SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
For the fiscal year ended September 30, 1999
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from __________ to _________
Commission File Number 0-10721
YANKEE ENERGY SYSTEM, INC.
--------------------------
(Exact name of registrant as specified in its charter)
599 Research Parkway
Connecticut 06-1236430 Meriden, CT 06450-1030
- ------------------------------- ---------------- --------------------- ----------
(State or other jurisdiction of (I.R.S. Employer (Address of principal (Zip Code)
incorporation or organization) Identification No.) executive offices)
(203) 639-4000
--------------
(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
------------------- -----------------------------------------
Common Stock, Par Value $5 Per Share
and Common Share Purchase Rights New York Stock Exchange
- ------------------------------------ -----------------------
Securities registered pursuant to Section 12(g) of the Act:
None
----
(Title of class)
Indicate by check mark whether the registrant: (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No __
--
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [ X ]
The aggregate market value of the voting stock held by non-affiliates of the
registrant at December 7, 1999 was $459,867,562 based on the closing price of
$43.25 per share. On December 7, 1999, the Company had 10,632,776 shares of
common stock outstanding.
YANKEE ENERGY SYSTEM, INC.
FORM 10-K
FOR THE FISCAL YEAR ENDED SEPTEMBER 30, 1999
TABLE OF CONTENTS
PAGES
-----
PART I
Item 1. Business............................................................... 1
The Company ........................................................ 1
Gas Markets and Customers........................................... 1
Gas Supply.......................................................... 3
Regulation and Rates ............................................... 5
Energy Services .................................................... 7
Competition ........................................................ 7
Environmental Matters .............................................. 8
Franchises ......................................................... 8
Employees .......................................................... 9
Item 2. Properties ........................................................... 9
Item 3. Legal Proceedings .................................................... 9
Item 4. Submission of Matters to a Vote of Security Holders .................. 10
PART II
Item 5. Market for Company's Common Equity and Related Stockholders Matters... 10
Item 6. Selected Financial Data .............................................. 11
Item 7. Management's Discussion and Analysis of Financial Conditions and
Results Of Operations .............................................. 12
Item 7a. Quantitative and Qualitative Disclosures About Market Risk ........... 19
Item 8. Financial Statements and Supplementary Data........................... 20
Item 9. Changes In and Disagreements with Accountants on Accounting and
Financial Disclosure ................................................. 20
PART III
Item 10. Directors and Executive Officers of the Company ...................... 21
Item 11. Executive Compensation ............................................... 23
Item 12. Security Ownership of Certain Beneficial Owners and Management ....... 29
Item 13. Certain Relationships and Related Transactions ....................... 30
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K ...... 30
Signatures
PART 1
ITEM 1. BUSINESS
THE COMPANY
Yankee Energy System, Inc. ("Yankee Energy" or the "Company"), is a public
utility holding company incorporated in Connecticut in 1989. The Company is
primarily engaged in the retail distribution of natural gas through its
wholly-owned subsidiary, Yankee Gas Services Company ("Yankee Gas"), a
Connecticut public service company. Yankee Gas serves approximately 185,000
residential, commercial and industrial customers in 69 cities and towns in
Connecticut. The Company is exempt from registration under the Public Utility
Holding Company Act of 1935.
The Company has four additional wholly-owned operating subsidiaries which
support the Company's core natural gas distribution business or allow the
Company to position itself in the market place as a provider of a full range of
energy-related mechanical services to commercial, industrial and institutional
customers.
Yankee Energy Services Company ("YESCo") provides comprehensive building
automation services, including engineering, installing, and maintaining building
control systems through its YESCo Controls Division and comprehensive heating
ventilation and air-conditioning ("HVAC"), boiler and refrigeration equipment
services and installation through its YESCo Mechanical Services Division. The
Company is in the process of selling a substantial portion of the assets of
YESCo's Power Division. R.M. Services, Inc. ("RMS"), directly and under contract
with Dun and Bradstreet Receivables Management Services, provides residential
collection services for companies throughout the United States, and Yankee
Energy Financial Services Company ("Yankee Financial") provides a full range of
equipment and home improvement financing services through various programs, such
as the Hometown Energy and Energy Key Loan Programs. Finally, NorConn
Properties, Inc. ("NorConn"), owns selected system real estate and leases it to
Yankee Gas.
GAS MARKETS AND CUSTOMERS
GENERAL. Yankee Gas operates the largest natural gas distribution system in
Connecticut as measured by number of customers and size of service territory.
Total throughput (sales and transportation) for fiscal 1999 was 46.4 billion
cubic feet ("Bcf"). In fiscal 1999, total gas operating revenues were comprised
of the following: 49% residential; 28% commercial; 20% industrial; and the
remaining 3% other. Yankee Gas provides firm gas sales service to customers who
require a continuous gas supply throughout the year, such as residential
customers who rely on gas for their heating, hot water, and cooking needs.
Yankee Gas also provides interruptible gas sales service to certain commercial
and industrial customers that have the capability to switch from natural gas to
an alternative fuel on short notice. Yankee Gas can interrupt service to these
customers during peak demand periods. Yankee Gas offers firm and interruptible
transportation services to customers who purchase gas from sources other than
Yankee Gas. In addition, Yankee Gas performs gas exchanges and capacity releases
to marketers to reduce its overall gas expense.
FIRM SALES. In fiscal 1999, total firm gas sales of 24.7 Bcf accounted for
approximately 53% of total throughput and approximately 81% of the Company's
total operating revenues. Firm gas sales, particularly sales for residential
space heating, are highly seasonal. In fiscal 1999, about 64% of total firm
sales occurred in the five months from November through March. The following
tables set forth certain information with respect to firm sales in fiscal 1999.
FISCAL 1999 FIRM SALES
Volumes as
Average Number Volumes a Percent of
of Customers in Bcf Revenues Firm Sales
------------ ------- ------------ ------------
Residential 162,880 12.1 $136,085,735 49
Commercial 17,086 5.8 57,446,113 23
Industrial 1,531 6.8 30,273,699 28
------------ ------ ------------ ------------
181,497 24.7 $223,805,547 100%
INTERRUPTIBLE SALES. In fiscal 1999, total interruptible gas sales of 5.2
Bcf accounted for approximately 11% of total throughput and approximately 7% of
the Company's total operating revenues. The price charged for interruptible
sales service is a market price based on the cost of the customer's alternative
fuel, which is usually oil. Interruptible sales depend upon the availability of
gas supplies and, generally, have provided lower margins than firm sales. Yankee
Gas has authorization from the Connecticut Department of Public Utility Control
("DPUC") to engage in flexible pricing to meet market prices for alternative
fuels available to interruptible customers. The following table sets forth
certain information with respect to interruptible sales in fiscal 1999.
FISCAL 1999 INTERRUPTIBLE SALES
Average Number Volumes
of Customers in Bcf Revenues
------------ ------ --------
Commercial and Industrial 250 5.2 $18,109,426
TRANSPORTATION SERVICES. Yankee Gas offers firm and interruptible
transportation service to its industrial and commercial customers. In fiscal
1999, total transportation sales accounted for approximately 11% of the
Company's total operating revenues. These transportation services permit
customers who desire to purchase gas from sources other than Yankee Gas to do
so, provided they have made all the necessary arrangements with the transmission
pipelines to deliver their gas to the Yankee Gas distribution system. Industrial
and commercial customers can purchase gas directly from producers and suppliers
and contract for transportation services rather than purchase gas solely from
the local distribution system. Generally, interruptible transportation service
is highly sensitive to alternative fuel prices as well as to the availability of
interstate pipeline capacity into the region. Under existing tariff structures,
the financial condition of the Company is unaffected by customers electing to
use transportation service in lieu of making gas purchases from Yankee Gas. The
average number of transportation customers was 3,412 during fiscal 1999.
MARKET EXPANSION STRATEGY. The Company completed a customer and market
segmentation study during 1999 that provides an in-depth analysis of customer
use of the Company's products and services and will be used to identify
additional sales opportunities.
2
Marketing information about current customers and new opportunities is
directing the Company's efforts to expand its distribution service. These
efforts focus on increasing the number of residential households using
natural gas, increasing the uses of natural gas by existing Yankee Gas
customers, and increasing the overall number of both large and small
customers through expansion of Yankee Gas' distribution system within its
service territory. In the residential and small commercial market, Yankee Gas
focuses marketing efforts on entities along Yankee Gas' existing mains
because they present opportunities to increase gas sales with little or no
capital investment. In the larger commercial and industrial markets, the
Company seeks to expand gas sales by increasing sales to existing customers
for both traditional and innovative uses, such as infrared heating,
engine-driven air compression, cooling, distributed electric generation and
combined heat and power. The Company also emphasizes attracting new
commercial and industrial customers within its service territory.
GAS SUPPLY
In 1992, the Federal Energy Regulatory Commission ("FERC") issued Order
No. 636, which required natural gas pipeline companies to separate or
"unbundle" their services. Prior to the issuance of Order No. 636, natural
gas pipeline companies sold pipeline services, such as gas purchasing,
storage and transportation, as a package. In 1993, the interstate pipeline
companies that provided natural gas to Yankee Gas complied with Order No.
636. As a result, Yankee Gas executed contracts with interstate pipeline
companies for services to transport gas from production and underground
storage areas to Yankee Gas' service territory to replace the traditional
merchant services previously provided by the pipeline companies. Yankee Gas
concurrently replaced the gas supply traditionally obtained from the pipeline
companies' merchant services with firm purchases directly from producers
and/or marketing companies. The FERC continues to regulate the rates charged
by interstate pipeline companies for transportation and storage of natural
gas, but does not regulate the price of natural gas purchased by the Company
from producers and marketing companies.
Interstate pipelines delivered over 99.9 percent of Yankee Gas' 1999 fiscal
year requirements to its distribution system. Interstate pipeline capacity
enabled Yankee Gas to meet its firm customers' requirements with pipeline
supplies for more than 99.9 percent of the year.
The following table sets forth sources of fiscal 1999 gas supply (including
purchases for storage injections):
Percent of
Source Total Supply
------ ------------
Alberta Northeast Gas, Limited 21.60
Other Canadian Supplies 56.33
Domestic Supply 22.05
Other (Peaking) 0.02
------
Total 100.00%
3
Yankee Gas is entitled to purchase 68,460 thousand cubic feet ("Mcf") per
day of gas, or about 25 Bcf annually, from Canadian gas suppliers. The sales
contracts between Yankee Gas and its Canadian suppliers expire in 2003 and 2006.
Most of the gas purchased from the Canadian suppliers is delivered in the United
States by the Iroquois Gas Transmission System, L.P. ("Iroquois"). The
transportation contract between Yankee Gas and Iroquois expires in 2011.
During fiscal 1999, one of Yankee Gas' largest Canadian suppliers was
Alberta Northeast Gas, Limited ("ANE"). ANE is an entity formed by several
utilities in the Northeast to aggregate the purchase of gas from Western Canada
and to facilitate its sale to local gas distribution company ("LDC") owners at
the United States-Canadian border. Yankee Gas held a 15.9 percent equity
interest in ANE until July 1, 1998 at which time Yankee Gas reduced its equity
interest to 5.3 percent.
Yankee Gas also holds pipeline transportation and storage service contracts
with Tennessee Gas Pipeline Company ("Tennessee"), Algonquin Gas Transmission
Company ("Algonquin"), Texas Eastern Transmission Corporation ("Texas Eastern"),
CNG Transmission Corporation ("CNG Transmission"), Transcontinental Gas Pipe
Line Company ("Transco"), and National Fuel Gas Supply Corporation ("National
Fuel") as summarized below:
TRANSPORTATION SERVICE CONTRACTS:
Annual Transport
Pipeline Quantity Expiration
-------- -------- ----------
Tennessee 27.7 Bcf 2003-2017
Algonquin 39.6 Bcf 2001-2014
Texas Eastern 38.2 Bcf 2003-2014
CNG Transmission 2.7 Bcf 2003-2012
Transco 0.63 Bcf 2008
National Fuel 0.63 Bcf 2003
STORAGE SERVICE CONTRACTS:
Annual Storage
Pipeline Quantity Expiration
-------- -------- ----------
Tennessee 1.9 Bcf 2003
Texas Eastern 1.7 Bcf 2012-2013
CNG Transmission 1.4 Bcf 2003-2012
Yankee Gas has entered comprehensive gas supply agreements with Engage
Energy US, L.P. ("Engage") and TransCanada Gas Services Inc. ("TransCanada")
which optimize portions of its supply portfolio. Specifically, the Engage
agreement optimizes gas supply delivered to Yankee Gas by Algonquin and expires
in 2000 while the TransCanada agreement optimizes gas supply delivered by
Tennessee and expires in 2001. Under these agreements, the supplier delivers
Yankee Gas' full fuel requirements on the respective pipeline while optimizing
the value of the supply and associated transportation and storage during
off-peak conditions. The agreements also provide Yankee Gas with enhanced supply
flexibility.
4
Yankee Gas does not have sufficient capacity entitlements on the interstate
pipelines to serve its firm customers with pipeline-delivered gas at all times.
During the winter, therefore, whenever daily firm demand exceeds the amount of
gas delivered by the pipelines, service to interruptible customers is curtailed.
Yankee Gas supplements pipeline gas with a propane-air mixture produced at
facilities within Yankee Gas' service territory and with contracted peaking gas
supplies. In fiscal 1999, these gas supplies comprised less than 1 percent of
Yankee Gas' total supply.
REGULATION AND RATES
FEDERAL REGULATION. Although Yankee Gas is not subject to FERC
jurisdiction, the FERC does regulate the interstate pipelines serving Yankee
Gas' service territory. Yankee Gas, therefore, is directly and substantially
affected by the FERC's policies and actions. Accordingly, Yankee Gas closely
follows and, when appropriate, participates in proceedings before the FERC.
CONNECTICUT REGULATION. Yankee Gas is subject to regulation by the DPUC,
which, among other things, has jurisdiction over rates, accounting procedures,
certain dispositions of property and plant, mergers and consolidations,
issuances of securities, standards of service, management efficiency and
construction and operation of distribution, production and storage facilities.
The DPUC may, after a special public hearing, order an interim rate
decrease if it finds that Yankee Gas' return on equity exceeds a reasonable rate
of return and rates are more than just, reasonable and adequate as determined by
the DPUC. The DPUC also is empowered to grant an interim rate increase under
compelling circumstances.
Yankee Gas sells gas to its retail customers under rate schedules filed
with and approved by the DPUC. Firm sales rates are subject to monthly
adjustments pursuant to a Purchased Gas Adjustment ("PGA") clause approved by
the DPUC. The PGA passes through to customers most changes in the cost of gas
purchased by Yankee Gas. These adjustments are designed to collect or refund
differences between actual purchased gas costs and the costs included in Yankee
Gas' base rates. In 1997, the DPUC conducted a review of the Connecticut LDCs'
PGA mechanism to determine if any changes were warranted. The most significant
change approved by the DPUC was the authorization for LDCs to pass on to
customers the costs of the Connecticut Gross Earnings Tax related to PGA
revenues.
Yankee Gas' rate order, effective for service rendered on and after
October 1, 1992, allowed a return on equity ("ROE") of 12.43 percent and
provided for favorable accounting treatment for environmental cleanup costs,
post-retirement benefits and certain other major items.
On August 25, 1996, Yankee Gas filed an application with the DPUC for a
Financial and Operation Review ("Review") of Yankee Gas. This Review was
required under Connecticut law because Yankee Gas had not undergone a rate
proceeding within the four years preceding the 1996 application. The DPUC
issued a decision on July 9, 1997, which called for a reduction of Yankee
Gas' ROE from 12.43 percent to 11.15 percent. The DPUC believed that lower
interest rates and allowed rates of return for other Connecticut utilities
justified a lower ROE for Yankee Gas. On October 1, 1997, the DPUC approved
an amendment to the settlement agreement between Yankee Gas and the
Connecticut Office of Consumer Counsel that, among other things, required
Yankee Gas to credit $3.2 million to firm sales customers through the PGA
during fiscal 1998.
5
Pursuant to the settlement agreement with the Connecticut Office of
Consumer Counsel, Yankee Gas agreed not to apply for a rate increase prior to
October 1, 2000, except in the event of certain circumstances that would have a
significant adverse effect on Yankee Gas' financial condition. If such an event
arises, Yankee Gas has the option to apply to the DPUC for a rate increase or to
retain up to 80% of any off system sales margin and excess interruptible margin.
FERC ORDER NO. 636. In implementing Order No. 636, the FERC recognized that
the restructuring of the pipelines' traditional services would cause pipelines
to incur transition costs in several areas. The FERC has permitted certain
transition costs to be recovered by the pipeline companies from their customers.
In July 1994, the DPUC issued an order permitting the recovery of
transition costs billed by pipelines under Order No. 636 through various
mechanisms authorized by the DPUC. Through September 30, 1999, Yankee Gas has
paid approximately $21.5 million of transition costs and an additional $1.5
million are anticipated. To date, Yankee Gas has collected $53.6 million through
a combination of credits received from pipeline refunds, capacity release
agreements, deferred gas costs credits, off system sales margins and excess
interruptible margins. The DPUC approved the settlement agreement in January
1996 and an amendment thereto in October 1997 between Yankee Gas and the
Connecticut Office of Consumer Counsel that permits Yankee Gas to retain
over-collected transition cost credits to offset certain deferred regulatory
assets. As of September 30, 1999, excess collections of approximately $32.1
million were applied against the deferred regulatory assets specified in the
agreement.
In January 1996, the DPUC, in response to Order No. 636, authorized the
Connecticut LDCs to offer unbundled firm transportation rates to its commercial
and industrial customers. The DPUC's decision permits Yankee Gas to offer a
variety of service options to its commercial and industrial firm transportation
customers. Yankee Gas implemented new firm transportation rates and services in
April 1996. In October, 1998, the DPUC issued a decision making a number of
modifications to the commercial and industrial firm transportation program.
These modifications became effective on January 1, 1999 and are designed to
simplify and improve the program based on the initial firm transportation
experience. As of September 30, 1999, Yankee Gas had approximately 3,627
customers under firm transportation service. The conversion by existing
customers to transportation service will result in decreased revenues for Yankee
Gas, as that portion of revenues representing gas costs will be borne directly
by these customers who will purchase their own gas directly. Yankee Gas,
however, does not expect customer conversions to transportation services to
affect its net income because the cost of gas has traditionally been a pass
through item with no income impact. The DPUC's decision did not address Yankee
Gas' revenue requirement.
Order No. 636 also authorizes LDCs to make off system sales or to release
firm pipeline capacity and Yankee Gas has engaged in these activities to
maximize revenues and for effective gas supply planning.
