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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 DECEMBER 31, 1997
COMMISSION FILE NUMBER 1-10403
TEPPCO PARTNERS, L.P.
(Exact name of Registrant as specified in its charter)
DELAWARE 76-0291058
(State of Incorporation or Organization) (I.R.S. Employer
Identification Number)
2929 ALLEN PARKWAY
P.O. BOX 2521
HOUSTON, TEXAS 77252-2521
(Address of principal executive offices, including zip code)
(713) 759-3636
(Registrant's telephone number, including area code)
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Name of each exchange on
Title of each class Which registered
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Units representing Limited Partner Interests New York Stock Exchange
Securities registered pursuant to Section 12(g) of the Act: NONE
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 twelve 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/
At February 24, 1998 the aggregate market value of the registrant's
Units held by non-affiliates was $803,379,582, which was computed using the
average of the high and low sales prices of the Units on February 24, 1998.
Units outstanding as of February 24, 1998: 14,500,000.
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TABLE OF CONTENTS
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PART I
ITEMS 1 Business and Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
AND 2.
ITEM 3. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9
ITEM 4. Submission of Matters to a Vote of Security Holders . . . . . . . . . . . . . . . . . . . . . . . . 9
PART II
ITEM 5. Market for Registrant's Units and Related Unitholder Matters . . . . . . . . . . . . . . . . . . . 10
ITEM 6. Selected Financial Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
ITEM 7. Management's Discussion and Analysis of Financial Condition and Results of Operations . . . . . . 12
ITEM 8. Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
ITEM 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure . . . . . . . 18
PART III
ITEM 10. Directors and Executive Officers of the Registrant . . . . . . . . . . . . . . . . . . . . . . . . . 18
ITEM 11. Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20
ITEM 12. Security Ownership of Certain Beneficial Owners and Management . . . . . . . . . . . . . . . . . . . 24
ITEM 13. Certain Relationships and Related Transactions . . . . . . . . . . . . . . . . . . . . . . . . . . . 25
PART IV
ITEM 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K . . . . . . . . . . . . . . . . . . 26
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ITEMS 1 AND 2. BUSINESS AND PROPERTIES
GENERAL
TEPPCO Partners, L.P. is a Delaware limited partnership that was
formed on March 7, 1990 to own and operate through TE Products Pipeline
Company, Limited Partnership (collectively the "Partnership"), the refined
petroleum products and liquefied petroleum gases ("LPGs") pipeline business of
Texas Eastern Products Pipeline Company (the "Company" or "General Partner"), a
Delaware corporation. The General Partner performs all management and
operating functions required for the Partnership pursuant to the Agreements of
Limited Partnership of TEPPCO Partners, L.P. and TE Products Pipeline Company,
Limited Partnership (the "Partnership Agreements"). The Company owns an
effective combined 2% general partner's interest in the Partnership. The
Company has agreed not to voluntarily withdraw as the general partner of the
Partnership, subject to certain limited exceptions, prior to January 1, 2000.
On June 18, 1997, PanEnergy Corp ("PanEnergy") and Duke Power Company
completed a previously announced merger. At closing, the combined companies
became Duke Energy Corporation ("Duke Energy"). The Company, previously a
wholly-owned subsidiary of PanEnergy, became an indirect wholly-owned
subsidiary of Duke Energy on the date of the merger.
The Partnership is one of the largest pipeline common carriers of
refined petroleum products and LPGs in the United States. The Partnership owns
and operates an approximate 4,300-mile pipeline system (together with the
receiving, storage and terminaling facilities mentioned below, the "Pipeline
System" or "Pipeline" or "System") extending from southeast Texas through the
central and midwestern United States to the northeastern United States. The
Pipeline System includes delivery terminals along the Pipeline for outloading
product to other pipelines, tank trucks, rail cars or barges, as well as
substantial storage capacity at Mont Belvieu, Texas, the largest LPGs storage
complex in the United States, and at other locations. The Partnership also owns
two marine receiving terminals, one near Beaumont, Texas, and the other at
Providence, Rhode Island. The Providence terminal is not physically connected
to the Pipeline. As an interstate common carrier, the Pipeline System offers
interstate transportation services, pursuant to tariffs filed with the Federal
Energy Regulatory Commission ("FERC"), to any shipper of refined petroleum
products and LPGs who requests such services, provided that the products
tendered for transportation satisfy the conditions and specifications contained
in the applicable tariff. In addition to the revenues received by the Pipeline
System from its interstate tariffs, it also receives revenues from the
shuttling of LPGs between refinery and petrochemical facilities on the upper
Texas Gulf Coast and ancillary transportation, storage and marketing services
at key points along the System. Substantially all the petroleum products
transported and stored in the Pipeline System are owned by the Partnership's
customers. Petroleum products are received at terminals located principally on
the southern end of the Pipeline System, stored, scheduled into the Pipeline in
accordance with customer nominations and shipped to delivery terminals for
ultimate delivery to the final distributor (e.g., gas stations and retail
propane distribution centers) or to other pipelines. Pipelines are generally
the lowest cost method for intermediate and long-haul overland transportation
of petroleum products. The Pipeline System is the only pipeline that transports
LPGs to the Northeast.
The Partnership's business depends in large part on (i) the level of
demand for refined petroleum products and LPGs in the geographic locations
served by it and (ii) the ability and willingness of customers having access to
the Pipeline System to supply such demand by deliveries through the System.
The Partnership cannot predict the impact of future fuel conservation measures,
alternate fuel requirements, governmental regulation, technological advances in
fuel economy and energy-generation devices, all of which could reduce the
demand for refined petroleum products and LPGs in the areas served by the
Partnership.
