pending final EPA determination as to whether FFC is hazardous.
In addition, Blackstone has notified certain liability insurers and has
filed claims with respect to the Mendon Road site, as well as other sites.
Blackstone reached settlement with one carrier for reimbursement of legal costs
related to the Mendon Road case. In January 1996, Blackstone received $1.2
million in connection with
this settlement.
As of December 31, 1995, Blackstone had incurred costs of approximately
$4.1 million (excluding the $5.9 million Mendon Road judgment) in connection
with these sites. These amounts have been financed primarily by internally
generated cash. Blackstone is currently amortizing all of its incurred costs
over a five-year period and is recovering certain of those costs in rates.
As a general matter, Blackstone will seek to recover costs relating to
environmental proceedings in its rates. Blackstone applied for and received
authority to recover in rates certain of the incurred costs over a five-year
period. The Company estimates that additional costs (excluding the Mendon Road
judgment) may be incurred at these sites through 1997 of up to approximately
$2.5 million by it and the other responsible parties. Estimated amounts after
1997 are not now determinable since site studies which are the basis of these
estimates have not been completed.
As a result of the recoverability in current rates and the uncertainty
regarding both its estimated liability, as well as potential contributions from
insurance carriers and other responsible parties, Blackstone does not believe
that the ultimate impact of the environmental costs will be material to its
financial position and thus, no loss provision is required at this time.
A number of scientific studies in the past several years have examined the
possibility of health effects from electric and magnetic fields (EMF) that are
found wherever there is electricity. While some of the studies have indicated
some association between exposure to EMF and health effects, many of the others
have indicated no direct association. The research to date has not
conclusively established a direct causal relationship between EMF exposure and
human health. Additional studies, which are intended to provide a better
understanding of EMF, are continuing.
Some states have enacted regulations to limit the strength of EMF at the
edge of transmission line rights-of-way. Rhode Island enacted a statute which
authorizes and directs the Rhode Island Energy Facility Siting Board to
establish rules and/or regulations governing construction of high voltage
transmission lines of 69 KV or more. Management cannot predict the impact, if
any, which legislation or other developments concerning EMF may have on
Blackstone.
In April 1992, NESCAUM, an environmental advisory group for eight
Northeast states, including Massachusetts and Rhode Island, issued
recommendations for oxides of nitrogen controls for existing utility boilers
required to meet the ozone non-attainment requirements of the Clean Air Act
Amendments. The NESCAUM recommendations are more restrictive than EPA's
requirements. The DEP has amended its regulations to require that Reasonably
Available Control Technology (RACT) be implemented at all stationary sources
potentially emitting 50 or more tons per year of oxides of nitrogen. Rhode
Island has also issued similar regulations requiring that RACT be implemented
at all stationary sources potentially emitting 50 or more tons per year of
oxides of nitrogen. Montaup has initiated compliance through, among other
things, selective, noncatalytic reduction processes.
Report of Independent Accountants
To the Directors and Shareholder of
Blackstone Valley Electric Company:
We have audited the accompanying balance sheets and statement of capitalization
of Blackstone Valley Electric Company (the Company) as of December 31, 1995 and
1994, and the related statements of income, retained earnings and cash flows
for each of the three years in the period ended December 31, 1995. These
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to
obtain reasonable assurance about whether the financial statements are free of
material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the financial position of the Company as of December 31,
1995 and 1994, and the results of its operations and its cash flows for each of
the three years in the period ended December 31, 1995 in conformity with
generally accepted accounting principles.
Coopers & Lybrand L.L.P.
Boston, Massachusetts
March 5, 1996