6
ENERGY SERVICES
The Company has refocused its mission to diversify into energy-related
businesses. This has resulted in a restructuring of YESCo, which included
consolidation of facilities and elimination of certain positions of the HVAC
division and a decision to close down the Power Division and sell its Power
Projects. The elimination of redundant administrative and operating positions
better focuses the business both geographically by ceasing all non-Connecticut
activities and operationally by discontinuing HVAC equipment sales operation.
YESCo provides comprehensive building automation services, including
engineering, installing, and maintaining building control systems through its
YESCo Controls Division and comprehensive HVAC, boiler and refrigeration
equipment services and installation through its YESCo Mechanical Services
Division.
COMPETITION
Yankee Gas' principal competitors are unregulated fuel-oil retailers and
regulated electric utilities. Natural gas competes with oil and electricity in
many commercial and industrial applications and in residential space and water
heating, clothes drying and cooking. Demand for natural gas is affected by the
marketing and pricing of competing sources of energy.
Yankee Gas may also face competition from other LDCs. In the past, LDCs did
not directly compete with other LDCs for retail customers because the
territories they serve are fixed by franchise. However, since 1993, LDCs began
marketing efforts within the service territory of other LDCs under blanket
certificates granted by the FERC. These certificates allow gas to be sold, but
not necessarily delivered, in the service territory of another LDC. Within
Yankee Gas' service territory, Yankee makes available its transportation
services to move other parties' gas through its distribution system. The Company
believes that deregulation of the sale of natural gas has created an opportunity
for its commercial and industrial customers to achieve savings on the purchase
price of natural gas by helping its customers lower the purchase price of
natural gas. The Company believes it will achieve more throughput through its
distribution system. This volume increase is expected to result in higher
transportation margin. The Company further believes that increasing competition
in gas marketing will result in growth in the Company's gas distribution
business. There can be no assurance, however, that such deregulation and
increased competition in gas marketing will have a beneficial effect on the
Company's results of operations.
Federal regulation also permits customers within Yankee Gas' distribution
system to connect directly with transmission pipelines and bypass Yankee Gas'
distribution system. A Connecticut statute currently prohibits an interstate
pipeline from bypassing a LDC without the DPUC's prior approval. The Company
believes that Yankee Gas is successfully addressing the threat of bypass by its
industrial customers by understanding what services they need and executing
market-competitive gas service agreements. There is, however, a potential risk
of loss of revenues from bypass of Yankee Gas' distribution system.
7
ENVIRONMENTAL MATTERS
The Company is subject to federal and state environmental regulation of its
operations and properties and has an ongoing monitoring program to review
compliance with existing environmental standards. Such regulation may result in
future environmental liabilities that may include significant expenses to
remove, contain or remediate contamination, including coal tar deposits, caused
by operations of former gas manufacturing plants by Yankee Gas' predecessor
companies prior to the introduction of pipeline gas into the region during the
1950s. Those predecessor companies disposed of the coal tar in accordance with
the standard operating practices of the time.
Fourteen sites containing coal tar became the property of Yankee Gas at the
time of divestiture from its former parent company. Yankee Gas has reported the
results of environmental studies conducted at these sites to the Connecticut
Department of Environmental Protection ("DEP"). Eight of the fourteen sites are
currently listed on the Connecticut Inventory of Hazardous Waste Sites.
Inclusion of a site on this list is an indication that remediation may be
required in the future.
Significant remediation efforts have been conducted at three of these
properties. In addition, the Company has developed a cost estimate for the
remaining sites based on various factors including the probability of clean-up.
The Company recorded a liability of $35 million in fiscal year 1993 for future
environmental cleanup, with a corresponding regulatory asset.
Recovery of remediation costs has been specifically allowed by Yankee Gas'
1992 rate case decision. Currently, $325,000 is allowed annually in rates and an
additional $2.5 million annually may be deferred. If costs are expected to
exceed $2.5 million on an annual basis, Yankee Gas is required to petition the
DPUC for review and additional authorization. The DPUC has stated that "to the
extent that coal tar remediation expenses are prudently incurred, they should be
allowed as proper operating expenses," and therefore, management continues to
believe a regulatory asset is appropriate for this item.
The Company expects to finance environmental remediation expenditures
through a combination of internally generated funds, short-term debt and through
funds received from certain of its insurance carriers in settlement of certain
claims for actual or potential contamination at certain sites that may give rise
to environmental liabilities. As of September 30, 1999, these funds totaled $9.6
million. The proceeds are being reflected as reductions in the regulatory
asset associated with recoverable environmental clean-up costs, as shown in
the accompanying balance sheets.
Management does not believe that the Company's environmental expenditures
will have a material adverse effect on its operations, liquidity or financial
position, based on known facts and existing laws and regulations and the
anticipated period over which expenditures will be made.
FRANCHISES
Yankee Gas and its predecessors in interest have held valid franchises to
sell gas in the areas in which Yankee Gas supplies gas service. Such franchises
are perpetual but remain subject to the power of alteration, amendment or repeal
by the General Assembly of the State of Connecticut, the power of revocation by
the DPUC and certain approvals, permits and consents of public authorities and
others prescribed by statute. Yankee Gas franchises include, among other rights
and powers, the rights and powers to manufacture, generate, purchase, transmit
and distribute gas, to sell gas at wholesale to other utility companies and
municipalities and to erect and maintain certain facilities on public highways
and grounds, all subject to such consents and approvals of public authorities
and others as may be required by law. The franchises include the power of
eminent domain.
8
EMPLOYEES
Yankee Energy has no employees. Its subsidiaries employ approximately 790
people.
ITEM 2. PROPERTIES
Yankee Gas' property consists primarily of its gas distribution facilities
including, distribution lines (mains and services), meters, pumps, valves and
pressure and flow controllers. Yankee Gas owns various propane facilities with a
combined storage capacity equivalent to approximately 245,000 Mcf. In the
opinion of management, Yankee Gas' distribution system is in good condition.
Virtually all of the gas properties are subject to the lien of the Yankee Gas
first mortgage bond indenture. Yankee Gas also owns service buildings in
Meriden, Waterbury, Torrington, Mystic, Norwalk, Bethel and Danielson,
Connecticut.
NorConn owns the Company's headquarters building in Meriden, Connecticut
and currently leases it to Yankee Gas. This is the site of the Company's
corporate administrative and staff functions including the Customer Service
Center. NorConn also owns and leases to Yankee Gas a service building in East
Windsor.
ITEM 3. LEGAL PROCEEDINGS
MUNICIPAL TAX ASSESSMENT. In fiscal 1996, Yankee Gas received revised
property tax bills from the City of Meriden, Connecticut ("City") for tax
years 1991 through 1994. The City is asserting a claim for the payment of
approximately $5.0 million for back taxes and interest resulting from the
reassessment and revaluation of Yankee Gas' personal property filings. The
City did not locate or identify any property which Yankee Gas omitted from
its filings. The tax bills reflect a reassessment of property using a
different methodology than that previously accepted by the City. Subsequent
to the filing of the lawsuit against the City, Yankee Gas appealed the
succeeding reassessments and is currently in the process of also litigating
the revaluation of the subject personal property for the 1995 through 1998
tax years. Although it is anticipated that the outcome of this claim will not
have a material impact on the Company, based on the information available at
this time, management cannot predict what the ultimate impact might be.
HEATING AND COOLING CONTRACTORS' LAWSUIT. In November 1995, a purported
class action suit was filed against Yankee Gas and the state's two other LDCs
by the Connecticut Heating and Cooling Contractors' Association, Inc. et al.
On December 21, 1999, the action was settled with the plaintiffs and is
awaiting the court's confirmation. This settlement does not have a material
adverse effect on the Company's consolidated results of operations or
financial position.
Other legal proceedings involving the Company and its subsidiaries are
litigation incidental to the conduct of the Company's business which, in
management's opinion, will not have a material impact on the Company's financial
condition or results of operations.
9
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There was no matter submitted to a vote of security holders during the
fourth quarter of 1999. At a Special Meeting of Shareholders of the Company held
on October 12, 1999, Yankee Energy shareholders voted to approve the Company's
merger into Northeast Utilities. See "Item 7. Management's Discussion and
Analysis of Financial Condition and Results of Operations - Overview" for a
discussion of the proposed merger with Northeast Utilities.
PART II
ITEM 5. MARKET FOR COMPANY'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
Yankee Energy declared and paid regular quarterly cash dividends in fiscal
1998 and 1999. The dividend paid for the first two quarters of 1998 was $.335
per share and $.345 per share in the last two quarters of 1998. The dividend
paid for the first two quarters of 1999 was $.345 per share and $.355 per share
in the last two quarters of 1999. As of October 31, 1999, there were 21,924
holders of record of Yankee Energy Common Stock. The following table sets forth
for the periods indicated the high and low sales price for the Common Stock as
reported on the New York Stock Exchange:
High Low
---- ---
Year Ended September 30, 1999
First Quarter, 1999 31.438 26.688
Second Quarter, 1999 29.313 22.625
Third Quarter, 1999 39.688 23.938
Fourth Quarter, 1999 42.688 39.220
Year Ended September 30, 1998
First Quarter, 1998 26.813 22.563
Second Quarter, 1998 25.750 24.563
Third Quarter, 1998 24.750 22.563
Fourth Quarter, 1998 26.188 23.438
The transfer agent and registrar for Yankee Energy Common Stock is
ChaseMellon Shareholder Services.
10
ITEM 6. SELECTED FINANCIAL DATA
SEPTEMBER 30, 1999 1998 1997 1996 1995
--------- --------- --------- --------- ---------
Balance Sheet Data: (In thousands)
Net Utility Plant $ 381,048 $ 367,933 $ 350,865 $ 335,488 $ 324,870
Total Assets 540,286 535,284 500,364 478,749 479,301
Total Capitalization 328,629 296,040 300,971 271,348 292,802
--------- --------- --------- --------- ---------
Income and Share Data: (In thousands,
except per share amounts)
Operating Revenues $ 303,482 $ 314,767 $ 325,041 $ 339,940 $ 294,022
Cost of Gas/Goods Sold 152,376 169,287 176,757 189,504 155,404
Other O&M Expenses 67,696 67,942 64,951 64,852 65,473
Depreciation and Amortization 21,560 19,789 18,130 16,895 16,520
Net Income 13,375 10,883 16,957 21,919 12,358
Earnings per Share $ 1.26 $ 1.04 $ 1.62 $ 2.10 $ 1.20
--------- --------- --------- --------- ---------
Revenues: (In thousands)
Gas:
Residential $ 136,086 $ 134,292 $ 140,750 $ 145,364 $ 127,493
Commercial 61,302 73,495 95,098 103,787 88,983
Industrial 44,527 50,055 70,743 82,725 73,715
Miscellaneous 4,478 3,642 2,312 6,217 2,161
Transportation 29,226 22,355 10,051 952 1,631
--------- --------- --------- --------- ---------
Total Gas 275,619 283,839 318,954 339,045 293,983
--------- --------- --------- --------- ---------
Nonutility Revenue 27,863 30,928 6,087 895 39
--------- --------- --------- --------- ---------
Total Operating Revenues $ 303,482 $ 314,767 $ 325,041 $ 339,940 $ 294,022
--------- --------- --------- --------- ---------
Sales and Transportation: (Mcf-thousands)
Firm:
Residential 11,836 11,888 12,473 13,185 11,591
Commercial 5,708 6,941 9,222 10,521 9,022
Industrial 6,835 7,792 9,862 11,438 10,007
Transportation 11,679 9,266 4,059 178 589
Unbilled and Other 306 (84) (110) 969 793
--------- --------- --------- --------- ---------
Total Firm 36,364 35,803 35,506 36,291 32,002
--------- --------- --------- --------- ---------
Non-Firm:
Commercial 970 1,293 1,595 1,746 1,809
Industrial 4,033 3,405 4,983 6,792 7,286
Transportation 5,062 6,646 6,850 2,444 3,654
--------- --------- --------- --------- ---------
Total Non-Firm 10,065 11,344 13,428 10,982 12,749
--------- --------- --------- --------- ---------
Total Sales and Transportation 46,429 47,147 48,934 47,273 44,751
--------- --------- --------- --------- ---------
Customers: (Average)
Residential 162,880 160,917 159,541 157,526 156,539
Commercial (1) 17,236 17,910 18,930 19,313 19,167
Industrial (1) 1,631 1,821 2,005 2,112 2,145
Firm Transportation 3,412 2,422 766 19 --
Resale -- -- -- 2 1
--------- --------- --------- --------- ---------
Total Customers 185,159 183,070 181,242 178,972 177,852
--------- --------- --------- --------- ---------
Sources of Gas: (Mcf-thousands)
Domestic 6,618 7,668 15,594 21,331 13,534
Canadian Gas Firm 23,860 24,941 24,919 24,721 24,283
Spot Market Gas -- -- 97 710 2,836
Produced Gas 7 4 34 19 9
Company Use/Unaccounted For (802) (440) (440) (509) (403)
--------- --------- --------- --------- ---------
Total Sources 29,683 32,173 40,204 46,272 40,259
--------- --------- --------- --------- ---------
Peak Day Data:
Peak Day Send Out (Mcf per day) (2) 274,759 260,470 250,448 239,348 250,518
Peak Day Date 1/14/99 3/12/98 1/17/97 2/5/96 2/6/95
Peak Day Degree Days 61 50 55 62 59
Total Annual Heating Degree Days 5,602 5,502 5,979 6,302 5,595
--------- --------- --------- --------- ---------
(1) Non-firm transportation customers who utilize both gas sales and
transportation service are included in these customer categories. Average
non-firm transportation customers are as follows: 1999:32 ,1998:19,
1997:18, 1996: 12 , and 1995: 23.
(2) Converted from BTU-millions assuming 1,020 BTU per CF.
11
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITIONS AND RESULTS
OF OPERATIONS
OVERVIEW
Yankee Energy, headquartered in Meriden, Connecticut, is a diversified
company specializing in the distribution, conversion, and control of energy to
meet our customers' needs. Our principal operating subsidiary is Yankee Gas.
Yankee Gas, the largest natural gas distribution company in Connecticut,
provides service to more than 185,000 customers in 69 cities and towns.
On June 14, 1999, the Company and Northeast Utilities ("NU") entered
into an Agreement and Plan of Merger ("Merger Agreement") providing for a
merger transaction ("Merger") between the Company and NU. Pursuant to the
Merger Agreement, the Company will merge with and into Merger Sub, a
Connecticut corporation to be formed by NU prior to the closing of the Merger
as a wholly owned subsidiary of NU. Merger Sub will be the surviving entity,
and will change its name to "Yankee Energy System, Inc." As a result of the
Merger, the Company will become a wholly owned subsidiary of NU. Shareholders
of Yankee Energy will receive $45.00 a share, 45% payable in NU shares and
55% payable in cash. The Merger will be accounted for using the purchase
method of accounting. On October 12, 1999, the shareholders of the Company
approved the Merger. The Merger is conditioned on, among other things, the
approval of the various regulatory agencies, including the DPUC and the
Securities and Exchange Commission. The Company expects the Merger to close
in the first half of fiscal 2000. On October 13, 1999, Consolidated Edison,
Inc. and NU announced a definitive merger agreement to combine the two
companies. This merger is expected to close in the fourth quarter of calendar
year 2000.
On August 4, 1999, the Company and NU filed a joint application, Docket
No. 99-08-02, with the DPUC for approval of the Merger. Hearings were held
September 1999 and October 1999. On December 29, 1999, the DPUC issued a
final decision approving the Merger and determining that NU is financially,
technologically and managerially suitable and responsible to assume control
of Yankee Energy. In addition, the DPUC determined that NU is capable of
providing safe, adequate and reliable service to the public.
The Company's other operating subsidiaries support the core business in
natural gas distribution, or allow the Company to expand its growing business
in energy-related services. YESCo provides a wide range of energy-related
services for its customers. YESCo Controls division provides comprehensive
building automation with engineering, installation and maintenance of
building control systems. YESCo Mechanical Services division provides
comprehensive heating, ventilation and air-conditioning ("HVAC"), boiler and
refrigeration equipment services and installation. In addition to Yankee Gas
and YESCo, two other subsidiaries are taking advantage of opportunities by
positioning services once exclusively provided to local energy customers to a
broader marketplace. RMS, through its alliance with Dun & Bradstreet
Receivables Management Services, provides consumer collection services for
companies throughout the United States, and Yankee Financial provides a full
range of equipment and home improvement financing options through programs
like the Hometown Energy Loan Program. NorConn owns selected system real
estate, which it leases to Yankee Gas. Additional company information can be
found at the Company's web site, www.yankeeenergy.com.
12
In fiscal 1998, the Company completed a review of the various operating
functions of YESCo. The Company decided to focus the efforts of YESCo primarily
on its controls and HVAC lines of business and to significantly reduce its cost
structure. As a result, the Company announced its intentions to dispose of the
assets of YESCo's Power division. The Company has reached agreements, subject to
certain closing conditions, to sell its landfill gas project investments ($15.4
million book value) and is currently discussing the disposition of other
investments with other parties. In addition, the Company has restructured its
HVAC business, including the consolidation of locations and better focusing its
business both geographically and operationally.
The Company reported consolidated net income of $13.4 million, or basic and
diluted earnings per share of $1.26, for the fiscal year ended September 30,
1999. This compared with consolidated net income of $10.9 million and $17.0
million, reflecting basic and diluted earnings per share of $1.04 and $1.62,
respectively, for fiscal years ended September 30, 1998 and 1997.
The fiscal 1999 and 1998 results were both affected by non-recurring and
non-operating items. Specifically, expenses associated with the Merger
reduced fiscal 1999 results by approximately $2.0 million or $0.19 per share.
Fiscal 1998 results were negatively impacted by non-recurring charges
totaling $2.1 million, or $0.20 per share, related primarily to restructuring
issues at YESCo. Absent these non-recurring items, earnings in fiscal 1999
improved $2.4 million or 18 percent from fiscal 1998, primarily related to
the significant improvement in performance at Yankee Energy's unregulated
businesses.