OPERATIONS
The Partnership conducts business and owns properties located in 12
states. Products are transported in liquid form from the upper Texas Gulf Coast
through two parallel underground pipelines that extend to Seymour,
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Indiana. From Seymour, segments of the Pipeline System extend to the Chicago,
Illinois; Lima, Ohio; Selkirk, New York; and Philadelphia, Pennsylvania, areas.
The Pipeline System east of Todhunter, Ohio, is dedicated solely to LPGs
transportation and storage services.
The Pipeline System includes 30 storage facilities with an aggregate
storage capacity of 13 million barrels of refined petroleum products and 38
million barrels of LPGs, including storage capacity leased to outside parties,
as well as 20 product delivery terminals. In addition, the Pipeline System
makes deliveries to terminals and storage facilities owned by third parties.
PIPELINE SYSTEM
The Pipeline System is comprised of a 20-inch diameter line extending
in a generally northeasterly direction from Baytown, Texas (located
approximately 30 miles east of Houston), to a point in southwest Ohio near
Lebanon and Todhunter. A second line, which also originates at Baytown, is 16
inches in diameter until it reaches Beaumont, Texas, at which point it reduces
to a 14-inch diameter line. This second line extends along the same path as the
20-inch diameter line to the Pipeline System's terminal in El Dorado, Arkansas,
before continuing as a 16-inch diameter line to Seymour, Indiana. The Pipeline
System also has smaller diameter lines that extend laterally from El Dorado to
Helena and Arkansas City, Arkansas, from Tyler, Texas, to El Dorado and from
McRae, Arkansas, to West Memphis, Arkansas. The lines from El Dorado to Helena
and Arkansas City have 10-inch diameters. The line from Tyler to El Dorado
varies in diameter from 8 inches to 10 inches. The line from McRae to West
Memphis has a 12-inch diameter. The Pipeline System also includes a 14-inch
diameter line from Seymour, Indiana, to Chicago, Illinois, and a 10-inch
diameter line running from Lebanon to Lima, Ohio. This 10-inch diameter
pipeline connects to the Buckeye Pipe Line Company system that serves, among
others, markets in Michigan and eastern Ohio. Also, the Pipeline System has a
6-inch diameter pipeline connection to the Greater Cincinnati/Northern Kentucky
International Airport and a 8-inch diameter pipeline connection to the George
Bush Intercontinental Airport, Houston. In addition, there are numerous smaller
diameter lines associated with the gathering and distribution system.
The Pipeline System continues eastward from Todhunter, Ohio, to
Greensburg, Pennsylvania, at which point it branches into two segments, one
ending in Selkirk, New York (near Albany), and the other ending at Marcus Hook,
Pennsylvania (near Philadelphia). The Pipeline east of Todhunter and ending in
Selkirk is an 8-inch diameter line, whereas the line starting at Greensburg and
ending at Marcus Hook varies in diameter from 6 inches to 8 inches. East of
Todhunter, Ohio, the Partnership transports only LPGs through the Pipeline.
The Pipeline System has been constructed and is in general compliance
with applicable federal, state and local laws and regulations, and accepted
industry standards and practices. The Partnership performs regular maintenance
on all the facilities of the Pipeline System and has an ongoing process of
inspecting segments of the Pipeline System and making repairs and replacements
when necessary or appropriate. In addition, the Partnership conducts periodic
air patrols of the Pipeline System to monitor pipeline integrity and
third-party right of way encroachments.
TITLE TO PROPERTIES
The Partnership believes it has satisfactory title to all of its
assets. Although such properties are subject to liabilities in certain cases,
such as customary interests generally contracted in connection with acquisition
of the properties, liens for taxes not yet due, easements, restrictions, and
other minor encumbrances, the Partnership believes none of such burdens
materially detracts from the value of such properties or from the Partnership's
interest therein or will materially interfere with their use in the operation
of the Partnership's business.
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MAJOR BUSINESS SECTOR MARKETS
The Pipeline System's major operations are the transportation, storage
and terminaling of refined petroleum products and LPGs along its mainline
system, and the storage and short-haul transportation of LPGs associated with
its Mont Belvieu operations. Product deliveries, in millions of barrels
(MMBbls) on a regional basis, over the last three years were as follows:
<TABLE>
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PRODUCT DELIVERIES (MMBbls)
YEARS ENDED DECEMBER 31,
----------------------------------
1997 1996 1995
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Refined Products Transportation:
Central (1) ............................ 69.4 66.9 60.6
Midwest (2) ............................ 29.9 28.7 29.3
Ohio and Kentucky ...................... 20.7 19.7 20.3
-------- -------- --------
Subtotal ............................ 120.0 115.3 110.2
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LPGs Mainline Transportation:
Central, Midwest and Kentucky (1)(2) ... 23.8 24.6 23.3
Ohio and Northeast (3) ................. 18.2 17.0 15.0
-------- -------- --------
Subtotal ............................ 42.0 41.6 38.3
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Mont Belvieu Operations:
LPGs ................................... 27.8 22.5 30.1
-------- -------- --------
Total Product Deliveries ............ 189.8 179.4 178.6
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</TABLE>
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(1) Arkansas, Louisiana, Missouri and Texas.
(2) Illinois and Indiana.
(3) New York and Pennsylvania.
The mix of products delivered varies seasonally, with gasoline demand
generally stronger in the spring and summer months and LPGs demand generally
stronger in the fall and winter months. Weather and economic conditions in the
geographic areas served by the Pipeline System also affect the demand for and
the mix of the products delivered.