Yankee Gas' fiscal 1999 results were comparable to last year, with a
slight increase in margin due to the elimination of customer bill credits
totaling $3.2 million in fiscal 1998 resulting from a decision of the
Connecticut Department of Public Utility Control ("DPUC"). There was also
slight growth in firm sales, which was offset by a decline in interruptible
sales due to lower oil prices when compared to the prior year. The margin
improvement was offset by increases in operational and maintenance expenses,
depreciation expense and interest expense over the prior year. In fiscal
1999, weather was 9 percent warmer than normal and 2 percent colder than the
prior fiscal year. Management estimates warmer weather reduced earnings by
$3.5 million, or $0.33 per share, in fiscal 1999 compared to normal. On the
unregulated side, RMS has contributed positively in its first year of
expanded operations. During fiscal 1999, RMS opened a new facility, and has
expanded its operations from a twenty-seat facility servicing Yankee Gas to a
120-seat facility servicing a variety of telecommunication, utility and other
businesses. YESCo substantially reduced losses from the prior year as a
result of the restructuring in fiscal 1998. YESCo's success during fiscal
1999 was due primarily to cost control strategies and narrowing its focus of
operations to the HVAC installation, service and control businesses. Finally,
as previously noted, fiscal 1999 earnings were negatively impacted by merger
related expenses of approximately $2.0 million, or $.19 per share.
Earnings for fiscal 1998 decreased from fiscal 1997 due to warmer weather
and customer bill credits. In addition, earnings were unfavorably impacted by
nonrecurring charges related to the restructuring of the HVAC operations of
YESCo, impairments of certain YESCo Power division assets, and severance
charges. In fiscal 1998, weather was 11 percent warmer than normal and 8 percent
warmer than the prior fiscal year. Management estimates warmer weather reduced
earnings by $4.4 million, or $0.42 per share, in fiscal 1998 compared to normal.
Customer bill credits resulting from a rate review settlement approved by the
DPUC in October 1997 reduced earnings by approximately $1.9 million, or $0.18
per share, for the fiscal year ended September 30, 1998. In the fourth quarter
of fiscal 1998, the Company recorded restructuring charges for YESCo, including
the impact of management's decisions to restructure its HVAC operations and
dispose of the existing assets and projects under development for the Power
13
division. The HVAC restructuring included the consolidation of four locations
into one operating center, thereby eliminating redundant administrative and
operating positions, and better focusing its business both geographically, by
discontinuing non-Connecticut activities, and operationally, by discontinuing
the HVAC equipment sales operation. The after-tax charge for YESCo restructuring
totaled $1.6 million, or $0.15 per share. YESCo recorded losses of $3.0 million,
exclusive of nonrecurring charges, and $2.7 million for the years ended
September 30, 1998 and 1997, respectively. Finally, Yankee Energy recorded an
after-tax charge for severance, due to the resignation of two senior executives,
of approximately $0.5 million, or $0.05 per share.
RESULTS OF OPERATIONS
Operating Revenues
Utility revenues decreased $8.2 million, or 3 percent, in fiscal 1999 from
fiscal 1998 and decreased $35.1 million, or 11 percent, in fiscal 1998 from
fiscal 1997. In fiscal 1999, nonutility revenues decreased $3.0 million from
fiscal 1998 and in fiscal 1998, nonutility revenues increased $24.8 million from
fiscal 1997. The components of operating revenues for the past three years are
provided in the following table:
Years Ended September 30, 1999 1998 1997
- ------------------------- ---- ---- ----
(In thousands)
Firm sales $223,806 $237,136 $276,299
Firm transportation 25,626 18,709 7,433
Interruptible/off-system sales 18,136 20,303 29,183
Interruptible transportation 3,601 3,646 2,646
Other utility revenues 4,450 4,045 3,393
-------- -------- --------
Total utility revenues 275,619 283,839 318,954
Nonutility revenues 27,863 30,928 6,087
-------- -------- --------
Total operating revenues $303,482 $314,767 $325,041
======== ======== --------
Utility operating margin $144,696 $139,655 $146,143
======== ======== ========
Nonutility operating margin $ 6,410 $ 5,825 $ 2,141
======== ======== ========
Throughput corresponding to utility revenues is as follows:
(Mcf-thousands)
Firm sales 24,685 26,537 31,447
Firm transportation 11,679 9,266 4,059
Interruptible/off-system sales 5,003 4,698 6,575
Interruptible transportation 5,062 6,646 6,853
------ ------ ------
Total throughput 46,429 47,147 48,934
====== ====== ======
Utility revenues decreased in fiscal 1999 as compared with fiscal 1998
regardless of weather that was 2% colder than the prior year. This decrease
was primarily due to the continued shift from firm sales to firm
transportation. An increasing number of commercial and industrial customers
continued to shift from gas sales to transportation service resulting in a
decrease in utility revenues, as prices for transportation services do not
include gas costs. In addition in fiscal 1999, revenues were negatively
impacted by a decrease in interruptible sales and transportation. This was
due to higher gas prices as compared with oil prices in fiscal 1999 making
gas less economical for customers able to use alternative fuels. Nonutility
revenues decreased in fiscal 1999 due to the downsizing of YESCo's
14
operations, partially offset by an increase in RMS' revenues due to their
expansion. The decrease in utility revenues in fiscal 1998 primarily
reflected weather that was 8 percent warmer in fiscal 1998 compared to fiscal
1997 and customer bill credits during fiscal 1998 of $3.2 million. The warmer
weather in the fiscal 1998 heating season directly reduced sales to firm
sales customers. Firm sales contribute the highest per-unit operating margin
of all utility revenues, and thus, the primary reason for the decrease in
utility operating margin from fiscal 1997. In addition, an increasing number
of commercial and industrial customers continued to shift from gas sales to
transportation service resulting in a decrease in utility revenues.
Interruptible revenues have decreased primarily as a result of lower oil
prices in fiscal 1998 compared to fiscal 1997. Revenues from nonutility
operations increased $24.8 million from 1997 to 1998 due to the growth of
nonutility subsidiaries, primarily due to acquisitions.
Operating Expenses
Total operating expenses decreased $17.5 million in 1999 compared to 1998
and decreased $0.5 million in 1998 compared to 1997 as a result of the following
items:
- - Cost of gas decreased $13.2 million, or 9 percent, in 1999 compared to 1998
and decreased $28.6 million, or 17 percent, in 1998 compared to 1997. The
fiscal 1999 and fiscal 1998 decreases were due primarily to a 6 percent and
16 percent decrease in utility revenues, excluding transportation revenues,
respectively, as a result of the warmer weather. Cost of gas was also
impacted by transportation customers who purchase their own gas supply from
marketers which is transported through the Yankee Gas distribution system.
- - Cost of goods sold decreased $3.6 million in 1999 compared to 1998, due to
the corresponding decrease in nonutility revenues. Cost of goods sold
increased $20.6 million in 1998 compared to 1997, due to increased YESCo
activity from acquisitions, particularly in mechanical contracting.
- - Operation and maintenance expense decreased $0.2 million in 1999 compared
to 1998 and increased $3.0 million in 1998 compared to 1997. The 1999
decrease was primarily due to a decrease in nonutility activity due to
restructuring, offset by an increase in utility expenses, primarily in the
areas of pension and data processing outsourcing expenses. The 1998
increase was primarily due to increases in nonutility operating expenses,
offset by a decrease in uncollectible expense, as a result of lower
revenues from the warmer weather, and a decrease in pension expense.
- - Merger expenses of approximately $2.0 million have been recorded for legal,
consulting and financial advisory services related to the Merger. In fiscal
2000, the Company expects to incur approximately $3.0 million in additional
merger costs. These additional costs will be expensed as incurred,
primarily at milestone dates of the Merger.
- - Nonrecurring charges relate to restructuring charges for the HVAC
operations of YESCo, impairments of certain YESCo Power division assets and
severance expense. Restructuring charges for YESCo included the impact of
management's decisions to restructure its HVAC operations and dispose of
the existing assets and projects under development for the Power division.
The charge for YESCo restructuring matters totaled $3.5 million in the
fourth quarter of fiscal 1998. Also, in the fourth quarter of fiscal 1998,
YES recorded a charge for severance, of approximately $0.9 million, due to
the resignation of two senior executives.
- - Depreciation and amortization expense increased $1.8 million in 1999
compared to 1998 and increased $1.7 million in 1998 from 1997. The 1999 and
1998 increases were primarily due to additions in both plant assets and
other property and investments.
15
- - Taxes other than income taxes increased $0.4 million in 1999 compared to
1998 and decreased $2.1 million in 1998 compared to 1997. The 1999 increase
was mainly due to an increase in Connecticut state sales tax, due to a
reserve recorded in conjunction with a sales tax audit, and Connecticut
unemployment tax, offset by a decrease in gross earnings tax due to lower
revenues in fiscal 1999. The 1998 decrease was primarily due to decreases
in both gross earnings tax, due to lower revenues in fiscal 1998 compared
to fiscal 1997, and Connecticut unemployment taxes due to lower than
expected unemployment costs associated with Yankee Gas' transformation
project in fiscal 1995.
Interest expense in 1999 increased $0.8 million as compared to 1998
primarily due to higher levels of outstanding long-term debt, offset by lower
interest rates and a decrease in outstanding short-term debt. Interest expense
in 1998 increased $1.4 million as compared to 1997 primarily due to higher
levels of outstanding short-term debt and higher interest rates associated with
short-term debt, offset by a slight decrease in outstanding long-term debt.
Federal and state income taxes increased $3.0 million in 1999 compared to
1998, and decreased $5.1 million in 1998 compared to 1997. The 1999 increase was
primarily due to an increase in taxable income and a higher effective tax rate,
due primarily to non-deductible merger expenses. The 1998 decrease was primarily
due to lower pre-tax income as a result of the warmer weather and nonrecurring
charges. Please refer to Note 2 to the Consolidated Financial Statements for
additional information concerning the components of federal and state income
taxes.
LIQUIDITY AND CAPITAL RESOURCES
Cash and temporary cash investments at September 30, 1999 totaled $1.7
million. Cash provided by operating activities was $42.9 million in fiscal 1999,
$18.5 million in fiscal 1998 and $28.6 million in fiscal 1997. The increase in
cash provided by operating activities was primarily due to the increase in net
income and a decrease in working capital requirements for fiscal 1999. Cash
provided by operating activities in fiscal 1999 was used primarily for dividend
payments and capital expenditures. The Company increased dividends paid per
share to $1.40 in 1999, up 3.0 percent from the $1.36 per share in 1998, the
ninth straight year the Company has increased its dividend. Expenditures for
plant, property and investments totaled $38.6 million in 1999 reflecting a $0.9
million decrease from 1998. Fiscal 1999 capital expenditures included
approximately $7.3 million related to the installation of a new customer service
system. The Company's estimated capital expenditures for fiscal 2000 is $30.8
million. The Company expects to finance the fiscal 2000 capital expenditures
through a combination of internally generated funds and short-term borrowings.
In addition to cash provided by operating activities, the Company generated
cash through financing activities, primarily by the issuance of new common stock
and increases in borrowings. During fiscal 1999 and 1998, the Company issued
42,836 and 82,708 new shares, respectively, under its Shareholder Investment
Plan and 45,468 and 8,240 shares, respectively, under its Long-Term Incentive
Plans. These new shares provided approximately $1.1 million and $2.2 million of
new equity funding in fiscal 1999 and 1998, respectively.
The seasonal nature of gas revenues, inventory purchases and construction
expenditures create a need for short-term borrowing to supplement internally
generated funds. Short-term borrowings decreased $19.7 million during fiscal
1999. Yankee Gas has arranged a $60 million revolving line of credit with a
group of three banks whereby funds may be borrowed on a short-term revolving
basis using either fixed or variable rate loans. Yankee Gas had $34.5 million
and $63.2 million outstanding under its agreements at September 30, 1999 and
1998, respectively. In addition, Yankee Energy had $21.5 and $12.5 million
outstanding at September 30, 1999 and 1998, respectively, on a $15 million line
of credit and a $10 million uncommitted line of credit. The weighted average
interest rates on short-term debt at September 30, 1999 and 1998 were 5.5
percent and 5.8 percent, respectively.
16
The long-term credit needs of Yankee Gas are being met by a first mortgage
bond indenture that provides for the issuance of bonds from time to time as the
need arises, subject to certain restrictions. At September 30, 1999, indenture
requirements, including the required coverage ratio, would allow for the
issuance of an additional $188 million of bonds at an assumed interest rate of
7.1 percent.
In January 1999, Yankee Gas completed a $50 million new long-term debt
financing at 6.2 percent, for the purposes of replacing a portion of the
existing outstanding short-term debt and retiring certain long-term debt. On
August 2, 1999, Yankee Gas redeemed its Series A Tranche D First Mortgage Bonds
with cash on hand and short-term debt facilities.
On April 1, 1997, Yankee Gas redeemed all $30 million Series A Tranche C
First Mortgage Bonds, which matured on that date. Yankee Gas used cash on hand
and the issuance of a $30 million principal amount of Series E First Mortgage
Bonds on April 1, 1997 to redeem the Series A Tranche C First Mortgage Bonds.
The Series E First Mortgage Bonds will mature April 1, 2012 and interest is
payable at an annual rate of 7.2 percent.
TAX AUDITS
The Company is currently under audit by the State of Connecticut regarding
the Company's Sales and Use Tax returns for the calendar years 1996, 1997 and
1998, by the City of Naugatuck, Connecticut regarding the Company's Personal
Property Tax Schedules for the years 1995, 1996 and 1997, and by the Internal
Revenue Service (IRS) regarding the Company's Federal Income Tax returns for the
calendar years 1995 and 1996. The Company is responding to all information
document requests put forth by the auditors. At this time, the Company does not
have sufficient information to determine the amount, if any, of additional
liability that may result from these proceedings. The Company is expecting a
formal proposal from the IRS regarding adjustments to the 1995 Federal Income
Tax Return. The Company does not anticipate that any of these audits, including
the audit of the 1995 Federal Income Tax Return, will have a material effect on
its consolidated results of operations or financial position.
YEAR 2000
The Company has implemented new information systems and enhanced existing
information systems to address Year 2000 issues. These issues could have
significant adverse effects on the Company if not properly resolved. In fiscal
1995, the Company began testing and remediation for Year 2000 problems and has
assigned dedicated personnel to its Year 2000 project. Remediated programs have
been tested prior to being declared compliant.
As of September 30, 1999, YES has completed the inventory, assessment of
risk, remediation and testing phases of the Year 2000 project for all
mainframe systems. The Company is currently finalizing the process of
reviewing and testing contingency plans. As part of the process, a detailed
inventory of all hardware and software currently utilized by the Company has
been prepared. All mission critical systems have been remediated and tested
for Year 2000 issues. The scope of the assessment phase also included the
Company's interface systems with significant suppliers, government agencies
and other third parties.
17
However, there can be no guarantee that the systems of these third parties
will be converted on a timely basis and will not have an adverse effect on
the Company's operations or systems.
In addition to remediating existing systems, the Company has purchased
and installed a new Human Resource Information System ("HRIS") and installed
a new Customer Connection Information System ("CCIS") system. These systems
were purchased to improve functionality of the application software and to
improve efficiency and customer service. In addition, the Company believes
that any Year 2000 issues associated with these systems have been eliminated.
The new HRIS system became operational in January 1, 1999 and the CCIS system
became operational on July 12, 1999.
For non-mainframe systems, the Company has developed a test environment
to carry out the remainder of the remediation program. The inventory and risk
assessment phase of all non-mainframe systems was completed by the end of
1998. The remediation/replacement and testing phases were completed by
September 1999. In March 1999, the Company installed a new Supervisory
Control and Data Acquisition system ("SCADA"), which monitors gas flows and
pressures within the distribution system. The Company believes that this
eliminated any Year 2000 issues associated with that system.
The Company currently estimates that total costs to update all of the
Company's systems, which would also render them Year 2000 compliant, will be
approximately $24.8 million, including approximately $0.6 million for the new
HRIS system, $21.3 million for the new CCIS system and $1.3 million for the new
SCADA system. All such costs associated with system enhancements have and will
continue to be expensed as incurred and the costs of new systems will be
capitalized as appropriate. As of September 30, 1999, 1998 and 1997, the Company
expensed approximately $173,000, $152,000 and $217,000, respectively, and
capitalized approximately $7.6 million, $9.7 million and $5.9 million,
respectively, of these costs. The remaining costs will be incurred by December
31, 1999. These costs have been financed through short-term borrowing and
internally generated funds.
The primary business risk associated with Year 2000 is the Company's
ability to continue to transport and distribute gas to its customers without
interruption. In the event the Company and/or its suppliers and vendors are
unable to remediate the Year 2000 problem prior to January 1, 2000, operations
of the Company could be significantly impacted. In order to mitigate this risk,
the Company has developed contingency plans to continue operations through
manual intervention and other procedures should it become necessary to do so.
Such procedures include back-up power supply for its critical pipeline and
storage operations and, if necessary, curtailment of supply. The Company has
completed its operational contingency plans and is in the process of reviewing
and testing them.
Although the Company expects its systems to be Year 2000 compliant on or
before December 31, 1999, it cannot predict the outcome or the success of its
Year 2000 program, or that the costs required to address the Year 2000 issue, or
that the impact of a failure to achieve substantial Year 2000 compliance, will
not have a material adverse effect on the Company's business, financial
condition or results of operations.
OTHER MATTERS
In fiscal 1999 and 1998, the Company's wholly-owned, nonregulated
subsidiary, Yankee Financial, sold portions of its loan receivable portfolio to
independent parties. Yankee Financial recognized small gains as a result of the
sales. The transactions were recorded as sales for financial reporting purposes.
In June 1998, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 133, "Accounting for Derivative Instruments
and Hedging Activities," which requires the Company to recognize all
18
derivatives as either assets or liabilities in the consolidated balance
sheets and measure those instruments at fair value. Management is currently
evaluating the impact of this standard and believes the adoption will not
materially impact the Company's consolidated financial position, results of
operations or cash flows. This statement is effective for the Company in the
first quarter of fiscal year 2001.
FORWARD-LOOKING STATEMENTS
This report contains statements which, to the extent they are not
recitations of historical fact, constitute "forward-looking statements" within
the meaning of the Private Securities Litigation Reform Act of 1995. Such
forward-looking statements involve risks and uncertainties. Actual results may
differ materially from such forward-looking statements for reasons including,
but not limited to, changes to and developments in the legislative and
regulatory environments affecting the Company's business, the impact of
competitive products and services, changes in the natural gas industry caused by
deregulation and other factors, certain environmental matters, internal and/or
third party delays or failures in achieving Year 2000 compliance, as well as
such other factors as set forth in this report and the Company's other filings
with the Securities and Exchange Commission.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
COMMODITY MARKET RISK
Yankee Gas is subject to market risk due to fluctuations in the price of
natural gas. All of Yankee Gas' sales are designed to fully recover the cost of
gas. Yankee Gas passes on to its firm customers changes in gas costs from those
reflected in its tariffs under purchased gas adjustment provisions allowed by
the DPUC. Interruptible and off-system sales are priced competitively at not
less than the cost of gas associated with those sales plus applicable taxes and
margin.
Yankee Gas has entered into fixed revenue-rate contracts with two customers
for the delivery of natural gas. Yankee Gas has hedged these commitments with
the purchase of natural gas swaps. In order to satisfy certain provisions of the
arrangement, Yankee Gas has provided a letter of credit for $1.75 million, as of
September 30, 1999. The Company's results of operations are unaffected by the
hedge transaction given that it passes through the cost of the hedge to either
the commodity trading firm or its customer depending on the difference in the
fixed and floating prices for gas.
INTEREST RATE RISK
The Company entered into an interest rate swap transaction in February
1999. The $49,000,000 (notional amount) agreement had the effect of converting
the interest obligations on Yankee Gas' $19,000,000, 10.07% Bonds and
$30,000,000, 7.19% Bonds to variable rates. Under the agreement, the Company
receives the stated fixed rate and pays a floating rate based on a "basket" of
interest rate indices, as determined in six month intervals. Net receipts or
payments under the agreement are recognized as adjustments to interest expense.
The maximum exposure to the Company is $250,000 per year.
In addition, both Yankee Energy and Yankee Gas have committed and
uncommitted lines of credit with variable interest rates.
19
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The Consolidated Financial Statements of Yankee Energy and the Notes
thereto, together with the reports thereon of the Company's management and of
Arthur Andersen LLP are included herein on pages F-1 through F-21.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
20
PART III
ITEM 10. DIRECTORS AND OFFICERS OF THE COMPANY
The Directors and Executive Officers of the Company are as follows:
POSITION AND BUSINESS EXPERIENCE
NAME AGE DURING PAST FIVE YEARS
- ---- --- --------------------------------
Sanford Cloud, Jr. 55 Director of the Company since 1995. President and
Chief Executive Officer of The National Conference
for Community and Justice, New York, New York,
since April 1994. Previously, he was a partner in
the law firm of Robinson and Cole, Hartford,
Connecticut from January 1993 until March 1994 and
Vice President of Aetna Life and Casualty Co. from
December 1986 until December 1992. Mr. Cloud is a
Director of The Advest Group, Inc. and Tenet
Healthcare Corp.
Charles E. Gooley 46 President, Chief Executive Officer and a Director
of the Company and Chairman, President, Director
and Chief Executive officer of its direct
subsidiaries, Yankee Gas, Yankee Financial, YESCO
and NorConn since September 1998 and President of
Yankee Gas since May 1997. Previously, he served
as Executive Vice President of the Company and its
direct subsidiaries, Yankee Gas, YESCO, NorConn,
and Yankee Financial, from July 1994 to September
1998, and as Vice President, General Counsel and
Assistant Secretary of the Company from July 1989
to July 1994.
Eileen S. Kraus 61 Director of the Company since 1990. Chairman,
Connecticut, Fleet National Bank since December 1,
1995. Previously, she was President of Shawmut
Bank Connecticut, N.A. and Vice Chairman of
Shawmut National Corporation from September 1992
until December 1, 1995, Vice Chairman, Consumer
Banking and Marketing Groups of predecessor banks
from 1990 to 1992, and Executive Vice President of
predecessor banks from 1987 to 1990. She is a
Director of Best Foods, Kaman Corporation and The
Stanley Works.
Emery G. Olcott 61 Director of the Company since 1989 and Chairman of
the Board since September 1998. Chairman,
President and Chief Executive Officer of Packard
BioScience Company (f/k/a Canberra Industries,
Inc.) since 1971. Packard is a manufacturer and
distributor of analytical instruments and
chemicals.
John J. Rando 47 Director of the Company since 1997.
Advisor-Partner with NewcoGen Group, Cambridge,
Massachusetts, since November 1999. Chairman of
@Stake, Inc., a professional services start-up
company specializing in security solutions and
services for internet e-commerce environments
since December 1999. Previously, he was Senior
Vice and Group General Manager of Compaq Computer
Corporation from June 1998 to July 1999 and Vice
President and General Manager of Digital Equipment
Corporation from November 1976 to June 1998.
21
Patricia M. Worthy 55 Director of the Company since 1996. Professor,
Howard University School of Law since 1992.
Previously, she served as Chief of Staff and Legal
Counsel to Mayor Sharon Pratt Kelly of Washington,
D.C. from 1991 to 1992 and was Commissioner,
District of Columbia Public Service Commission
from 1980 to 1983, and then served as Chairman of
the Commission from 1983 to 1991. She serves as
Chairman of the District of Columbia Judicial
Nomination Commission.
J. Kingsley Fink 47 Vice President-Operations of Yankee Gas since
October 1997. Previously, he was President of his
own consulting company from 1996 to 1997. Prior
thereto he served in various operating positions
at Florida Power and Light Company over a 14-year
period.
Mary J. Healey 48 Vice President, General Counsel and Secretary of
the Company and its direct subsidiaries since
January 1995. Previously, she served as Secretary
and Assistant General Counsel of the Company from
January 1992 to January 1995 and as Secretary and
Counsel of the Company from July 1989 to January
1992.
Thomas J. Houde 52 Vice President of the Company and its direct
subsidiary, Yankee Gas, since January 1992.
Previously, he served as Director, Corporate
Planning, Rates and Economic Analysis of Yankee
Gas from March 1990 to December 1991.
Steven P. Laden 51 Vice President of the Company and its direct
subsidiary, Yankee Gas since July 1996. From
October 1991 to July 1996, he served as Vice
President of Marketing of Southern Union Company,
a company engaged in various aspects of the energy
business including the distribution of natural gas
in Texas and Missouri.
James M. Sepanski 42 Vice President and Chief Financial Officer of the
Company and its direct subsidiaries, Yankee Gas,
YESCo, NorConn, and Yankee Financial, and
Secretary of R.M. Services, Inc., since December
1999. Previously, he served as Vice President and
Chief Financial Officer of the Company and its
direct subsidiaries, Yankee Gas, YESCo, NorConn,
and Yankee Financial, and as President of R.M.
Services, Inc. from July 1997 to December 1999.
From 1989 to June 1997, he was a partner at Arthur
Andersen LLP.
The Board of Directors is divided into three classes. One class is elected
at each annual meeting of the Company to serve a three-year term. All executive
officers are elected annually by the Company's Board of Directors. There are no
family relationships among the executive officers and directors nor are there
any arrangements or understandings between any executive officer and any other
person pursuant to which the officer was selected.
22
ITEM 11. EXECUTIVE COMPENSATION
SUMMARY COMPENSATION TABLE
The following table sets forth certain information regarding the
compensation paid by the Company and its subsidiaries to the Chief Executive
Officer and the next four most highly compensated executive officers of the
Company during the last fiscal year (the "Named Executive Officers") for
services rendered in all capacities to the Company and its subsidiaries.
SUMMARY COMPENSATION TABLE
Long-term Compensation
Annual Compensation Awards
--------------------- -----------------------
Securities
Restricted Underlying
Name and Fiscal Stock Options All Other
Principal Position Year Salary($) Bonus($) Awards($)(1) (#) Compensation($)(2)
- ------------------ ---- --------- -------- ------------ --- ------------------
Charles E. Gooley (3) 1999 293,642 125,000 0 5,200 8,820
President and Chief 1998 215,000 50,900 510,781 6,000 0
Executive Officer 1997 184,384 37,800 0 0 2,400
James M. Sepanski (4) 1999 179,325 43,600 0 2,100 4,480
Vice President and 1998 169,950 32,200(5) 91,169 1,800 53,942
Chief Financial Officer 1997 41,250 0 70,008 0 33,000
J. Kingsley Fink (6) 1999 147,321 39,800 0 1,700 25,838
Vice President - 1998 136,035 31,400 75,098 600 32,685
Operations
Steven P. Laden 1999 139,460 40,500 0 1,100 1,980
Vice President 1998 133,017 19,400(5) 0 2,500 --
1997 128,750 32,800 0 0 41,865
Mary J. Healey 1999 134,461 32,600 0 1,000 5,680
Vice President, General 1998 123,500 20,600 0 1,800 1,994
Counsel and Secretary 1997 118,750 22,700 0 4,300 1,241
- -----------
(1) The amounts shown represent the value of the restricted stock award,
calculated by multiplying the closing market price of the Company's Common Stock
on the date of grant by the number of shares awarded. Restricted stock holdings
as of September 30, 1999, and their value on such date, based on an equivalent
number of unrestricted shares were: Mr. Gooley, 17,500 shares ($747,031); Mr.
Sepanski, 5,087 shares ($217,151); and Mr. Fink, 2,640 shares ($112,695).
(2) All other compensation includes the Company's matching contributions
under the Company's 401(k) Plan. It also includes the following: (i) Mr.
Sepanski received payment for relocation expenses of $53,942 in 1998 and
received a signing bonus of $33,000 in 1997; (ii) Mr. Fink received payment
for relocation expenses of $17,335 in 1999 and $32,685 in 1998; and (iii) Mr.
Laden received payment for relocation expenses of $39,465 in 1997.
(3) Mr. Gooley was appointed President and Chief Executive Officer of the
Company on September 29, 1998.
23
Mr. Gooley was previously appointed President of Yankee Gas Services Company in
May 1997 and served as Executive Vice President of the Company from July 1994 to
September 1998.
(4) Mr. Sepanski became Vice President and Chief Financial Officer of the
Company in July 1997.
(5) Pursuant to an election of the executive officer, 50 percent of such bonus
was paid in cash and 50 percent was paid in the Company's Common Stock. The
number of shares awarded was determined by dividing 50 percent of the award by
$26.1875, which was the fair market value of the Common Stock on September 30,
1998.
(6) Mr. Fink became Vice President - Operations of Yankee Gas Services Company
on September 29, 1997.
OPTION GRANTS IN LAST FISCAL YEAR
The following table sets forth certain information regarding stock options
granted under the Company's 1996 Long-Term Incentive Compensation Plan to the
Named Executive Officers during the fiscal year ended September 30, 1999.
OPTION GRANTS IN LAST FISCAL YEAR
Individual Grants Potential
----------------------------------------------- Realizable Value at
Assumed Annual
Number of % of Total Rates of Stock
Securities Options Price Appreciation
Underlying Granted to Exercise for Option Term (2)
Options Employees in Price Expiration -------------------
Name Granted(#)(1) Fiscal Year ($/Sh) Date 5%($) 10%($)
----- ------------- ----------- ------ ---- ----- ------
Charles E. Gooley 5,200 25 $ 29.31 05/11/09 95,888 242,840
James M. Sepanski 2,100 10 $ 29.31 05/11/09 38,724 98,070
J. Kingsley Fink 1,700 8 $ 29.31 05/11/09 31,348 79,390
Steven P. Laden 1,100 5 $ 29.31 05/11/09 20,284 51,370
Mary J. Healey 1,000 5 $ 29.31 05/11/09 18,440 46,700
(1) Options granted vest ratably over five years on each of the first five
anniversary dates of the grant date.
(2) The dollar amounts under these columns are the result of calculations
assuming 5% and 10% growth rates as set by the Securities and Exchange
Commission and, therefore, are not intended to forecast future price
appreciation, if any, of the Company's Common Stock.
24
AGGREGATED OPTION EXERCISES IN LAST FISCAL YEAR AND FISCAL YEAR-END OPTION
VALUES
The following table sets forth certain information with respect to the
Named Executive Officers regarding options held as of September 30, 1999.
AGGREGATED OPTION EXERCISES IN LAST
FISCAL YEAR AND FISCAL YEAR-END OPTION VALUES
Number of Value of
Securities Unexercised
Underlying In-The-Money
Unexercised Options
Options at At Fiscal
Shares Value Fiscal Year End (#) Year-End ($)(1)
Acquired on Realized Exercisable/ Exercisable/
Name Exercise (#) ($) Unexercisable Unexercisable
-------- ------------ -------- ------------------- ---------------
Charles E. Gooley 7,500 135,900 5,040/12,560 112,959/192,870
James M. Sepanski 0 0 220/1,580 11,084/51,564
J. Kingsley Fink 0 0 120/2,180 2,347/32,129
Steven P. Laden 0 0 380/2,120 16,762/45,726
Mary J. Healey 0 0 3,660/4,540 105,053/68,670
(1) Based on the fair market value of the Company's Common Stock as of September
30, 1999 ($42.6875), less the exercise price of the options.
LONG-TERM INCENTIVE COMPENSATION AWARDS
In October 1997, the Organization and Compensation Committee of the Board
of Directors (the "Committee") set long-term incentive compensation awards for
certain key employees of the Company, including the individuals named in the
Summary Compensation Table. The awards are contingent upon the Company achieving
certain performance goals described below. The awards are measured in dollar
amounts, but, to the extent that the performance goals are achieved, will be
paid in shares of Common Stock pursuant to the long-term incentive award
provisions of the 1996 Long-Term Incentive Compensation Plan. One half of any
shares awarded will be subject to certain transfer restrictions imposed by the
Committee. The number of shares to be issued shall be based on the closing price
of the Common Stock on the last day of the three-year performance period. Under
the terms of the awards, there are two equally weighted performance goals
measured over the fiscal 1998-2000 three-year period: (i) the relative stock
performance of the Company's Common Stock compared with the stock of a group of
peer natural gas distribution companies; and (ii) annualized earnings growth.
However, if certain minimum performance measurements are not achieved in either
category, no awards will be granted regardless of performance achieved in the
other category. The Committee established threshold, target and maximum
performance results to be achieved in connection with the awards. Under the 1996
Long-Term Incentive Compensation Plan, the award levels for each job level is
25
based upon a percentage of the salary range midpoint for that job level. For
the fiscal 1998-2000 performance period, these levels are 20%, 40% and 80%
for Mr. Gooley and 15%, 30% and 60% for the other current executive officers
named in the Summary Compensation Table. In particular, the threshold, target
and maximum performance awards are: $45,320, $90,640 and $181,280 for Mr.
Gooley; $20,685, $41,370 and $82,740 for Mr. Sepanski; $17,835, $35,670 and
$71,340 for Mr. Fink; $17,835, $35,670 and $71,340 for Mr. Laden; and
$17,835, $20,685 and $71,340 for Ms. Healey. The Committee may, in good
faith and in response to unforeseen circumstances or significantly changed
conditions, modify performance goals or the formula for applying such goals
during the performance cycle.
CHANGE-IN-CONTROL AND TERMINATION OF EMPLOYMENT AGREEMENTS
The Company has entered into Change in Control Executive Severance
Agreements with each of Messrs. Gooley, Sepanski, Fink, Laden and Ms. Healey.
The intent of the agreements is to assure continuity in the management of the
operations of the Company in the event of a "change in control." A change in
control is defined as occurring when (i) any person becomes the beneficial
owner, directly or indirectly, of 25% or more of the Company's Common Stock,
(ii) there is a change in the majority of the Board during a 25-month period,
(iii) a consolidation or merger of the Company is consummated in which the
Company is not the continuing or surviving corporation or pursuant to which the
Company's Common Stock would be converted into cash, securities or other
property, other than a merger of the Company in which the holders of the
Company's Common Stock have the same proportionate ownership of Common Stock of
the surviving corporation, (iv) the consummation of any sale, lease, exchange or
other transfer of a majority of the Company's assets, (v) the Company's
shareholders approve any plan or proposal for the liquidation or dissolution of
the Company, or (vi) the Board determines that a change in control has occurred.
These agreements provide that in the event that the executive officer's
employment is terminated within two years of a change in control either by (i)
the Company for reasons other than for disability, death or cause, or (ii) the
executive officer due to (a) material diminution in status, position, duties or
responsibilities, (b) a reduction in total compensation, or (c) assignment to a
location more than 50 miles from the executive officer's current place of
employment, the executive officer is entitled to a severance payment. The amount
payable upon the occurrence of any of the foregoing events is two times the sum
of the executive officer's annual base salary at the date of the change in
control plus the average annual incentive compensation paid to the executive
officer in the two fiscal years prior to the fiscal year in which the change in
control occurs. In addition, the executive officer shall be entitled to
participate in all benefit plans in which such officer participated in prior to
the termination, and if the executive officer is age 55 or older on the date of
termination of employment, such officer shall be entitled to receive service
credit under the Company's pension plans until his or her normal retirement
date. The agreements will be automatically renewed on each successive January 1,
unless not later than December 1 of the preceding year, one of the parties
notifies the other that he or she does not wish to extend the agreement, except
that the agreement shall be automatically extended for 24 months after any
change in control.
26
RETIREMENT PLANS
The following table sets forth the annual pension benefits payable upon
normal retirement at age 65, pursuant to the Yankee Energy System, Inc.
Retirement Plan (the "Retirement Plan", described below) and the Company's
Excess Benefit Plan (the "Excess Benefit Plan", described below), based upon the
average annual earnings and years of service indicated.
AVERAGE ANNUAL
EARNINGS FOR THE HIGHEST
CONSECUTIVE 60 MONTHS OF YEARS OF SERVICE
LAST 120 MONTHS PRIOR --------------------------------------------------------------------
TO NORMAL RETIREMENT
- ------------------------
15 20 25 30 35 40
-------- -------- ------- -------- -------- --------
$ 75,000 $ 15,635 $ 20,847 $ 28,059 $ 31,271 $ 36,482 $ 38,357
125,000 26,885 35,847 44,809 53,771 62,732 65,857
175,000 38,135 50,847 63,559 76,271 88,982 93,357
225,000 49,385 65,847 82,309 98,771 115,232 120,857
275,000 60,635 80,847 101,059 121,271 141,482 148,357
325,000 71,885 95,847 119,809 143,771 167,732 175,857
375,000 83,135 110,847 138,559 166,271 193,982 203,357
Pursuant to provisions of the Internal Revenue Code, compensation earned
that is used in calculating retirement benefits under the Retirement Plan is
limited to a maximum of $160,000. This affects the benefit calculation for
certain individuals and effectively reduces their benefits under the Retirement
Plan. The Company's Excess Benefit Plan provides benefits not payable under the
Retirement Plan due to the $160,000 limitation. The maximum annual benefit that
can be paid in 1999 to a participant from a tax qualified benefit plan is
$130,000.
All employees of the Company, including the Named Executive Officers, are
entitled to participate in the Retirement Plan, which is a non-contributory,
defined benefit retirement plan. Retirement benefits are based on years of
credited service and the employee's average annual earnings, which is the
average of an employee's five highest years of earnings during the last ten
years of employment. The benefits presented are based on straight life annuity
and do not take into account any reduction for joint and survivorship annuity
payments. The Retirement Plan provides for several optional forms of benefit
payments, including a straight life annuity option, a contingent annuitant
option, a ten-year certain and life option and a level income option. Retirement
benefits under the Retirement Plan are not reduced by the employee's Social
Security benefits. Contributions, which are actuarially determined, are made to
the Retirement Plan by the Company for the benefit of all employees covered by
the Retirement Plan. The Retirement Plan provides for continued benefit accruals
for employees who work beyond age 65.