Refined products and LPGs deliveries over the last three years were as
follows:
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PRODUCT DELIVERIES (MMBbls)
YEARS ENDED DECEMBER 31,
----------------------------------
1997 1996 1995
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Refined Products Transportation:
Gasoline ........................ 66.8 65.4 64.1
Jet Fuels ....................... 22.4 20.7 18.1
Middle Distillates (1) .......... 24.0 23.2 22.4
MTBE/Toluene .................... 6.8 6.0 5.6
-------- -------- --------
Subtotal ..................... 120.0 115.3 110.2
-------- -------- --------
LPGs Mainline Transportation:
Propane ......................... 34.7 35.2 29.1
Butanes ......................... 7.3 6.4 9.2
-------- -------- --------
Subtotal ..................... 42.0 41.6 38.3
-------- -------- --------
Mont Belvieu Operations:
LPGs ............................ 27.8 22.5 30.1
-------- -------- --------
Total Product Deliveries ..... 189.8 179.4 178.6
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</TABLE>
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(1) Primarily diesel fuel, heating oil and other middle distillates.
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Refined Petroleum Products Transportation
The Pipeline System transports refined petroleum products from the
upper Texas Gulf Coast, eastern Texas and southern Arkansas to the Central and
Midwest regions of the United States with deliveries in Texas, Louisiana,
Arkansas, Missouri, Illinois, Kentucky, Indiana and Ohio. At these points,
refined petroleum products are delivered to Partnership-owned terminals,
connecting pipelines and customer-owned terminals. The volume of refined
petroleum products transported by the Pipeline System is directly affected by
the demand for such products in the geographic regions the System serves. Such
market demand varies based upon the different end uses to which the refined
products deliveries are applied. Demand for gasoline, which accounts for a
substantial portion of the volume of refined products transported through the
Pipeline System, depends upon price, prevailing economic conditions and
demographic changes in the markets served. Demand for refined products used in
agricultural operations is affected by weather conditions, government policy
and crop prices. Demand for jet fuel depends upon prevailing economic
conditions and military usage.
Effective January 1, 1995, the Clean Air Act Amendments of 1990
mandated the use of reformulated gasolines in nine metropolitan areas of the
United States, including the Houston and Chicago areas served by the System. A
portion of the reformulated and oxygenated gasolines includes methyl tertiary
butyl ether ("MTBE") as a major blending component. The Partnership has
invested in modifications to the System needed to allow the Partnership to
achieve increased revenues from the transportation and storage of MTBE as well
as other blending components used in the production of reformulated gasolines.
LPGs Mainline Transportation
The Pipeline System transports LPGs from the upper Texas Gulf Coast to
the Central, Midwest and Northeast regions of the United States. The Pipeline
System east of Todhunter, Ohio, is devoted solely to the transportation of
LPGs. Since LPGs demand is generally stronger in the winter months, the
Pipeline System often operates near capacity during such time. Propane
deliveries are generally sensitive to the weather and meaningful year-to-year
variations have occurred and will likely continue to occur.
The Partnership's ability to serve markets in the Northeast is
enhanced by its propane import terminal at Providence, Rhode Island. This
facility includes a 400,000-barrel refrigerated storage tank along with ship
unloading and truck loading facilities. Although the terminal is operated by
the Partnership, the utilization of the terminal is committed by contract to a
major propane marketer through May 2001.
Mont Belvieu LPGs Storage and Pipeline Shuttle
A key aspect of the Pipeline System's LPGs business is its storage and
pipeline asset base in the Mont Belvieu, Texas, complex serving the
fractionation, refining and petrochemical industries. The complex is the
largest of its kind in the United States and provides substantial capacity and
flexibility in the transportation, terminaling and storage of natural gas
liquids, LPGs and olefins.
The Partnership has approximately 34 million barrels of LPGs storage
capacity, including storage capacity leased to outside parties, at the Mont
Belvieu complex. The Partnership's Mont Belvieu short-haul transportation
shuttle system, consisting of a complex system of pipelines and interconnects,
ties Mont Belvieu to virtually every refinery and petrochemical facility on the
upper Texas Gulf Coast.
Product Sales and Other
The Partnership also derives revenue from the sale of product
inventory, terminaling activities and other ancillary services associated with
the transportation and storage of refined petroleum products and LPGs.
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CUSTOMERS
The Pipeline System's customers for the transportation of refined
petroleum products include major integrated oil companies, independent oil
companies and wholesalers. End markets for these deliveries are primarily (i)
retail service stations, (ii) truck stops, (iii) agricultural enterprises, (iv)
refineries (for MTBE and other blendstocks), and (v) military and commercial
jet fuel users.
Propane shippers include wholesalers and retailers who, in turn, sell
to commercial, industrial, agricultural and residential heating customers, as
well as utilities who use propane as a fuel source. Refineries constitute the
Partnership's major customers for butane and isobutane, which are used as a
blendstock for gasolines and as a feedstock for alkylation units, respectively.
At December 31, 1997, the Pipeline System had approximately 165
customers. Transportation revenues (and percentage of total revenues)
attributable to the top 10 shippers were $85 million (38%), $81 million (38%),
and $77 million (38%) for the years ended December 31, 1997, 1996 and 1995,
respectively. During 1997, 1996 and 1995, no single customer accounted for
greater than 10% of total revenues. Loss of a business relationship with a
significant customer could have an adverse affect on the consolidated financial
position, results of operations and liquidity of the Partnership.
COMPETITION
The Pipeline System conducts operations without the benefit of
exclusive franchises from government entities. Interstate common carrier
transportation services are provided through the System pursuant to tariffs
filed with the FERC.
Because pipelines are generally the lowest cost method for intermediate
and long-haul overland movement of refined petroleum products and LPGs, the
Pipeline System's most significant competitors (other than indigenous
production in its markets) are pipelines in the areas where the Pipeline System
delivers products. Competition among common carrier pipelines is based
primarily on transportation charges, quality of customer service and proximity
to end users. The General Partner believes the Partnership is competitive with
other pipelines serving the same markets; however, comparison of different
pipelines is difficult due to varying product mix and operations.