As of September 30, 1999, the years of credited service under the
Retirement Plan for Messrs. Gooley, Sepanski, Fink, Laden and Ms. Healey were
18, 2, 2, 6, and 10, respectively. The years of credited service for certain of
the executive officers named above include prior service under the Northeast
Utilities Service Company Retirement Plan. Mr. Laden receives two years of
credited service for every one year of service completed for the first five
years of service pursuant to an agreement with the Company. Under federal law,
an employee's benefits under a qualified pension plan, such as the Retirement
Plan, are limited to certain amounts. The Company has adopted the Excess Benefit
Plan in which all of the Named Executive Officers may participate. The Excess
27
Benefit Plan supplements the benefits of a participant in the Retirement Plan
in an amount by which such participant's benefits under the Retirement Plan
are limited by law. The Excess Benefit Plan also provides for the payment of
additional retirement benefits in the same manner as under the Retirement
Plan on remuneration paid under certain management incentive plans. The
Excess Benefit Plan is an unfunded plan that is not intended to meet the
qualification requirements of Section 401 of the Internal Revenue Code.
DIRECTOR COMPENSATION
In fiscal year 1999, non-employee directors received an annual retainer of
$15,000, consisting of $10,000 in Common Stock of the Company and $5,000 in
cash, each paid in equal installments on a quarterly basis in December, March,
June and September. Board committee chairs received an additional annual cash
retainer of $1,500. Non-employee directors also received $1,000 for each Board
and committee meeting attended. Directors who are full-time employees of the
Company or a subsidiary receive no additional compensation for services as a
member of the Board or any committee of the Board.
Under the Non-Employee Directors' Stock Compensation Plan, established in
1991 to promote ownership of the Company's Common Stock by members of the Board,
each non-employee director, upon his or her election or reelection to the Board,
receives an award of 450 restricted shares of the Company's Common Stock.
One-third of such restricted shares of Common Stock vests each year at
subsequent annual meetings of shareholders. The Board may make appropriate
adjustments in share amounts in the event of any change in the Company's Common
Stock, such as a stock split, or other change in the Company's corporate
structure or distribution to shareholders. Participants in the plan have voting
rights and rights to receive dividends and other distributions with respect to
such shares, but until their vesting, such shares are subject to the plan's
provisions on forfeiture and restrictions on disposition. In January 1999, Mr.
Cloud and Mr. Rando each received 450 shares upon election to a three-year term,
and 150 shares vested for all non-employee directors upon completion of a year
of their respective terms.
The Company's Non-Employee Director Deferred Compensation Plan permits
non-employee directors to defer all or a portion of total fees for all services
rendered as a director, including meeting fees, committee chair retainers,
quarterly retainers paid in the Company's Common Stock and vested shares of
restricted stock awarded pursuant to the Company's Non-Employee Directors' Stock
Compensation Plan. A non-employee director may elect to have deferred cash
compensation credited to either a cash account or a stock unit account. Amounts
credited to a director's cash account will be credited on a monthly basis with
interest at an annual rate equal to the rate of return of Yankee Gas as filed
with the DPUC. Amounts credited to a director's stock unit account will be
credited initially as a dollar amount which shall be converted into stock units
on a quarterly basis by dividing the dollar amount by the closing price of the
Company's Common Stock on the last day of each quarter. Stock units will be
further credited with an amount equal to the dividends payable if the stock
represented by the stock units had been outstanding. Quarterly retainers paid in
the Company's Common Stock and vested shares of restricted stock deferred by a
director pursuant to the Non-Employee Director Deferred Compensation Plan will
be automatically allocated to such director's stock unit account. A non-employee
director may also elect among various options as to how and when compensation
deferred pursuant to the Plan will be paid to the director. The director may
elect to commence payment of deferred compensation at a specified future date or
after the date on which the participant ceases to be a director for any reason.
A director may also elect to receive payment as a single lump sum or over a
fixed period of time. Amounts credited to the director's cash account will be
paid in cash. Amounts credited to the director's stock unit account will be paid
in cash or in shares of the Company's Common Stock, based on the prior election
of the director.
28
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following table sets forth information regarding the beneficial
ownership of shares of Yankee Energy Common Stock as of December 7, 1999, by (i)
each director; (ii) each Named Executive Officer; and (iii) all current
executive officers and directors as a group.
Name of Number of Yankee Shares
Beneficial Owner Title Beneficially Owned (1)
---------------- ----- ----------------------
Sanford Cloud, Jr. Director 2,539
J. Kingsley Fink (2) Vice-President--Operations, Yankee Gas 4,488
Charles E. Gooley (3) President and C.E.O. 26,523
Mary J. Healey (4) Vice-President, General Counsel and Secretary 8,354
Eileen S. Kraus Director 3,809
Steven P. Laden (5) Vice-President 6,231
Emery G. Olcott Director 7,170
John J. Rando Director 672
James M. Sepanski (6) Vice-President and C.F.O. 7,117
Patricia M. Worthy Director 450
Current Directors and Executive 73,283
Officers As a Group (11 persons) (7)
(1) As of December 7, 1999, each of the directors and executive officers
identified above and all current directors and executive officers of the
Company as a group beneficially owned less than 1% of the outstanding
Common Stock of the Company. The number of shares shown includes 450 shares
of restricted stock held by Mr. Rando, 300 shares of restricted stock held
by Ms. Kraus and Ms. Worthy, 225 shares of restricted stock held by Mr.
Cloud and 150 shares of restricted stock held by Mr. Olcott granted under
the Company's Non-Employee Directors Stock Compensation Plan, which shares
had not vested by December 7, 1999. The number of shares shown also
includes 13,125 shares of restricted stock held by Mr. Gooley, 825 shares
of restricted stock held by Mr. Fink, 474 shares of restricted stock held
by Mr. Laden and 4,362 shares of restricted stock held by Mr. Sepanski
granted under the Company's 1991 and 1996 Long-Term Incentive Compensation
Plans, which shares had not vested by December 7, 1999. Pursuant to the
terms of each plan, such individuals have the power to vote and receive
dividends with respect to such shares but do not have dispositive power
with respect to such shares until such shares are vested.
(2) Includes 120 shares issuable upon exercise of options that are exercisable
within 60 days of December 7, 1999.
(3) Includes 7,220 shares issuable upon exercise of options that are
exercisable within 60 days of December 7, 1999.
(4) Includes 6,160 shares issuable upon exercise of options that are
exercisable within 60 days of December 7, 1999.
(5) Includes 2,500 shares owned by Mr. Laden's spouse and 880 shares issuable
upon exercise of options that are exercisable within 60 days of December 7,
1999.
(6) Includes 580 shares issuable upon exercise of options that are exercisable
within 60 days of December 7, 1999.
(7) Includes an aggregate of 20,211 shares of non-vested restricted stock held
by current directors and executive officers and an aggregate of 18,820
shares issuable upon exercise of options that are exercisable within 60
days of December 7, 1999.
The above shares do not include amounts that have been credited to
participating directors' stock unit accounts under the Company's Non-Employee
Director Deferred Compensation Plan.
29
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
PART IV.
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) 1. Financial Statements:
The report of the Company's management, the report of
independent public accountants and the Company's Consolidated
Financial Statements listed in the Index to Consolidated
Financial Statements on page F-1 hereof are filed as part of
this report, commencing on page F-2 hereof.
Page
----
Index to Consolidated Financial Statements..................... F-1
Management Report.............................................. F-2
Report of Independent Public Accountants....................... F-3
Consolidated Statements of Income for the years ended
September 30, 1999, 1998 and 1997............................ F-4
Consolidated Balance Sheets at September 30, 1999 and 1998..... F-5
Consolidated Statements of Cash Flows for the years ended
September 30, 1999, 1998 and 1997............................ F-6
Consolidated Statements of Capitalization at September 30,
1999 and 1998................................................ F-7
Consolidated Statements of Common Shareholders' Equity for the
years ended September 30, 1999, 1998 and 1997.................. F-8
Notes to Consolidated Financial Statements..................... F-9
2. Financial Statement Schedules:
The following schedules of the Company are included on the attached
pages as indicated:
Page
----
Report of Independent Public Accountants on Schedules ........... S-1
Schedule II Valuation and Qualifying Accounts and Reserves for
the years ended September 30, 1999, 1998 and 1997 ............. S-2
3. Exhibits:
Exhibits for Yankee Energy are listed in the Index to Exhibits... E-1
(b) Reports on Form 8-K:
On June 18, 1999, the Company filed a Current Report on Form 8-K dated June
14, 1999, reporting in Item 5 thereof that the Company had entered into an
Agreement and Plan of Merger providing for the merger transition between the
Company and Northeast Utilities.
On October 27, 1999, the Company filed a Current Report on Form 8-K dated
October 12, 1999, reporting in Item 5 that the Company held a Special Meeting of
Shareholders to approve an Agreement and Plan of Merger dated June 14, 1999
between the Company and Northeast Utilities, a Massachusetts business trust. The
Company's shareholders voted to approve the Merger Agreement.
30
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
Page
----
Index to Consolidated Financial Statements................................ F-1
Management Report......................................................... F-2
Report of Independent Public Accountants.................................. F-3
Consolidated Statements of Income for the years ended September 30,
1999, 1998 and 1997....................................................... F-4
Consolidated Balance Sheets at September 30, 1999 and 1998................ F-5
Consolidated Statements of Cash Flows for the years ended September
30, 1999, 1998 and 1997................................................... F-6
Consolidated Statements of Capitalization at September 30, 1999 and
1998...................................................................... F-7
Consolidated Statements of Common Shareholders' Equity for the years
ended September 30, 1999, 1998 and 1997................................... F-8
Notes to Consolidated Financial Statements................................ F-9
F-1
MANAGEMENT REPORT
The consolidated financial statements of Yankee Energy System, Inc. and
subsidiaries and other sections of this 10K were prepared by management, which
is responsible for their integrity and objectivity. These financial statements,
which were audited by Arthur Andersen LLP, were prepared in accordance with
generally accepted accounting principles using estimates and judgement, where
required, and giving consideration to materiality.
The Company maintains a system of internal controls over financial
reporting, which is designed to provide reasonable assurance to the Company's
management and Board of Directors regarding the preparation of reliable
published financial statements. The system contains self-monitoring
mechanisms, and actions are taken to correct deficiencies as they are
identified. Even an effective internal control system, no matter how well
designed, has inherent limitations, including the possibility of the
circumvention or overriding of controls, and such systems can provide only
reasonable assurance with respect to financial statement preparation.
Further, because of changes in conditions, internal control system
effectiveness may vary over time.
Through established programs, the Company regularly emphasizes to its
management employees their internal control responsibilities and policies
prohibiting conflicts of interest. The Audit Committee of the Board of Directors
is composed entirely of outside directors. This Committee meets periodically
with management, the internal auditors and the independent auditors to review
the activities of each and to discuss audit matters, financial reporting and the
adequacy of internal controls.
Management believes that its system of internal accounting controls and
control environment provide reasonable assurance that its assets are safeguarded
from loss or unauthorized use and that its financial records, which are the
basis for the preparation of all financial statements, are reliable.
/s/ CHARLES E. GOOLEY
President and Chief Executive Officer
/s/ JAMES M. SEPANSKI
Vice President, Chief Financial Officer and Treasurer
F-2
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors and Shareholders of Yankee Energy System, Inc.:
We have audited the accompanying consolidated balance sheets and consolidated
statements of capitalization of Yankee Energy System, Inc. (a Connecticut
corporation) and subsidiaries (the Company) as of September 30, 1999 and 1998,
and the related consolidated statements of income, common shareholders' equity
and cash flows, for each of the three years in the period ended September 30,
1999. 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 Yankee Energy System, Inc. and
subsidiaries as of September 30, 1999 and 1998, and the results of their
operations and their cash flows for each of the three years in the period ended
September 30, 1999, in conformity with generally accepted accounting principles.
/s/ Arthur Andersen LLP
Hartford, Connecticut
November 15, 1999
F-3
CONSOLIDATED STATEMENTS OF INCOME
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
FOR THE YEARS ENDED SEPTEMBER 30, 1999 1998 1997
- -------------------------------------------------------------------------------
Revenues:
Utility revenues $275,619 $283,839 $318,954
Nonutility revenues 27,863 30,928 6,087
-------- -------- --------
Total revenues 303,482 314,767 325,041
-------- -------- --------
Operating expenses:
Cost of gas/goods sold 152,376 169,287 176,757
Operations 61,353 61,964 58,569
Maintenance 6,343 5,978 6,382
Merger expenses 1,981 -- --
Nonrecurring charges 4,436 -- --
Depreciation and amortization 21,560 19,789 18,130
Taxes other than income taxes 20,809 20,431 22,519
-------- -------- --------
Total operating expenses 264,422 281,885 282,357
-------- -------- --------
Operating income 39,060 32,882 42,684
Other income/expense:
Other income, net 243 174 159
Interest expense, net 14,604 13,853 12,463
-------- -------- --------
Income before income taxes 24,699 19,203 30,380
Provision for income taxes 11,324 8,320 13,423
-------- -------- --------
Net income $ 13,375 $ 10,883 $ 16,957
======== ======== ========
Basic and diluted earnings per common share $ 1.26 $ 1.04 $ 1.62
======== ======== ========
The accompanying notes are an integral part of these consolidated financial
statements.
F-4
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
AT SEPTEMBER 30, 1999 1998
- -------------------------------------------------------------------------------
ASSETS
Utility plant, at original cost $591,882 $547,098
Less-Accumulated provision for depreciation 223,142 207,872
-------- --------
368,740 339,226
Construction work in progress 12,308 28,707
-------- --------
Total net utility plant 381,048 367,933
-------- --------
Other property and investments 15,593 12,778
Assets held for sale 15,352 12,361
Current assets:
Cash and temporary cash investments 1,736 1,881
Accounts receivable, less accumulated provision
for uncollectible accounts of $5,979 in 1999
and $8,132 in 1998 38,952 35,946
Fuel supplies 1,316 1,418
Other materials and supplies 1,994 1,972
Accrued utility revenues 6,705 4,028
Prepaid expenses and other 18,165 25,327
-------- --------
Total current assets 68,868 70,572
-------- --------
Deferred gas costs 7,244 10,480
Recoverable environmental cleanup costs 33,816 34,084
Recoverable income taxes 4,166 10,673
Recoverable postretirement benefits costs 1,236 1,725
Other deferred debits 12,963 14,678
-------- --------
Total assets $540,286 $535,284
======== ========
CAPITALIZATION AND LIABILITIES
Capitalization (see accompanying statements):
Common shareholders' equity $165,579 $164,992
Long-term debt, net of current portion 163,050 131,048
-------- --------
Total capitalization 328,629 296,040
-------- --------
Current liabilities:
Notes payable to banks 56,000 75,700
Long-term debt, current portion 1,200 4,217
Accounts payable 23,013 19,643
Accrued interest 3,322 3,176
Pipeline transition costs payable 1,539 2,516
Other 6,456 8,402
-------- --------
Total current liabilities 91,530 113,654
-------- --------
Accumulated deferred income taxes 65,843 72,816
Accumulated deferred investment tax credits 7,948 8,325
Reserve for environmental cleanup costs 35,000 35,000
Postretirement benefits obligation 3,691 3,353
Other deferred credits 7,645 6,096
Commitments and contingencies (Note 9)
-------- --------
Total capitalization and liabilities $540,286 $535,284
======== ========
The accompanying notes are an integral part of these consolidated financial
statements.
F-5
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
FOR THE YEARS ENDED SEPTEMBER 30, 1999 1998 1997
- ----------------------------------------------------------------------------------------------
Cash Flows From Operating Activities:
Net income $ 13,375 $ 10,883 $ 16,957
Adjusted for the following:
Depreciation and amortization 21,560 19,789 18,130
Asset impairment, nonrecurring charge -- 2,037 --
Equity earnings from investments (372) (216) (105)
Deferred income taxes, net (843) 4,598 6,927
Deferred gas costs activity and other non-cash items 6,031 (3,688) (5,007)
Changes in working capital:
Accounts receivable and accrued utility revenues (5,683) (8,305) (271)
Prepaid expenses and other 7,162 (11,395) (5,106)
Accounts payable and accrued liabilities 3,370 (3,098) 170
Other working capital (excludes cash) (1,720) 7,885 (3,089)
-------- -------- --------
Net cash provided by operating activities 42,880 18,490 28,606
Cash Flows From Financing Activities:
Net proceeds from common stock issuance 1,193 2,232 105
Issuance of long-term debt 50,000 -- 30,000
Retirement of long-term debt (21,015) (4,017) (34,017)
(Decrease) increase in short-term debt (19,700) 36,700 18,700
Cash dividends (14,858) (14,267) (13,797)
-------- -------- --------
Net cash (used for) provided by financing activities (4,380) 20,648 991
Investment In Plant And Other:
Utility plant (31,881) (34,649) (31,320)
Other property, investments and assets held for sale (6,764) (4,847) (3,891)
-------- -------- --------
Net cash used for plant and other (38,645) (39,496) (35,211)
Net Decrease In Cash and Temporary Cash
Investments For The Period (145) (358) (5,614)
Cash and Temporary Cash Investments, beginning of period 1,881 2,239 7,853
-------- -------- --------
Cash and Temporary Cash Investments, end of period $ 1,736 $ 1,881 $ 2,239
======== ======== ========
Supplemental Cash Flow Information:
Cash paid during the period for:
Interest, net of amounts capitalized $ 15,313 $ 13,273 $ 14,203
Income taxes $ 3,884 $ 6,469 $ 12,140
The accompanying notes are an integral part of these consolidated financial
statements.
F-6
CONSOLIDATED STATEMENTS OF CAPITALIZATION
(IN THOUSANDS)
AT SEPTEMBER 30, 1999 1998
- -------------------------------------------------------------------------------
Common shareholders' equity:
Common shares - $5 par value, authorized 20,000,000
shares; 10,633,666 and 10,545,362 shares outstanding
at September 30, 1999 and 1998 $ 53,168 $ 52,727
Capital surplus, paid in 90,978 89,949
Unearned compensation-restricted stock awards (a) (131) (131)
Retained earnings 21,564 23,047
Employee stock ownership plan guarantee (b) -- (600)
-------- ---------
Total common shareholders' equity 165,579 164,992
-------- ---------
Long-term debt:
First mortgage bonds (c)
Maturity Interest rates
2004 10.03% -- 20,165
2005 6.75% 20,000 20,000
2009 6.20% 50,000 --
2012 7.19% 30,000 30,000
2019 10.07% 19,000 19,000
2022 8.48% 20,000 20,000
2023 8.63% 20,000 20,000
-------- ----------
Total first mortgage bonds 159,000 129,165
Term loan agreement, 6.24%, due February, 2003 (c) 5,250 5,500
Guarantee of employee stock ownership plan term
loan agreement, 10.38%, final maturity July, 1999 (b) -- 600
-------- --------
Total long-term debt 164,250 135,265
Less amounts due within one year (b)(c) 1,200 4,217
-------- --------
Long-term debt, net 163,050 131,048
-------- --------
Total capitalization $328,629 $296,040
======== ========
(a) Consistent with the terms of the Non-Employee Directors' Stock Compensation
Plan, incentive awards of 225 shares and 1,200 shares of restricted common stock
were granted to directors during 1999 and 1998, respectively. Under the
directors' plan, the market value of the restricted stock awards has been
recorded as unearned compensation and is shown as a separate component of
shareholders' equity. The earned compensation is charged to administrative and
general expense as shares become vested. Earned compensation was approximately
$30,100 for fiscal 1999 and $29,000 for fiscal 1998.
Consistent with the terms of the Long-Term Incentive Compensation Plans of the
Company, incentive awards of 25,600 and 1,711 shares of restricted common stock
were granted to employees during 1999 and 1998, respectively. Under the
Long-Term Compensation Plans, the market value of the restricted stock awards
has been recorded as unearned compensation and is shown as a separate component
of shareholders' equity. The earned compensation is charged to administrative
and general expense as shares become vested. Earned compensation was
approximately $253,000 for fiscal 1999 and $78,000 for fiscal 1998.
(b) On July 20, 1989, Yankee Energy became guarantor of a term loan agreement
between the Trustee for the Company's 401(k) Employee Stock Ownership Plan
(ESOP), and a commercial bank, in the amount of $4,000,000. The proceeds were
used by the Trustee exclusively to acquire outstanding shares of Yankee Energy
common stock pursuant to the terms of the Company's ESOP. The final maturity
date of the agreement was July 1, 1999.
(c) Long-term debt maturities and cash sinking fund requirements on debt
outstanding at September 30, 1999 for each of the fiscal years 2000 through 2004
(excluding early redemption options the Company may utilize) are $1,200,000;
$1,200,000; $1,200,000; $5,450,000; and $950,000, respectively.
The accompanying notes are an integral part of these consolidated financial
statements.
F-7
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY
(In thousands) Employee
Stock
Capital Ownership
Common Surplus, Retained Plan
Shares Paid In Earnings (a) Guarantee Total
- ----------------------------------------------------------------------------------------------------------------------------------
Balance at September 30, 1996 $52,248 $87,947 $23,271 ($1,400) $162,066
Net income 16,957 16,957
Issuance of 4,860 common shares - $5 par value 24 81 105
Cash dividends on common shares - $1.32 per share (13,797) (13,797)
Employee stock ownership plan loan repayment 400 400
Unearned compensation-restricted stock awards (b) (25) (25)
- ----------------------------------------------------------------------------------------------------------------------------------
Balance at September 30, 1997 $52,272 $88,003 $26,431 ($1,000) $165,706
Net income 10,883 10,883
Issuance of 90,948 common shares - $5 par value 455 1,777 2,232
Cash dividends on common shares - $1.36 per share (14,267) (14,267)
Employee stock ownership plan loan repayment 400 400
Unearned compensation-restricted stock awards (b) 38 38
- ----------------------------------------------------------------------------------------------------------------------------------
Balance at September 30, 1998 $52,727 $89,818 $23,047 ($600) $164,992
Net income 13,375 13,375
Issuance of 88,304 common shares - $5 par value 441 752 1,193
Cash dividends on common shares - $1.40 per share (14,858) (14,858)
Employee stock ownership plan loan repayment 600 600
Unearned compensation-restricted stock awards (b) 277 277
- ----------------------------------------------------------------------------------------------------------------------------------
Balance at September 30, 1999 $53,168 $90,847 $21,564 $0 $165,579
- ----------------------------------------------------------------------------------------------------------------------------------
(a) Yankee Gas has dividend restrictions imposed by its Bond Purchase
Agreements. At September 30, 1999, retained earnings available for common
dividends under the terms of the Series A agreement and Series B and C
agreements totaled approximately $40.5 million and $50.8 million, respectively.
(b) See note (a) of the Consolidated Statements of Capitalization.
The accompanying notes are an integral part of these consolidated financial
statements.
F-8
YANKEE ENERGY SYSTEM, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
The Company: Yankee Energy System, Inc. ("YES" or the "Company"),
headquartered in Meriden, Connecticut, is a diversified company
specializing in the distribution, conversion, and control of energy to
meet our customers' needs. Our principal operating subsidiary is
Yankee Gas Services Company ("Yankee Gas"). Yankee Gas, the largest
natural gas distribution company in Connecticut, provides service to
more than 185,000 customers in 69 cities and towns.
On June 14, 1999, the Company and Northeast Utilities ("NU") entered
into an Agreement and Plan of Merger ("Merger Agreement") providing
for a merger transaction ("Merger") between the Company and NU.
Pursuant to the Merger Agreement, the Company will merge with and into
Merger Sub, a Connecticut corporation to be formed by NU prior to the
closing of the Merger as a wholly owned subsidiary of NU. Merger Sub
will be the surviving entity, but will change its name to "Yankee
Energy System, Inc." As a result of the Merger, the Company will become
a wholly owned subsidiary of NU. Shareholders of Yankee Energy will
receive $45.00 a share, 45% payable in NU shares and 55% payable in
cash. The Merger will be accounted for using the purchase method of
accounting. On October 12, 1999, the shareholders of the Company
approved the Merger. The Merger is conditioned on, among other things,
the approval of the various regulatory agencies, including the
Connecticut Department of Public Utility Control ("DPUC") and the
Securities and Exchange Commission. The Company expects the Merger to
close in the first half of fiscal 2000.
The Company's other operating subsidiaries support the core business in
natural gas distribution, or allow the Company to expand its growing
business in energy-related services. Yankee Energy Services Company
("YESCo") provides a wide range of energy-related services for its
customers. YESCo Controls division provides comprehensive building
automation with engineering, installation and maintenance of building
control systems. YESCo Mechanical Services division provides
comprehensive heating, ventilation and air-conditioning ("HVAC"),
boiler and refrigeration equipment services and installation. In
addition to Yankee Gas and YESCo, two other subsidiaries are taking
advantage of opportunities by offering services once exclusively
provided to local energy customers to a broader marketplace. R.M.
Services, Inc. ("RMS"), through its alliance with Dun & Bradstreet
Management Receivables Services, provides consumer collection services
for companies throughout the United States, and Yankee Energy Financial
Services Company ("Yankee Financial") provides a full range of
equipment and home improvement financing options through programs like
the Hometown Energy Loan Program. NorConn Properties, Inc. ("NorConn")
owns selected system real estate, which it leases to Yankee Gas.
Additional company information can be found at the Company web site,
www.yankeeenergy.com.
Principles of Consolidation: The consolidated financial statements of
the Company include the accounts of all subsidiaries. Intercompany
transactions have been eliminated in consolidation.
Public Utility Regulation: Yankee Gas is subject to regulation for
rates and other matters by the DPUC and follows accounting policies
prescribed by the DPUC. The Company prepares its financial statements
in accordance with generally accepted accounting principles, which
include the provisions of Statement of Financial Accounting Standards
No. 71, "Accounting for the Effects of Certain Types of Regulation,"
("FAS 71"). FAS 71 requires a cost-based, rate-regulated enterprise
such as Yankee Gas to reflect the impact of regulatory decisions in
its financial statements. The DPUC, through the rate regulation
process, can create regulatory assets that result when costs are
allowed for rate making purposes in a period other than the period in
which the costs would be charged to expense by an unregulated
enterprise.
Following the provisions of FAS 71, Yankee Gas has recorded regulatory
assets or liabilities as appropriate primarily related to deferred gas
costs, pipeline transition costs, hardship customer receivables,
F-9
environmental cleanup costs, income taxes and postretirement benefit
costs. The specific amounts related to these items are disclosed in the
consolidated balance sheets. Yankee Gas continues to be subject to
cost-of-service-based rate regulation by the DPUC. Based upon current
regulation and recent regulatory decisions, the Company believes that
its use of regulatory accounting in accordance with the provisions of
FAS 71 is appropriate.
Revenues: Utility revenues are based on authorized rates applied to
each customer's use of gas. Rates can be changed only through a formal
proceeding before the DPUC. At the end of each accounting period, a
revenue estimate for the amount of gas delivered but unbilled is
recorded.
Merger Costs: The Company has recorded approximately $2.0 million of
costs for legal, consulting and financial advisory services related to
the Merger. These costs have been expensed as incurred.
Depreciation: The provision for utility depreciation is calculated
using the straight-line method based on estimated remaining useful
lives of depreciable utility plant in service, adjusted for net salvage
value and removal costs as approved by the DPUC. The depreciation rates
for the several classes of plant in service are equivalent to an
overall composite rate of 3.3 percent in fiscal years 1999, 1998 and
1997.
Purchased Gas Adjustment Clause ("PGA"): The DPUC-approved rates
include an adjustment clause under which gas costs above or below base
rate levels are charged or credited to customers. As prescribed by the
DPUC, differences between the actual purchased gas costs and the
current cost recovery are deferred and recovered or refunded over
future periods.
Equity Accounting: The Company accounts for YESCo's investments in
energy production facilities using the equity method, recording their
proportionate share of earnings (losses) with corresponding increases
(decreases) in their investment. Distributions received reduce the
carrying amount of these investments.
Income Taxes: Differences exist between the periods in which
transactions affect income in the financial statements and the periods
in which they affect the determination of income subject to tax. The
tax effect of such timing differences is accounted for in accordance
with the ratemaking treatment required by the DPUC. As of September 30,
1999, the Company has a deferred tax liability and a corresponding
regulatory asset of approximately $4 million. These deferred amounts
represent book/tax differences for which the tax impacts were not
recognized in the financial statements (or included in the rates) at
the time the differences occurred (flow-through accounting), but for
which the additional taxes due at the time the differences reverse will
be recoverable from ratepayers.
Cash and Temporary Cash Investments: Cash and temporary cash
investments includes cash on hand and short-term investments which are
highly liquid in nature and have original maturities of three months or
less.
Reclassifications: Certain prior year amounts have been reclassified to
conform with current year classifications.
Use of Estimates: 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.
F-10
Earnings per Share: The Company is required to compute and present
basic and diluted earnings per share. The basic weighted average shares
outstanding for fiscal 1999, 1998 and 1997 were 10,609,293, 10,495,806
and 10,451,165, respectively, and the diluted weighted average shares
outstanding for fiscal 1999, 1998 and 1997 were 10,623,017, 10,499,810
and 10,453,318, respectively. As such, there is no measurable
difference between basic and diluted earnings per share.
Recent Accounting Pronouncements: In June 1998, the Financial
Accounting Standards Board issued Statement of Financial Accounting
Standards No. 133, "Accounting for Derivative Instruments and Hedging
Activities," which requires the Company to recognize all derivatives as
either assets or liabilities in the consolidated balance sheets and
measure those instruments at fair value. Management is currently
evaluating the impact of this standard and believes the adoption will
not materially impact the Company's consolidated financial position,
results of operations or cash flows. This statement is effective for
the Company in the first quarter of fiscal year 2001.
NOTE 2) INCOME TAX EXPENSE
The components of the federal and state income tax provisions are:
YEARS ENDED SEPTEMBER 30, 1999 1998 1997
------------------------- ---- ---- ----
(In thousands)
Charged to income:
Current income taxes:
Federal $9,631 $2,252 $4,509
State 2,726 624 1,979
------ ------ ------
Total current 12,357 2,876 6,488
------ ------ ------
Deferred income taxes, net:
Investment tax credit (377) (377) (377)
Federal (55) 5,528 6,004
State (601) 293 1,308
------- ------ -------
Total deferred (1,033) 5,444 6,935
------- ------ -------
Total income tax expense $11,324 $8.320 $13,423
======= ====== =======
Deferred income tax liabilities (assets) are comprised of the following:
AT SEPTEMBER 30, 1999 1998
---------------- ---- ----
(In thousands)
Depreciation $71,854 $75,238
Other (6,011) (2,422)
------- -------
Net deferred income tax liability $65,843 $72,816
======= =======
F-11
The differences between the effective income tax rate recorded by the
Company and the statutory federal tax rate are reconciled as follows:
1999 1998 1997
---- ----- ----
Federal statutory rate 35.0% 35.0% 35.0%
Tax effect of differences:
Depreciation 6.1 9.3 5.1
State income taxes net of federal benefit 5.6 3.1 6.9
Merger expenses 2.5 - -
Pension accrual (1.4) (4.0) (0.1)
Miscellaneous (1.9) (0.1) (2.7)
------ ----- -----
Effective income tax rate 45.9% 43.3% 44.2%
===== ===== =====
NOTE 3) LEASES
The Company has entered into operating lease agreements for the use of
office equipment, vehicles and buildings. For fiscal 1999, 1998 and
1997, these lease payments were $2,274,000, $1,999,000 and $2,064,000,
respectively. Future minimum lease payments, excluding associated
costs such as property taxes, state use taxes, insurance and
maintenance, under long-term noncancelable leases as of September 30,
1999, are approximately:
Year (In Thousands)
---- --------------
2000 $1,851
2001 1,568
2002 1,239
2003 655
2004 497
After 2005 333
Future minimum lease payments $6,143
NOTE 4) POSTRETIREMENT BENEFITS
The Company has a noncontributory defined benefit retirement plan,
covering employees of Yankee Gas and RMS. Benefits are based on years
of service and employees' highest consecutive 60 months of compensation
during the last 120 months of employment. It is the Company's policy to
fund annually an amount at least equal to that which will satisfy the
requirements of the Employee Retirement Income Security Act and the
Internal Revenue Code. No contributions were required or made in fiscal
1999, 1998 and 1997. Pension assets are invested primarily in equity
securities and investment grade bonds.
In fiscal 1999, the Company adopted Statement of Financial Accounting
Standards No. 132 "Employers' Disclosures about Pensions and Other
Postretirement Benefits", which standardizes the disclosure
requirements for pension and other postretirement benefits, eliminates
certain disclosure, and requires additional information on the changes
in the benefit obligations and fair value of plan assets.
F-12
The components of net pension cost (income) were:
YEARS ENDED SEPTEMBER 30, 1999 1998
------------------------- ---- ----
(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of year $73,352 $64,845
Service cost 2,425 2,099
Interest cost 5,022 4,814
Amendments - 717
Actuarial loss (gain) (9,244) 3,961
Benefits paid (3,261) (3,084)
------- -------
Benefit obligation at end of year $68,294 $73,352
======= =======
Change in plan assets:
Fair value of plan assets at beginning of year $88,837 $89,966
Actual return on plan assets 15,339 1,955
Benefits paid (3,261) (3,084)
Fair value of plan assets at end of year $100,915 $88,837
======== =======
Funded status $32,621 $15,485
Unrecognized transition asset (531) (617)
Unrecognized prior service cost 625 665
Unrecognized net actuarial loss (32,888) (16,629)
-------- --------
Accrued pension cost (income) $(173) $(1,096)
======== ========
YEARS ENDED SEPTEMBER 30, 1999 1998 1997
------------------------- ----- ---- ----
(In thousands)
Net pension cost includes the following components:
Service cost $2,425 $2,099 $1,992
Interest cost 5,022 4,814 4,522
Expected return on plan assets (7,851) (7,958) (6,413)
Amortization of transition asset (86) (86) (86)
Amortization of prior service cost 40 26 (3)
Recognized net actuarial gain (473) (1,135) (517)
------ ------ ------
Net periodic pension cost (income) $ (923) $(2,240) $(505)
======= ======== =======
Weighted-average assumptions:
Discount rate 7.50% 7.00% 7.50%
Expected long-term rate of return 9.00% 9.00% 9.00%
Compensation/progression rate 4.00% 4.00% 4.50%
Pension cost for 1999, 1998, and 1997 includes $85,000 in cost of
living increases each year for NU retirees who were previously employed
in the gas business operated by The Connecticut Light and Power
Company, a subsidiary of NU. These payments were agreed to at the time
of divestiture from NU.
During fiscal 1994, the Company adopted an Excess Benefit Plan ("EBP")
that provides retirement benefits to executive officers and other key
management staff. The EBP recognizes total compensation and service
that would otherwise be disregarded due to Internal Revenue Code
limitations on compensation in determining benefits under the regular
retirement plan. The EBP is not funded and benefits are paid from
general corporate assets when due.
F-13
NOTE 5) POSTRETIREMENT BENEFITS OTHER THAN PENSIONS
The Company provides certain health care and life insurance benefits to
its retired Yankee Gas and RMS employees. The Company recognizes the
cost of postretirement benefits over the employment period that
encompasses eligibility to receive such benefits. On July 1, 1990, in
accordance with terms of the divestiture, Yankee Gas began compensating
NU for a portion of NU's liability for certain health care and life
insurance expenses of retirees or surviving spouses. Yankee Gas and NU
will share costs in a defined manner until June 30, 2005. The cost of
providing those benefits for NU retirees was approximately $1,283,000
for the fiscal year ended September 30, 1999 and $1,032,000 and
$1,103,000 for the comparable periods in 1998 and 1997, respectively.
The Company has established two Internal Revenue Code Section 501(c)(9)
Voluntary Employee Beneficiary Association ("VEBA") Trusts, one for
union employees and one for non-union employees, to fund its future
liabilities for retiree health care and life insurance benefits.
Contributions to the VEBA Trusts totaled $1.3 million for fiscal 1999
and $1.1 million for fiscal 1998. Assets of the VEBA Trusts are
invested primarily in equity securities and investment grade bonds.
For Yankee Gas, the DPUC is allowing $1.7 million of associated
expenses to be recovered in rates and up to an additional $1.5 million
annually, which is being collected through a rate settlement process,
which is more fully described in Note 9, Commitments and Contingencies
(Transition Costs-Order No. 636).