Trucks, barges and railroads competitively deliver products in some of
the areas served by the Pipeline System. Trucking costs, however, render that
mode of transportation less competitive for longer hauls or larger volumes.
Barge fees for the transportation of refined products are generally lower than
the Partnership's tariffs. The Partnership faces competition from rail
movements of LPGs in several geographic areas. The most significant area is the
Northeast, where rail movements of propane from Sarnia, Canada, compete with
propane moved on the Pipeline System.
CAPITAL EXPENDITURES
Capital expenditures by the Partnership were $32.9 million for the year
ended December 31, 1997. This amount includes capitalized interest of $1.5
million. Approximately, $12.5 million was used for revenue-generating projects
and $18.9 million was used for System integrity projects and for sustaining
existing operations. Revenue-generating projects were primarily comprised of
$4.4 million of expenditures to complete the expansion of the Ark-La-Tex system
between Shreveport, Louisiana, and El Dorado, Arkansas, which was placed in
service on March 31, 1997; $3.6 million of expenditures to complete the
mainline expansion of 50,000 barrels per day of capacity between El Dorado and
Seymour, Indiana, which was completed during the first quarter of 1997; and
$2.1 million of expenditures to complete the pipeline connection to Colonial
Pipeline Company's ("Colonial") pipeline at Beaumont, Texas, which was placed
in service on May 1, 1997.
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The Partnership estimates that capital expenditures for 1998 will be
approximately $23 million. Approximately $1.5 million is expected to be used
for revenue-generating projects and the remaining capital expenditures during
1998 will primarily be used for life-cycle replacements and to upgrade current
facilities. The Partnership revises capital spending periodically in response
to changes in cash flows and operations.
REGULATION
The Partnership's interstate common carrier pipeline operations are
subject to rate regulation by the FERC under the Interstate Commerce Act
("ICA"), the Energy Policy Act of 1992 ("Act") and rules and orders promulgated
pursuant thereto. FERC regulation requires that interstate oil pipeline rates
be posted publicly and that these rates be "just and reasonable" and
nondiscriminatory.
Rates of interstate oil pipeline companies, like the Partnership, are
currently regulated by FERC primarily through an index methodology, whereby a
pipeline is allowed to change its rates based on the change from year-to-year
in the Producer Price Index for finished goods less 1% ("PPI Index"). In the
alternative, interstate oil pipeline companies may elect to support rate
filings by using a cost-of-service methodology, competitive market showings or
agreements between shippers and the oil pipeline company that the rate is
acceptable. With one immaterial exception, the Partnership has used the index
methodology since the adoption thereof in 1995 and intends to continue using
such methodology in the future. Conditions may arise in the future, however,
that would prompt the Partnership to utilize an alternative methodology.
In a June 1995 decision, the FERC disallowed the inclusion of imputed
income taxes in the cost-of-service tariff filing of Lakehead Pipeline Company,
Limited Partnership ("Lakehead"), an unrelated oil pipeline limited
partnership. The FERC's decision held that Lakehead was entitled to include an
income tax allowance in its cost-of-service for income attributable to
corporate partners but not on income attributable to individual partners. In
1996, Lakehead reached an agreement with its shippers on all contested rates
and has withdrawn its appeal of the June 1995 decision. In another FERC
proceeding, SFPP, L.P., the Administrative Law Judge in the Initial Decision
Concerning Rates, Terms and Conditions of Service, and Other Matters, followed
the Commission's decision in Lakehead and held that SFPP may claim an income
tax allowance with respect to income attributable to SFPP, Inc.'s general
partnership interest and income attributable to corporations holding publicly
traded limited partnership interests, but not for income attributable to
non-corporate limited partners, both individuals and other entities. The
decision also disallowed the income tax allowance attributable to SFPP, Inc.'s
limited partnership interest under facts peculiar to the way SFPP held its
limited partnership interests. Neither the FERC's decision in Lakehead nor the
Administrative Law Judge's initial decision in SFPP, L.P. affects the
Partnership's current rates and rate structure because the Partnership uses the
index methodology to support its rates and intends to continue to do so.
However, the Lakehead and SFPP precedents might become relevant to the
Partnership should it (i) elect in the future to use the cost-of-service
methodology or (ii) be required to use such methodology to defend its indexed
rates against a shipper protest alleging that an indexed rate increase
substantially exceeds actual cost increases. Should such circumstances arise,
there can be no assurance with respect to the effect of such precedents on the
Partnership's rates in view of the uncertainties involved in this issue.
ENVIRONMENTAL MATTERS
The operations of the Partnership are subject to federal, state and
local laws and regulations relating to protection of the environment. Although
the Partnership believes the operations of the Pipeline System are in material
compliance with applicable environmental regulations, risks of significant
costs and liabilities are inherent in pipeline operations, and there can be no
assurance that significant costs and liabilities will not be incurred.
Moreover, it is possible that other developments, such as increasingly strict
environmental laws and regulations and enforcement policies thereunder, and
claims for damages to property or persons resulting from the operations of the
Pipeline System, could result in substantial costs and liabilities to the
Partnership.
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Water
The Federal Water Pollution Control Act of 1972, as renamed and amended
as the Clean Water Act ("CWA"), imposes strict controls against the discharge
of oil and its derivatives into navigable waters. The CWA provides penalties
for any discharges of petroleum products in reportable quantities and imposes
substantial potential liability for the costs of removing an oil or hazardous
substance spill. State laws for the control of water pollution also provide
varying civil and criminal penalties and liabilities in the case of a release
of petroleum or its derivatives in surface waters or into the groundwater.
Spill prevention control and countermeasure requirements of federal laws
require appropriate containment berms and similar structures to help prevent
the contamination of navigable waters in the event of a petroleum tank spill,
rupture or leak.