The components of net pension cost (income) were:
YEARS ENDED SEPTEMBER 30, 1999 1998
------------------------- ----- ----
(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of year $27,465 $21,803
Service cost 1,253 922
Interest cost 1,892 1,597
Employee contribution 59 57
Actuarial loss (gain) (3,227) 4,181
Benefits paid (967) (1,095)
----- -------
Benefit obligation at end of year $26,475 $27,465
======= =======
Change in plan assets:
Fair value of plan assets at beginning of year $11,893 $10,790
Actual return on plan assets 1,851 1,309
Employer contribution 1,292 832
Employee contribution 59 57
Benefits paid (967) (1,095)
---- ------
Fair value of plan assets at end of year $14,128 $11,893
======= =======
Funded status $(12,347) $(15,572)
Unrecognized transition obligation 11,856 12,731
Unrecognized net actuarial loss (6,527) (2,529)
------- -------
Accrued benefit cost $(7,018) $(5,370)
======= =======
F-14
YEARS ENDED SEPTEMBER 30, 1999 1998 1997
------------------------- ----- ---- ----
(In thousands)
Net pension cost includes the following components:
Service cost $1,253 $922 $913
Interest cost 1,892 1,597 1,685
Expected return on plan assets (1,080) (1,076) (713)
Amortization of transition obligation 875 876 875
Recognized net actuarial gain - (253) (88)
Other adjustments or deferrals - - 210
------ ------- -------
Net periodic pension cost $2,940 $ 2,066 $ 2,882
====== ======= =======
Weighted-average assumptions:
Discount rate 7.50% 7.00% 7.50%
Expected return of plan assets 9.00% 9.00% 9.00%
Rate of compensation increase 4.00% 4.00% 4.50%
Health care cost trend rate
- First year 6.00% 7.00% 8.00%
- Ultimate 5.00% 5.00% 5.00%
Trend rates are assumed to decrease one percent per year until they
reach the ultimate rate. A one percent increase in the weighted average
trend rate assumption of health care claims would result in a 12
percent increase in accumulated benefit obligations and a 16 percent
increase in net periodic postretirement benefit costs.
NOTE 6) STOCK-BASED COMPENSATION
Yankee Energy established Long-Term Incentive Compensation Plans in
1991 and 1996. Options on 73,400 and 20,500 shares of common stock were
granted under the 1996 plan, in fiscal 1998 and 1999, respectively.
Under the terms of the options granted, the exercise price of any
option may not be less than 100 percent of the fair market value of the
common stock on the date of the grant. The stock options generally vest
over a five year period, with 20 percent becoming exercisable on each
of the first five anniversaries of the grant. All stock options expire
ten years from the date of grant. Options granted to a senior executive
were accelerated and deemed fully vested as of September 30, 1998, as
part of a severance agreement (see Note 9 Commitments and
Contingencies). The Company recorded expenses in fiscal 1998 of
approximately $101,000 due to the change in the measurement date.
The Company accounts for stock options in accordance with Accounting
Principles Board Opinion No. 25, under which no compensation costs have
been recognized for stock option awards. Had compensation costs of
option awards been determined under a fair value alternative method as
stated in Statement of Financial Accounting Standards No. 123,
"Accounting for Stock-Based Compensation," the Company would have been
required to value such options and record such amounts in the financial
statements as compensation expense. Pro forma net income and net income
per share for fiscal 1999, 1998 and 1997 would have been $13,297,000
and $1.25, $10,832,000 and $1.03, and $16,919,000 and $1.62,
respectively. For purposes of this calculation, the Company arrived at
the fair value of each stock grant at the date of grant by using the
Black Scholes option pricing model with the following weighted average
assumptions used for grants for the fiscal years ended September 30,
1999 and 1998: risk-free interest rate of 5.5 and 5.7 percent,
respectively, expected life of 5.0 years, expected volatility of 30 and
17 percent, respectively, and a dividend yield of 3.3 and 5.3 percent,
respectively. No stock options were granted for the fiscal year ended
September 30, 1997.
F-15
The following summarizes stock option transactions for the fiscal years
ended September 30, 1999, 1998 and 1997:
-------------------------------------------------------------------------------------------------------
Weighted Number
Option Prices Average Price of Shares
-------------------------------------------------------------------------------------------------------
Outstanding Options September 30, 1996 $21.38-$23.69 $22.73 115,000
Exercised $21.63-$23.69 $21.73 (4,860)
Canceled $21.63-$23.69 $22.97 (8,980)
-------
Outstanding Options September 30, 1997 $21.38-$23.69 $22.75 101,160
Granted $23.13-$26.19 $24.63 73,400
Exercised $21.63-$23.69 $21.93 (8,240)
Canceled $21.63-$23.72 $23.01 (45,260)
-------
Outstanding Options September 30, 1998 $21.63-$26.19 $23.85 121,060
Granted $29.31 $29.31 20,500
Exercised $21.63-$26.19 $24.25 (60,860)
Canceled $21.63-$23.72 $23.57 (7,800)
-------
Outstanding Options September 30, 1999 $21.63-$29.31 $25.08 72,900
=======
At September 30, 1999, 1998, and 1997, there were 42,612 options,
63,388 options, and 38,136 options exercisable, respectively, which
have weighted average exercise prices of $26.16 per share, $24.24 per
share, and $22.20 per share, respectively.
NOTE 7) SHORT-TERM DEBT
Yankee Gas has arranged a $60 million revolving line of credit with a
group of three banks whereby funds may be borrowed on a short-term
revolving basis using either fixed or variable rate loans. Yankee Gas
had $34.5 million and $63.2 million outstanding under its agreements at
September 30, 1999 and 1998, respectively. In addition, Yankee Energy
had $21.5 and $12.5 million outstanding at September 30, 1999 and 1998,
respectively, on a $15 million line of credit and a $10 million
uncommited line of credit. The weighted average interest rates on
short-term debt at September 30, 1999 and 1998 were 5.5 percent and 5.8
percent, respectively.
NOTE 8) FAIR VALUE OF FINANCIAL INSTRUMENTS
The carrying amount of cash and temporary cash investments approximates
fair value. The fair values of the Company's first mortgage bonds,
which are fixed rate long-term debt, are based upon borrowing rates
currently available to the Company. Adjustable rate securities are
assumed to have a fair value equal to their carrying value. The
carrying amount of the first mortgage bonds (including current
maturities) was $159,000,000 and $129,165,000 as of September 30, 1999
and 1998, respectively. The fair value was $152,577,000 and
$144,100,000 as of September 30, 1999 and 1998, respectively. These
fair values have been reported to meet the disclosure requirements of
Statement of Financial Accounting Standards No. 107, "Disclosures About
Fair Values of Financial Instruments," and do not purport to represent
the amounts at which those obligations would be settled.
F-16
NOTE 9) COMMITMENTS AND CONTINGENCIES
Construction Program: The Company's estimated capital expenditures for
fiscal 2000 are $30.8 million. The Company intends to use $29.0 million
of these estimated expenditures to maintain the reliability of the
distribution system and in projects that will generate or support gas
sales and transportation activities.
Environmental Matters: Fourteen sites containing coal tar became the
property of Yankee Gas at divestiture from NU in 1989. Contamination at
these sites was caused by operations of former manufactured gas plants
at those locations. Yankee Gas has reported the results of its
environmental studies to the Connecticut Department of Environmental
Protection ("DEP"). The DEP has not required that any remedial action
be undertaken to date. However, eight of the fourteen sites are
presently listed on the Connecticut Inventory of Hazardous Waste Sites.
Inclusion of a site on this list indicates that remediation may be
required in the future.
Remediation has been conducted at three of these properties. In
addition, Yankee Gas has developed a cost estimate for the remaining
sites based on various factors including the probability of clean-up.
As a result of this effort, Yankee Gas recorded a liability of $35
million in fiscal 1993 for future environmental clean-up with a
corresponding regulatory asset. Recovery of remediation costs has been
specifically allowed by Yankee Gas' 1992 rate case decision. Presently,
$325,000 is allowed annually in rates. If costs are expected to exceed
$2.5 million on an annual basis, Yankee Gas is required to review such
expenditures with the DPUC. The DPUC has stated that "to the extent
that coal tar remediation expenses are prudently incurred, they should
be allowed as proper operating expenses," and therefore, management
continues to believe a regulatory asset is appropriate for this item.
Yankee Gas has received $9.6 million from certain of its insurance
carriers in settlement of certain claims for actual or potential
contamination at certain sites that may give rise to environmental
liabilities. The terms of the aforementioned settlements are subject to
confidentiality provisions in agreements between Yankee Gas and its
insurance carriers. The proceeds are being reflected as reductions in
the regulatory asset associated with recoverable environmental clean-up
costs, as shown in the accompanying balance sheets.
Transition Costs-Order No. 636: On April 8, 1992, the Federal Energy
Regulatory Commission ("FERC") issued Order No. 636 on pipeline
restructuring. In essence, the FERC found that absent the unbundling
of traditional merchant services, pipelines would not be able to
achieve the FERC's long-term goal of open access and provide
transportation services that are indifferent to the seller of the gas.
Order No. 636 acknowledges that the restructuring of the pipelines'
traditional services will cause pipelines to incur transition costs in
several areas and provides mechanisms for the pipelines to fully
recover prudently incurred transition costs attributable to the
implementation of Order No. 636.
On July 8, 1994, the DPUC issued a decision on the implementation of
FERC Order No. 636 by the Connecticut Local Distribution Companies
("LDCs"). The DPUC is allowing the LDCs to offset the transition costs
billed by pipelines under Order No. 636 with recoveries from capacity
release activity, refunds of deferred gas costs, gas supplier refunds,
off-system sales margin and interruptible margin earned in excess of
target amounts. Through September 30, 1999, Yankee Gas paid
approximately $21.5 million of transition costs and an additional $1.5
million is anticipated. To date, Yankee Gas has collected $53.6 million
through a combination of credits received from gas supplier refunds,
deferred gas costs, excess interruptible margin, off-system sales
margin, and capacity release agreements.
F-17
On January 3, 1996, the DPUC issued a Final Decision in reopened Docket
No. 92-02-19. The Docket allows for recovery of certain deferred
regulatory assets with the stipulation that Yankee Gas would not
increase its rates before October 1, 1998, except in the event of
certain circumstances which would adversely affect Yankee Gas'
financial condition. Yankee Gas may apply a portion of excess
transition credits received from pipeline refunds, interruptible excess
margin, deferred gas costs, capacity release activity, and off-system
sales margin to certain regulatory assets. As of September 30, 1999,
excess collections of approximately $32.1 million were applied against
the deferred regulatory assets specified in the decision.
Rate Review: On July 9, 1997, the DPUC issued its decision in Docket
No. 96-08-05. The DPUC decision, which is not a rate order, called for
a lowering of Yankee Gas' authorized Return on Equity ("ROE") from
12.43 percent to 11.15 percent. The DPUC believed that lower current
interest rates and recently allowed rates of return for other
Connecticut utilities justified a lower ROE for Yankee Gas. On October
1, 1997, the DPUC approved a settlement whereby Yankee Gas would credit
approximately $3.2 million to firm sales customers through the PGA
during fiscal year 1998. The settlement also allowed Yankee Gas to
maintain its base rates until the end of fiscal year 2000, resulting in
an eight-year period in which Yankee Gas will have gone without an
increase in its base rates.
Legal Issues: In fiscal 1996, Yankee Gas received revised property tax
bills from the City of Meriden, Connecticut ("City") for tax years
1991 through 1994. The City is asserting a claim for approximately $5.0
million for back taxes and interest resulting from the reassessment and
revaluation of Yankee Gas' personal property filings. The City did not
locate or identify any property which Yankee Gas omitted from its
filings. The tax bills reflect a reassessment of property using a
different methodology than that previously accepted by the City.
Subsequent to the filing of the lawsuit against the City, Yankee Gas
appealed the succeeding reassessment and currently is in the process of
also litigating the revaluation of the subject personal property for
the tax years 1995 through 1998. Although it is anticipated that the
outcome of this claim will not have a material impact on the Company's
financial statements, based on the information available at this time,
management cannot predict what the ultimate impact might be.
In November 1995, a purported class action suit was filed against
Yankee Gas and the state's two other LDCs by the Connecticut Heating
and Cooling Contractors' Association, Inc. et al. On December 21,
1999, the action was settled with the plaintiffs and is awaiting the
court's confirmation. The settlement does not have a material adverse
effect on the Company's consolidated results of operations or financial
position.
The Company is not a party to any other litigation other than ordinary
routine litigation incident to the operations of the Company or its
subsidiaries. In the opinion of management, the resolution of such
litigation will not have a material adverse effect on the Company's
financial condition or results of operations.
Tax Audits: The Company is currently under audit by the State of
Connecticut regarding the Company's Sales and Use Tax returns for the
calendar years 1996, 1997 and 1998, by the City of Naugatuck,
Connecticut regarding the Company's Personal Property Tax Schedules for
the years 1995, 1996 and 1997, and by the Internal Revenue Service
("IRS") regarding the Company's Federal Income Tax returns for the
calendar years 1995 and 1996. The Company is responding to all
information document requests put forth by the auditors. At this time,
except for the audit of the 1995 Federal Income Tax Return, the Company
does not have sufficient information to determine the amount, if any,
of additional liability that may result from these proceedings. The
Company is expecting a formal proposal from the IRS regarding
adjustments to the 1995 Federal Income Tax Return. The Company does not
anticipate that any of these audits, including the audit of the 1995
Federal Income Tax Return, will have a material effect on its
consolidated results of operations or financial position.
F-18
Nonrecurring Charges: In connection with YESCo's HVAC restructuring
and impairments of certain Power division assets, the Company recorded
a pre-tax charge of approximately $3.5 million in the fourth quarter of
fiscal 1998. Of the total charge, $1.6 million represents impairment of
HVAC and Power divisions' long-lived assets such as property and
goodwill and $1.9 million pertains to YESCo restructuring charges such
as lease costs, severance and other exit costs. In addition, in the
fourth quarter of fiscal 1998, the Company recorded a pre-tax charge
for severance of approximately $0.9 million, due to the resignation of
two senior executives. As of September 30, 1999, all amounts accrued
have been paid and no additional charges were required.
The Company is currently negotiating the sale of its more significant
Power Division investments with several interested parties. These
investments include an operating land fill gas fueled generating
facility in Brookhaven, NY, interests in two operating cogeneration
facilities, development stage projects and other less significant
assets. The total investment at September 30, 1999 is approximately
$15.4 million and is reflected as assets held for sale in the
consolidated balance sheets. Management expects that the sale of
the Power Division assets will have no material effect on the Company's
consolidated results of operations or financial position.
NOTE 10) RISK MANAGEMENT ACTIVITIES
Gas Supply Hedging Activities: Yankee Gas has gas service agreements
with two customers to supply gas at fixed prices. Because Yankee Gas
purchases gas on a variable price basis, it has hedged gas prices with
derivatives to respond to customers' needs for fixed pricing. Both
agreements are similar in structure in that Yankee Gas executed a
commodity swap contract with a commodity trading firm. Under a master
commodity swap agreement, the price of a specified quantity of gas is
fixed over the term of the gas service agreement with the customer. In
both cases, Yankee Gas is acting as an agent, using its credit to
provide fixed pricing to its customers, using a commodity swap. Yankee
Gas' results of operations are unaffected by the hedge transaction
given that it passes through the cost of the hedge to either the
commodity trading firm or its customer depending on the difference in
the fixed and floating prices for gas. Also, the customers are
accountable for all costs incurred by Yankee Gas to execute and
maintain the commodity swap contract.
Of the two gas service hedging agreements currently in force, only one
is material relative to the significance of gas volumes being hedged.
This agreement has a ten-year term and requires Yankee Gas to supply
approximately one BCF of gas per year, with relatively low margin, at a
fixed price that began August 1, 1995. The price is allowed to escalate
by a predetermined rate every year after the first year. The commodity
swap contract for this hedging agreement was executed August 17, 1994.
Yankee Gas is responsible for margin calls collateralizing the
commodity swap contract from August 17, 1994 through the term of the
gas service agreement. Currently, Yankee Gas has a letter of credit in
the amount of $1.75 million issued to the commodity trading firm
collateralizing the commodity contract.
Interest Rate Swap: The Company uses swap instruments with financial
institutions to exchange fixed rate interest obligations to a blend
between fixed and variable rate obligations without exchanging the
underlying notional amounts. These instruments convert high fixed
interest rate obligations to variable rates. The notional amounts
parallel the underlying debt levels and are used to measure interest to
be paid or received and do not represent the exposure to credit loss.
As of September 30, 1999, Yankee Energy had outstanding agreements with
a total notional value of $49 million and a positive mark-to-market
position of approximately $63,000. The difference between the amounts
paid and received under the swaps is accrued and recorded as an
adjustment to interest expense over the life of the swap instruments.
NOTE 11) REPORTABLE SEGMENTS
Yankee Energy operates principally in two segments: utility and
nonutility. The utility segment is a regulated natural gas distribution
company. The nonutility segement is composed of energy-related
services, consumer collection services and financial services. The
accounting policies of each reportable segment are the same as those
described in the summary of significant accounting policies. The
Company accounts for intercompany sales in accordance with existing
F-19
tariffs and contracts. Yankee Energy evaluates performance based on
profitability and growth potential of each segment. Financial data for
reportable segments is as follows:
(In thousands) Depreciation & Interest Income Net
Revenues Amortization Expense Taxes Income
Year ended September 30, 1999
Utility $275,619 $19,646 $13,526 $12,923 $15,907
Nonutility 31,084 1,914 1,310 (963) 139
Parent/Eliminations (3,221) - (232) (636) (2,671)A
----------- ---------- ---------- ----------- ---------
Total $303,482 $21,560 $14,604 $11,324 $13,375
=========== ========== ========== =========== =========
Year ended September 30, 1998
Utility $283,839 $18,213 $12,909 $12,868 $16,978
Nonutility 33,759 1,576 1,456 (4,124) (5,389)B
Parent/Eliminations (2,831) - (512) (424) (706)C
----------- ---------- ---------- ----------- ---------
Total $314,767 $19,789 $13,853 $8,320 $10,883
=========== ========== ========== =========== =========
Year ended September 30, 1997
Utility $318,993 $16,868 $12,335 $14,999 $19,739
Nonutility 8,631 1,260 913 (1,576) (2,934)
Parent/Eliminations (2,583) 2 (785) - 152
----------- ---------- ----------- ----------- ---------
Total $325,041 $18,130 $12,463 $13,423 $16,957
=========== ========== ========== =========== =========
A - Parent loss includes non-tax deductible merger expenses of $1.9
million.
B - Nonutility loss includes nonrecurring restructuring charges and
asset impairment associated with YESCo. After-tax, these amounts were
approximately $2.7 million.