Contamination resulting from spills or release of refined petroleum
products is an inherent risk within the petroleum pipeline industry. To the
extent that groundwater contamination requiring remediation exists along the
Pipeline System as a result of past operations, the Partnership believes any
such contamination could be controlled or remedied without having a material
adverse effect on the financial condition of the Partnership, but such costs
are site specific, and there can be no assurance that the effect will not be
material in the aggregate.
The primary federal law for oil spill liability is the Oil Pollution
Act of 1990 ("OPA"), which addresses three principal areas of oil pollution --
prevention, containment and cleanup, and liability. It applies to vessels,
offshore platforms, and onshore facilities, including terminals, pipelines and
transfer facilities. In order to handle, store or transport oil, shore
facilities were required to file oil spill response plans with the appropriate
agency being either the United States Coast Guard, the United States Department
of Transportation Office of Pipeline Safety ("OPS") or the Environmental
Protection Agency ("EPA"). Numerous states have enacted laws similar to OPA.
Under OPA and similar state laws, responsible parties for a regulated facility
from which oil is discharged may be liable for removal costs and natural
resources damages. The General Partner believes that the Partnership is in
material compliance with regulations pursuant to OPA and similar state laws.
The EPA has adopted regulations that require the Partnership to have
permits in order to discharge certain storm water run-off. Storm water
discharge permits may also be required by certain states in which the
Partnership operates. Such permits may require the Partnership to monitor and
sample the effluent. The General Partner believes that the Partnership is in
material compliance with effluent limitations at existing facilities.
Air Emissions
The operations of the Partnership are subject to the federal Clean Air
Act and comparable state and local statutes. The Clean Air Act Amendments of
1990 (the "Clean Air Act") will require most industrial operations in the
United States to incur future capital expenditures in order to meet the air
emission control standards that are to be developed and implemented by the EPA
and state environmental agencies during the next decade. Pursuant to the Clean
Air Act, any Partnership facilities that emit volatile organic compounds or
nitrogen oxides and are located in ozone non-attainment areas will face
increasingly stringent regulations, including requirements that certain sources
install the reasonably available control technology. The EPA is also required
to promulgate new regulations governing the emissions of hazardous air
pollutants. Some of the Partnership's facilities are included within the
categories of hazardous air pollutant sources which will be affected by these
regulations. The Partnership does not anticipate that changes currently
required by the Clean Air Act hazardous air pollutant regulations will have a
material adverse effect on the Partnership.
The Clean Air Act also introduced the new concept of federal operating
permits for major sources of air emissions. Under this program, one federal
operating permit (a "Title V" permit) will be issued. The permit will act as an
umbrella that includes all other federal, state and local preconstruction
and/or operating permit provisions, emission standards, grandfathered rates,
and record keeping, reporting, and monitoring requirements in a single
document. The federal operating permit will be the tool that the public and
regulatory agencies use to review and enforce a site's compliance with all
aspects of clean air regulation at the federal, state and local level. The
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Partnership expects approximately ten of its facilities to apply for and obtain
these federal operating permits in the next two years.
Solid Waste
The Partnership generates hazardous and non-hazardous solid wastes that
are subject to requirements of the federal Resource Conservation and Recovery
Act ("RCRA") and comparable state statutes. Amendments to RCRA have required
the EPA to promulgate regulations banning the land disposal of all hazardous
wastes unless the wastes meet certain treatment standards or the land-disposal
method meets certain waste containment criteria. In 1990, the EPA issued the
Toxicity Characteristic Leaching Procedure, which substantially expanded the
number of materials defined as hazardous waste. Certain wastewater and other
wastes generated from the Partnership's business activities previously
classified as nonhazardous are now classified as hazardous due to the presence
of dissolved aromatic compounds. The Partnership has utilized waste
minimization and recycling processes and has installed pre-treatment facilities
to reduce the volume of its hazardous waste. The Partnership is currently
permitted to utilize five regional on-site waste water treatment facilities.
Operating expenses of these facilities have not had a material adverse effect
on the financial position or results of operations of the Partnership.
Superfund
The Comprehensive Environmental Response, Compensation and Liability
Act ("CERCLA"), also known as "Superfund," imposes liability, without regard to
fault or the legality of the original act, on certain classes of persons who
contributed to the release of a "hazardous substance" into the environment.
These persons include the owner or operator of a facility and companies that
disposed or arranged for the disposal of the hazardous substances found at a
facility. CERCLA also authorizes the EPA and, in some instances, third parties
to take actions in response to threats to the public health or the environment
and to seek to recover from the responsible classes of persons the costs they
incur. In the course of its ordinary operations, the Pipeline System generates
wastes that may fall within CERCLA's definition of a "hazardous substance."
Should a disposal facility previously used by the Partnership require clean up
in the future, the Partnership may be responsible under CERCLA for all or part
of the costs required to clean up sites at which such wastes have been
disposed.
Other Environmental Proceedings
The Partnership and the Indiana Department of Environmental Management
("IDEM") have entered into an Agreed Order that will ultimately result in a
remediation program for any on-site and off-site groundwater contamination
attributable to the Partnership's operations at the Seymour, Indiana, terminal.
As part of the Agreed Order, the Partnership has completed the remedial
investigation sampling for groundwater contamination. In November 1997, IDEM
approved the final remedial investigation report for the Seymour terminal. The
Partnership is currently negotiating with IDEM the clean-up levels to be
attained at the Seymour terminal. The Partnership estimates that the costs of
the remediation program to be proposed by the Partnership for the Seymour
terminal will not exceed the amount accrued therefore (approximately $1.7
million at December 31, 1997). In the opinion of the General Partner, the
completion of the remediation program to be proposed by the Partnership, if
such program is approved by IDEM, will not have a material adverse impact on
the Partnership.