C - Parent loss includes an after-tax charge for severance, due to the
resignation of two senior executives of approximately $0.5 million.
At September 30, (In thousands) 1999 1998
Total Plant and Other Investments
Utility $ 381,343 $ 368,227
Nonutility 15,298 12,484
--------- ---------
Total Plant and Other Investments $ 396,641 $ 380,711
Other Assets
Utility $ 121,189 $ 132,357
Nonutility 49,360 39,647
Less intercompany receivables (26,904) (17,431)
--------- ---------
Total Other Assets $ 143,645 $ 154,573
--------- ---------
Total Assets $ 540,286 $ 535,284
========= =========
F-20
NOTE 12) QUARTERLY FINANCIAL DATA (UNAUDITED)
The following table provides information with respect to the
consolidated quarterly results of operations for the fiscal years ended
September 30, 1999 and 1998, and reflects the seasonal nature of the
Company's operations. The results of any one quarter during the year
are not indicative of the results of future quarters.
(In thousands, except per share amounts)
------------------------------------------------------------------------------------------
Fiscal Year 1999 December 31 March 31 June 30 September 30
------------------------------------------------------------------------------------------
Operating revenues $ 85,001 $117,444 $ 56,221 $ 44,816
Operating income (loss) 16,066 27,035 1,112 (5,153)
Net income (loss) 7,846 11,450 (2,108) (3,813)
Basic and diluted earnings (loss) per
common share (1) $ 0.74 $ 1.08 $ (0.20) $ (0.36)
------------------------------------------------------------------------------------------
Quarter Ended
Fiscal Year 1998 December 31 March 31 June 30 September 30
------------------------------------------------------------------------------------------
Operating revenues $102,595 $113,193 $ 54,327 $ 44,652
Operating income (loss) 20,334 23,828 402 (11,682)
Net income (loss) 9,091 10,810 (1,902) (7,116)
Basic and diluted earnings (loss) per
common share (1) $ 0.87 $ 1.03 $ (0.18) $ (0.68)
(1) Basic and diluted earnings (loss) per common share were
calculated on the basic weighted average common shares
outstanding of 10,609,293 and 10,495,806 and the diluted
weighted average common shares outstanding of 10,623,017 and
10,499,810 for the twelve months ended September 30, 1999 and
1998, respectively.
F-21
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized.
YANKEE ENERGY SYSTEM, INC.
--------------------------
(Registrant)
Date: December 7, 1999 By /S/ CHARLES E. GOOLEY
-----------------------------
Charles E. Gooley
President, Chief Executive Officer and a Director
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
DATE TITLE SIGNATURE
- ---- ----- ---------
December 7, 1999 President, Chief Executive /S/ CHARLES E. GOOLEY
Officer and a Director ----------------------
Charles E. Gooley
December 7, 1999 Vice President and Chief /S/JAMES M. SEPANSKI
Financial Officer ----------------------
James M. Sepanski
December 7, 1999 Controller /S/NICHOLAS A. RINALDI
----------------------
Nicholas A. Rinaldi
December 7, 1999 Chairman of the Board /S/EMERY G. OLCOTT
----------------------
Emery G. Olcott
December 7, 1999 Director /S/SANFORD CLOUD, JR.
----------------------
Sanford Cloud, Jr.
December 7, 1999 Director /S/EILEEN S. KRAUS
----------------------
Eileen S. Kraus
December 7, 1999 Director /S/JOHN J. RANDO
----------------------
John J. Rando
December 7, 1999 Director /S/PATRICIA M. WORTHY
----------------------
Patricia M. Worthy
ARTHUR ANDERSEN LLP
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors and Shareholders of
Yankee Energy System, Inc.:
We have audited, in accordance with generally accepted auditing standards,
the financial statements included in this Form 10-K, and have issued our
report thereon dated November 15, 1999. Our audit was made for the purpose of
forming an opinion on those statements taken as a whole. The schedule listed
in the index of financial statements is presented for purposes of complying
with the Securities and Exchange Commission's rules and is not part of the
basic financial statements. The schedule has been subjected to the auditing
procedures applied in the audit of the basic financial statements and, in our
opinion, fairly states in all material respects the financial data required
to be set forth therein in relation to the basic financial statements taken
as a whole.
Arthur Andersen LLP
Hartford, Connecticut
November 15, 1999
S-1
YANKEE ENERGY SYSTEM, INC. AND SUBSIDIARIES
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
YEAR ENDED SEPTEMBER 30, 1999
SCHEDULE II
(Thousands of Dollars)
- --------------------------------------------------------------------------------------------------------------------
Column A Column B Column C Column D Column E
Additions
------------------------
(1) (2)
Balance at Charged to Charged to
beginning costs and other accounts- Deductions- Balance at
Description of period expenses describe describe end of period
- ----------- --------- ---------- -------------- ---------- -------------
RESERVES DEDUCTED FROM ASSETS
TO WHICH THEY APPLY:
Reserves for uncollectible
accounts $ 8,132 $ 4,262 $ 0 $ 6,415(a) $ 5,979
Other property and investment impairment: $ 2,037 $ 0 $ 0 $ 2,037 $ 0
------- ------- ------- ------- -------
TOTAL $10,169 $ 4,262 $ 0 $ 8,452 $ 5,979
======= ======= ======= ======= =======
RESERVES NOT APPLIED AGAINST ASSETS:
Injuries and
damages(b) $ 587 $ 250 $ 0 $ 84(c) $ 753
Medical(d) $ 880 $ 3,106 $ 0 $ 1,376(e) $ 2,610
Restructuring $ 925 $ 0 $ 0 $ 925 $ 0
------- ------- ------- ------- -------
TOTAL $ 2,392 $ 3,356 $ 0 $ 2,385 $ 3,363
======= ======= ======= ======= =======
a) Amounts charged off as uncollectible after deducting customers' deposits and
recoveries of accounts previously charged off.
b) Provided to cover claims for injuries to employees, for workmen's
compensation, for bodily injury to others and property damage.
c) Principally payments for various injuries and damages and expenses in
connection therewith.
d) Provided to cover employee medical claims.
e) Principally payments for various employee medical expenses and expenses in
connection therewith.
S-2
YANKEE ENERGY SYSTEM, INC. AND SUBSIDIARIES
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
YEAR ENDED SEPTEMBER 30, 1998
SCHEDULE II
(Thousands of Dollars)
- --------------------------------------------------------------------------------------------------------------------
Column A Column B Column C Column D Column E
Additions
------------------------
(1) (2)
Balance at Charged to Charged to
beginning costs and other accounts- Deductions- Balance at
Description of period expenses describe describe end of period
- ----------- --------- ---------- -------------- ---------- -------------
RESERVES DEDUCTED FROM ASSETS
TO WHICH THEY APPLY:
Reserves for uncollectible
accounts $ 7,713 $ 6,477 $ 0 $ 6,058(a) $ 8,132
Other property and investment impairment: $ 0 $ 2,037 $ 0 $ 0 $ 2,037
------- ------- ------- -------- -------
TOTAL $ 7,713 $ 8,514 $ 0 $ 6,058 $10,169
======= ======= ======= ======= ========
RESERVES NOT APPLIED AGAINST ASSETS:
Injuries and
damages(b) $ 1,038 $ 300 $ 0 $ 751(c) $ 587
Medical(d) $ 1,042 $ 2,246 $ 0 $ 2,408(e) $ 880
Restructuring $ 0 $ 925 $ 0 $ 0 $ 925
------- ------- ------- -------- -------
TOTAL $ 2,080 $ 3,471 $ 0 $ 3,159 $ 2,392
======= ======= ======= ======= ========
a) Amounts charged off as uncollectible after deducting customers' deposits and
recoveries of accounts previously charged off.
b) Provided to cover claims for injuries to employees, for workmen's
compensation, for bodily injury to others and property damage.
c) Principally payments for various injuries and damages and expenses in
connection therewith.
d) Provided to cover employee medical claims.
e) Principally payments for various employee medical expenses and expenses in
connection therewith.
S-3
YANKEE ENERGY SYSTEM, INC. AND SUBSIDIARIES
VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
YEAR ENDED SEPTEMBER 30, 1997
SCHEDULE II
(Thousands of Dollars)
- --------------------------------------------------------------------------------------------------------------------
Column A Column B Column C Column D Column E
Additions
------------------------
(1) (2)
Balance at Charged to Charged to
beginning costs and other accounts- Deductions- Balance at
Description of period expenses describe describe end of period
- ----------- --------- ---------- -------------- ---------- -------------
RESERVES DEDUCTED FROM ASSETS
TO WHICH THEY APPLY:
Reserves for uncollectible
accounts $7,259 $4,673 $ 0 $4,219(a) $7,713
====== ====== ====== ====== ======
RESERVES NOT APPLIED AGAINST ASSETS:
Injuries and
damages (b) $1,510 $1,230 $ 0 $1,702(c) $1,038
Medical(d) $1,118 $2,385 $ 0 $2,461(e) $1,042
------ ------ ------ ------ ------
TOTAL $2,628 $3,615 $ 0 $4,163 $2,080
====== ====== ====== ====== ======
(a) Amounts charged off as uncollectible after deducting customers' deposits and
recoveries of accounts previously charged off.
(b) Provided to cover claims for injuries to employees for workmen's
compensation, for bodily injury to others and property damage.
(c) Principally payments for various injuries and damages and expenses in
connection therewith.
(d) Provided to cover employee medical claims.
(e) Principally payments for various employee medical expenses and expenses in
connection therewith.
S-4
INDEX TO EXHIBITS
EXHIBIT NUMBER DESCRIPTION OF EXHIBIT
(2)
2.1 Agreement and Plan of Merger, dated as of June 14, 1999
between the Company and Northeast Utilities (Incorporated by
reference to Form 8-K dated June 14, 1999, File No. 0-10721).
(3)
3.1 Restated Certificate of Incorporation of Yankee Energy System,
Inc. (the "Company") (Incorporated by reference to Form 10
Registration Statement dated April 14, 1989 and amendments
thereto, File No. 0-17605 ("Form 10")).
3.2 Amended Bylaws of the Company (Incorporated by reference to
Form 10).
(4)
4.1 Specimen of the Company's Common Stock (Incorporated by
reference to Form 10).
4.2 Rights Agreement between the Company and The Connecticut Bank
and Trust Company, N.A., as Rights Agent, dated November 20,
1989 (Incorporated by reference to Form 8-A Registration
Statement dated December 7, 1989, File No. 0-17605).
4.3 Amendment to Rights Agreement dated May 10, 1990 (Incorporated
by reference to Form 8 dated May 30, 1990, File No. 0-17605).
4.4 Amendment to Rights Agreement dated January 23, 1991
(Incorporated by reference to Form 8 dated January 31, 1991,
File No. 0-17605).
4.5 Term Loan Agreement between NorConn Properties, Inc. and Fleet
Bank dated as of January 31, 1996. (To be submitted to the
Commission upon request.)
4.6 Bond Purchase Agreement dated July 1, 1989 between Yankee Gas
and the Purchasers identified therein (Incorporated by
reference to Form 10).
4.7 Indenture of Mortgage and Deed of Trust dated July 1, 1989
between Yankee Gas and The Connecticut National Bank, as
Trustee (Incorporated by reference to Form 10).
4.8 Guaranty of the Company with Term Loan dated July 20, 1989
between United Bank & Trust Company, as Trustee of the Trust
of the 401(k) Employee Stock Ownership Plan and The National
Bank of Boston (Incorporated by reference to Form 10-K for the
fiscal year ended December 31, 1989, File No. 0-17605 ("1989
Form 10-K")).
4.9 First Supplemental Indenture of Mortgage and of Trust dated
April 1, 1992 between Yankee Gas and The Connecticut National
Bank, as (Incorporated by reference to Form 1992 ("Form
S-3")).
4.10 Second Supplemental Indenture of Mortgage and Deed of Trust
dated December 1, 1992 between Yankee Gas and The Connecticut
National Bank, as Trustee (Incorporated by reference to Form
10-K for the fiscal year ended September 30, 1992, File No.
0-17605 ("1992 Form 10-K")).
4.11 Bond Purchase Agreement dated April 1, 1992 between Yankee Gas
and the Purchasers identified therein (Incorporated by
reference to Form S-3).
4.12 Bond Purchase Agreement dated December 1, 1992 between Yankee
Gas and Purchaser identified therein (Incorporated by
reference to 1992 Form 10-K).
4.13 Third Supplemental Indenture of Mortgage and Deed of Trust
dated June 1, 1995 between Yankee Gas and Shawmut Bank
Connecticut, N.A., as Trustee. (Incorporated by reference to
Form 10-K for the fiscal year ended September 30, 1995, File
No. 0-10721 ("1995 Form 10-K")).
4.14 Bond Purchase Agreement dated June 22, 1995 between Yankee Gas
and Purchaser identified therein. (Incorporated by reference
to 1995 Form 10-K).
4.15 Fourth Supplemental Indenture of Mortgage and Deed of Trust
dated April 1, 1997 between Yankee Gas and Fleet National
Bank, as Trustee. (Incorporated by reference to Form 10-K for
the fiscal year ended September 30, 1997, File No. 0-10721
("1997 Form 10-K")).
4.16 Bond Purchase Agreement dated April 1, 1997 between Yankee Gas
and Purchaser. (Incorporated by reference to 1997 Form 10-K).
4.17 Bond Purchase Agreement dated January 1, 1999 between Yankee
Gas and the purchasers identified therein (Incorporated by
reference to Form 10-Q for the quarter ended March 31, 1999,
File No. 0-10721 ("March 31, 1999 Form 10-Q")).
4.18 First Supplemental Indenture of Mortgage and Deed of Trust
dated January 1, 1999 between Yankee Gas and The Bank of New
York, as trustee (Incorporated by reference to March 31, 1999
Form 10-Q).
(10)
10.1 Asset Transfer Agreement among Northeast Utilities Service
Company ("NUSCO"), The Connecticut Light and Power Company
("CL&P"), the Company, Yankee Gas and Housatonic Corporation
dated June 30, 1989 (Incorporated by reference to Form 10).
10.2 Environmental Liability Sharing and Indemnity Agreement dated
June 30, 1989 between Yankee Gas and CL&P (Incorporated by
reference to Form 10).
10.3 Rate Case Decision dated August 26, 1992 (Incorporated by
reference to 1992 Form
10-K).
10.4 Lease Agreement between Yankee Gas and NorConn Properties,
Inc. dated October 1, 1990 (Incorporated by reference to Form
S-1 Registration Statement #33-40758 dated May 22, 1991 and
amendment thereto dated June 18, 1991 ("Form S-1")).
10.5+ Non-Employee Director Deferred Compensation Plan (Incorporated
by reference to Form 10-K for the fiscal year ended September
30, 1996, File No. 0-10721 ("1996 Form 10-K")).
10.6+ 1991 Long-Term Incentive Compensation Plan (Incorporated by
reference to Proxy Statement dated December 24, 1990).
10.7+ Non-Employee Directors' Stock Compensation Plan (Incorporated
by reference Form 10-K for the fiscal year ended September 30,
1991, File No. 0-17605 ("1991 Form 10-K").
10.8+ Severance Pay Plan (Incorporated by reference to 1991 Form
10-K).
10.9 Service Agreement #800308 dated June 1, 1993, applicable to
Rate Schedule FT-1 (Firm Transportation) between Texas Eastern
Transmission Company ("Texas Eastern") and Yankee Gas
(Incorporated by reference to Form 10-K for the fiscal year
ended September 30,1993, File No. 0-17605 ("1993 Form 10-K")).
10.10 Service Agreement #1596 dated September 1, 1993, applicable to
Rate Schedule FT-A (Firm Transportation) between Tennessee Gas
Pipeline ("Tennessee") and Yankee Gas (Incorporated by
reference to 1993 Form 10-K).
10.11 Service Agreement #333 dated September 1,1993, applicable to
Rate Schedule FT-A (Firm Transportation) between Tennessee and
Yankee Gas (Incorporated by reference to 1993 Form 10-K).
10.12 Transportation Agreement dated February 7, 1991 between
Iroquois Gas System, L.P. ("Iroquois") and Yankee Gas for
transportation of Canadian gas purchased (Incorporated by
reference to Form S-1).
10.13 Service Agreement dated February 7, 1991 between Alberta
Northeast Gas Ltd. ("ANE" and Yankee Gas for purchase of gas
from ATCOR Limited (Incorporated by reference to Form S-1).
10.14 Service Agreement dated February 7, 1991 between ANE and
Yankee Gas for purchase of gas from PROGAS Limited
(Incorporated by reference to Form S-1).
10.15 Service Agreement dated February 7, 1991 between ANE and
Yankee Gas for purchase of gas from AEC Oil and Gas Company
(Incorporated by reference to Form S-1).
10.16 Service Agreement dated February 7, 1991 between ANE and
Yankee Gas for purchase of gas from TransCanada Pipelines
(Incorporated by reference to Form
S-1).
10.17+ Form of Change in Control Executive Severance Agreement for
Charles E. Gooley, Mary J. Healey, Thomas J. Houde, Steven P.
Laden, James M. Sepanski, and J. Kingsley Fink (Incorporated
by reference to 1995 Form 10-K).
10.18 $60 million Revolving Credit Agreement among Yankee Gas and
several banks dated February 2, 1995. (Incorporated by
reference to 1995 Form 10-K).
10.19 Agreement for Systems Operations Services among Yankee Gas and
Integrated Systems Solutions Corporation ("ISSC") dated August
12, 1991 (Incorporated by reference to 1992 Form 10-K).
10.20 Stipulation and Agreement dated January 3, 1996 between Yankee
Gas and the Office of Consumer Counsel. (Incorporated by
reference to 1996 Form 10-K).
10.21+ 1996 Long-Term Incentive Compensation Plan, as amended.
(Incorporated by reference to Form 10-K for the year ended
September 30, 1998, File No. 0-10721).
10.22 Amendment to Stipulation and Agreement dated October 1, 1997
between Yankee Gas and Connecticut Office of Consumer Counsel.
(Incorporated by reference to 1997 Form 8-K).
10.23 Credit Agreement dated as of June 11, 1998 by and among Yankee
Energy System, Inc., the lenders identified therein, and the
Bank of New York as administrative agent for each of the
lenders (Incorporated by reference to Form 10-Q for the
quarter ended June 30, 1998, File No. 0-10721).
11* Statement re: Computation of per share earnings.
21* Subsidiaries of the registrant.
23* Consent of Arthur Andersen LLP.
27* Financial Data Schedule.
* Filed herewith.
+ Management contract or compensatory plan.