The Partnership received a compliance order from the Louisiana
Department of Environmental Quality ("DEQ") during 1994 relative to potential
environmental contamination at the Partnership's Arcadia, Louisiana facility,
which may be attributable to the operations of the Partnership and surrounding
petroleum terminals of other companies. The Partnership has finalized a
negotiated Compliance Order with DEQ that will allow the Partnership to
continue with a remediation plan similar to the one previously agreed to by DEQ
and implemented by the Company. In the opinion of the General Partner, the
completion of the remediation program being proposed by the Partnership will
not have a future material adverse impact on the Partnership.
8
<PAGE> 11
SAFETY REGULATION
The Partnership is subject to regulation by the United States
Department of Transportation ("DOT") under the Hazardous Liquid Pipeline Safety
Act of 1979 ("HLPSA") and comparable state statutes relating to the design,
installation, testing, construction, operation, replacement and management of
its pipeline facilities. HLPSA covers petroleum and petroleum products and
requires any entity that owns or operates pipeline facilities to comply with
such regulations, to permit access to and copying of records and to make
certain reports and provide information as required by the Secretary of
Transportation. The Partnership believes it is in material compliance with
HLPSA requirements.
The Partnership is also subject to the requirements of the federal
Occupational Safety and Health Act ("OSHA") and comparable state statutes. The
Partnership believes it is in material compliance with OSHA and state
requirements, including general industry standards, recordkeeping requirements
and monitoring of occupational exposure to benzene.
The OSHA hazard communication standard, the EPA community right-to-know
regulations under Title III of the federal Superfund Amendment and
Reauthorization Act, and comparable state statutes require the Partnership to
organize and disclose information about the hazardous materials used in its
operations. Certain parts of this information must be reported to employees,
state and local governmental authorities, and local citizens upon request. In
general, the Partnership expects to increase its expenditures during the next
decade to comply with higher industry and regulatory safety standards such as
those described above. Such expenditures cannot be accurately estimated at this
time, although the General Partner does not believe that they will have a
future material adverse impact on the Partnership.
The Partnership is subject to OSHA Process Safety Management ("PSM")
regulations which are designed to prevent or minimize the consequences of
catastrophic releases of toxic, reactive, flammable, or explosive chemicals.
These regulations apply to any process which involves a chemical at or above
the specified thresholds; or any process which involves a flammable liquid or
gas, as defined in the regulations, stored on site in one location, in a
quantity of 10,000 pounds or more. The Partnership utilizes certain covered
processes and maintains storage of LPG in pressurized tanks, caverns and wells
in excess of 10,000 pounds at various locations. Flammable liquids stored in
atmospheric tanks below their normal boiling point without benefit of chilling
or refrigeration are exempt. The Partnership believes it is in material
compliance with the PSM regulations.
EMPLOYEES
The Partnership does not have any employees, officers or directors. The
General Partner is responsible for the management of the Partnership. As of
December 31, 1997, the General Partner had 516 employees.
ITEM 3. LEGAL PROCEEDINGS
The Partnership has been, in the ordinary course of business, a
defendant in various lawsuits and a party to various legal proceedings, some of
which are covered in whole or in part by insurance. The General Partner
believes that the outcome of such lawsuits and other proceedings will not
individually or in the aggregate have a material adverse effect on the
Partnership's financial condition, operations or cash flows.
For information regarding certain legal proceedings brought by a state
agency to which the Partnership is a party, see Items 1 and 2, "Business and
Properties -- Environmental Matters -- Other Environmental Proceedings."
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
NONE
9
<PAGE> 12
PART II
ITEM 5. MARKET FOR REGISTRANT'S UNITS AND RELATED UNITHOLDER MATTERS
The Units of the Partnership are listed and traded on the New York
Stock Exchange under the symbol TPP. The high and low trading prices of the
Units in 1997 and 1996, respectively, as reported in The Wall Street Journal,
were as follows:
<TABLE>
<CAPTION>
1997 1996
-------------------------- ---------------------------
QUARTER HIGH LOW HIGH LOW
- -------------- ----------- ---------- ----------- -----------
<S> <C> <C> <C> <C>
First ............. $ 44 1/8 $ 40 1/4 $ 37 7/8 $ 34 1/4
Second ............ 45 13/16 39 5/8 38 1/4 34 5/8
Third ............. 53 1/8 44 7/8 40 3/8 37
Fourth ............ 56 1/2 50 1/16 42 1/8 38 1/8
</TABLE>
Based on the information received from its transfer agent and from
brokers/nominees, the Company estimates the number of beneficial Unitholders of
the Partnership as of February 24, 1998 to be approximately 21,300.
The quarterly cash distributions applicable to 1996 and 1997 were as
follows:
<TABLE>
<CAPTION>
AMOUNT
RECORD DATE PAYMENT DATE PER UNIT
----------- ------------ --------
<S> <C> <C>
April 30, 1996 ......................... May 10, 1996 ............................ $0.70
July 31, 1996 .......................... August 9, 1996 .......................... 0.75
October 31, 1996 ....................... November 8, 1996 ........................ 0.75
January 31, 1997 ....................... February 7, 1997 ........................ 0.75
April 30, 1997 ......................... May 9, 1997 ............................. 0.75
July 31, 1997 .......................... August 8, 1997 .......................... 0.80
October 31, 1997 ....................... November 7, 1997 ........................ 0.80
January 30, 1998 ....................... February 6, 1998 ........................ 0.85
</TABLE>
The Partnership makes quarterly cash distributions of its Available
Cash, as defined by the Partnership Agreements. Available Cash consists
generally of all cash receipts less cash disbursements and cash reserves
necessary for working capital, anticipated capital expenditures and
contingencies the General Partner deems appropriate and necessary.
The Partnership is a publicly traded master limited partnership that is
not subject to federal income tax. Instead, Unitholders are required to report
their allocable share of the Partnership's income, gain, loss, deduction and
credit, regardless of whether the Partnership makes distributions.
Distributions of cash by the Partnership to a Unitholder will not
result in taxable gain or income except to the extent the aggregate amount
distributed exceeds the tax basis of the Units held by the Unitholder.
10
<PAGE> 13
ITEM 6. SELECTED FINANCIAL DATA (UNAUDITED)
The following tables set forth, for the periods and at the dates
indicated, selected consolidated financial and operating data for the
Partnership. The financial data was derived from the consolidated financial
statements of the Partnership and should be read in conjunction with the
Partnership's audited consolidated financial statements included in the Index
to Financial Statements on page F-1 of this report. See also Item 7,
"Management's Discussion and Analysis of Financial Condition and Results of
Operations."
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
---------------------------------------------------------------------
1997 1996 1995 1994 1993
--------- --------- --------- --------- ---------
(in thousands, except per Unit Amounts and Operating Data)
<S> <C> <C> <C> <C> <C>
INCOME STATEMENT DATA:
Operating revenues:
Transportation -- Refined products .............. $ 107,304 $ 98,641 $ 96,190 $ 89,442 $ 75,144
Transportation -- LPGs .......................... 79,371 80,219 70,576 73,458 74,270
Gain on sale of inventory ....................... 2,261 3,674 4,115 966 1,848
Mont Belvieu operations ......................... 12,815 11,811 13,570 12,290 12,611
Other ........................................... 20,342 21,680 19,265 21,146 19,761
--------- --------- --------- --------- ---------
Total operating revenues ....................... 222,093 216,025 203,716 197,302 183,634
Operating expenses ................................. 106,771 105,182 103,938 94,337 88,257
Depreciation and amortization ...................... 23,772 23,409 23,286 23,063 23,485
--------- --------- --------- --------- ---------
Operating income ................................... 91,550 87,434 76,492 79,902 71,892
Interest expense -- net ............................ (32,229) (33,534) (34,987) (36,076) (36,242)
Other income -- net ................................ 1,979 4,748 5,212 2,714 1,502
--------- --------- --------- --------- ---------
Income before cumulative effect of accounting
change......................................... 61,300 58,648 46,717 46,540 37,152
Cumulative effect of accounting change, net of
minority interest (1) ......................... -- -- -- -- (949)
--------- --------- --------- --------- ---------
Net income ......................................... $ 61,300 $ 58,648 $ 46,717 $ 46,540 $ 36,203
========= ========= ========= ========= =========
Income per Limited Partner Unit:
Before cumulative effect of accounting change ... $ 3.90 $ 3.79 $ 3.08 $ 3.13 $ 2.54
Cumulative effect of accounting change (1) ...... -- -- -- -- (0.07)
--------- --------- --------- --------- ---------
Basic net income per Limited Partner Unit ....... $ 3.90 $ 3.79 $ 3.08 $ 3.13 $ 2.47
========= ========= ========= ========= =========
Diluted net income per Limited Partner Unit ..... $ 3.90 $ 3.78 $ 3.07 $ 3.13 $ 2.47
========= ========= ========= ========= =========
Distributions paid per Limited Partner Unit ..... $ 3.10 $ 2.90 $ 2.65 $ 2.37 $ 2.22
========= ========= ========= ========= =========
BALANCE SHEET DATA (AT PERIOD END):
Property, plant and equipment -- net ............... $ 567,681 $ 561,068 $ 533,470 $ 540,577 $ 543,613
Total assets ....................................... 673,909 671,241 669,915 665,331 655,138
Long-term debt (net of current maturities) ......... 309,512 326,512 339,512 349,512 356,512
Partners' capital .................................. 302,967 290,311 276,381 269,599 257,428
CASH FLOW DATA:
Net cash from operations ........................... $ 83,604 $ 86,121 $ 78,456 $ 70,082 $ 60,989
Capital expenditures ............................... (32,931) (51,264) (25,967) (20,826) (16,240)
Investments -- net ................................. 18,860 4,148 6,527 (41,776) --
Distributions ...................................... (49,042) (45,174) (40,342) (34,720) (30,056)
Principal payment, First Mortgage Notes ............ (13,000) (10,000) (7,000) (5,000) (4,000)
OPERATING DATA:
Volumes delivered (thousands of Bbls)
Refined products ................................ 119,971 115,262 110,234 107,271 90,712
LPGs ............................................ 41,991 41,640 38,237 36,636 38,813
Mont Belvieu operations ......................... 27,869 22,522 30,148 28,695 22,035
--------- --------- --------- --------- ---------
Total .......................................... 189,831 179,424 178,619 172,602 151,560
========= ========= ========= ========= =========
Average system tariff ($/Bbl)
Refined products ................................ $ 0.89 $ 0.86 $ 0.87 $ 0.83 $ 0.83
LPGs ............................................ 1.89 1.93 1.85 2.01 1.91
</TABLE>
(1) See Note 12 of the Notes to Consolidated Financial Statements included
elsewhere in this report.
11
<PAGE> 14
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
GENERAL
The Partnership's operations consist of the transportation, storage and
terminaling of petroleum products. Operations are somewhat seasonal with
higher revenues generally realized during the first and fourth quarters of each
year. Refined products volumes are generally higher during the second and third
quarters because of greater demand for gasolines during the spring and summer
driving seasons. LPGs volumes are generally higher from November through March
due to higher demand in the Northeast for propane, a major fuel for residential
heating.
The Partnership's revenues are derived from the transportation of
refined products and LPGs, the storage and short-haul shuttle transportation of
LPGs at the Mont Belvieu, Texas complex, sale of product inventory and other
ancillary services. Labor and electric power costs comprise the two largest
operating expense items of the Partnership.
The following information is provided to facilitate increased
understanding of the 1997, 1996 and 1995 consolidated financial statements and
accompanying notes of the Partnership included in the Index to Financial
Statements on page F-1 of this report. Material period-to-period variances in
the consolidated statements of income are discussed under "Results of
Operations." The "Financial Condition and Liquidity" section analyzes cash
flows and financial position. Discussion included in "Other Matters" addresses
key trends, future plans and contingencies. Throughout these discussions,
management addresses items that are reasonably likely to materially affect
future liquidity or earnings.
RESULTS OF OPERATIONS
Volume and average tariff information for 1997, 1996 and 1995 is
presented below:
<TABLE>
<CAPTION>
PERCENTAGE
INCREASE
YEARS ENDED DECEMBER 31, (DECREASE)
------------------------------------------- -----------------------------
1997 1996 1995 1997 1996
----------- ----------- ----------- ----------- -----------
(IN THOUSANDS, EXCEPT TARIFF INFORMATION)
<S> <C> <C> <C> <C> <C>
Volumes Delivered
Refined products ....................... 119,971 115,262 110,234 4% 5%
LPGs ................................... 41,991 41,640 38,237 1% 9%
Mont Belvieu operations ................ 27,869 22,522 30,148 24% (25%)
----------- ----------- ----------- ----------- -----------
Total ............................... 189,831 179,424 178,619 6% --
=========== =========== =========== =========== ===========
Average Tariff per Barrel
Refined products ....................... $ 0.89 $ 0.86 $ 0.87 3% (1%)
LPGs ................................... 1.89 1.93 1.85 (2%) 4%
Mont Belvieu operations ................ 0.15 0.17 0.15 (12%) 13%
Average system tariff per barrel .... $ 1.00 $ 1.02 $ 0.96 (2%) 6%
=========== =========== =========== =========== ===========
</TABLE>
1997 Compared to 1996
Net income for the year ended December 31, 1997 increased 5% to $61.3
million, compared with net income of $58.6 million for the year ended December
31, 1996. The increase in net income resulted from a $6.1 million increase in
operating revenues and a $1.3 million decrease in interest expense, net of
capitalized interest. These increases were partially offset by a $2.0 million
increase in costs and expenses and a $2.7 million decrease in other income -
net.
Operating revenues for the year ended 1997 increased 3% to $222.1
million from $216.0 million for the year ended 1996. This $6.1 million
increase resulted from a $8.7 million increase in refined products
transportation revenues and a $1.0 million increase in revenues generated from
Mont Belvieu operations, partially offset by a $0.8
12
<PAGE> 15
million decrease in LPGs transportation revenues, a $1.4 million decrease in
gain on sale of inventory and a $1.3 million decrease in other operating
revenue.
Refined products transportation revenues increased $8.7 million for the
year ended December 31, 1997, compared with the prior year, as a result of the
4% increase in volumes delivered and a 3% increase in the refined products
average tariff per barrel. The 4% increase in volumes delivered in 1997 was
attributable to the capacity expansion of the mainline System between El
Dorado, Arkansas, and Seymour, Indiana, which was completed during the first
quarter of 1997; capacity expansion of the Ark-La-Tex System between
Shreveport, Louisiana, and El Dorado, which was placed in service on March 31,
1997; and the connection to the Colonial pipeline, which was placed in service
on May 1, 1997. Also, jet fuel deliveries increased to 22.4 million barrels
due to a full year of deliveries to the United States Air Force Base near
Little Rock, Arkansas, which was completed in June 1996, as well as higher
demand from commercial airlines in the Midwest. Distillate and natural
gasoline deliveries increased during 1997 as a result of higher demand in the
Midwest market area. MTBE deliveries at the marine terminal near Beaumont,
Texas increased in 1997 as a result of higher production along the upper Texas
Gulf Coast. The 3% increase in the refined products average tariff per barrel
in 1997 was primarily attributable to new tariff structures for volumes
transported on the Ark-La-Tex System and volumes originating from the Colonial
pipeline connection.
LPGs transportation revenues decreased $0.8 million for the year ended
December 31, 1997, compared with the prior year, due to a 2% decrease in the
LPGs average tariff per barrel, partially offset by a 1% increase in volumes
delivered. Long-haul propane deliveries were lower than in the prior year
because of warmer winter weather in the Northeast during the first and fourth
quarters of 1997. These decreases were partially offset by stronger demand for
butane as a refinery feedstock due to the resumption during the second quarter
of 1997 of operations at a Northeast refinery that was shut down during early
1996. Increased petrochemical demand along the upper Texas Gulf Coast resulted
in a 17% increase in short-haul propane deliveries. The 2% decrease in the
LPGs average tariff per barrel resulted from an increase in 1997 of the ratio
of short-haul to long-haul propane deliveries.
Revenues generated from Mont Belvieu operations increased $1.0 million
for the year ended December 31, 1997, compared with the prior year, due
primarily to higher terminaling fees on butane received into the system,
increased propane dehydration fees and higher petrochemical demand for LPGs
along the upper Texas Gulf Coast. The decrease in the Mont Belvieu operations
average tariff per barrel was due to a higher percentage in 1997 of contract
deliveries, which generally carry lower tariffs.
Gains on the sale of inventory decreased $1.4 million during 1997,
compared with the prior year, as a result of lower volumes of product sold in
1997.
Other operating revenues decreased $1.3 million during the year ended
December 31, 1997, compared with 1996, due to lower propane imports at the
Partnership's marine terminal at Providence, Rhode Island, reduced refined
products storage volumes and write-downs of product inventory values as a
result of higher volumes of product blends in 1997. These decreases were
partially offset by increased terminaling revenues.
Costs and expenses increased $2.0 million during the year ended
December 31, 1997, compared with the prior year, due to a $1.0 million increase
in taxes - other than income taxes, a $0.6 million increase in operating,
general and administrative expenses and a $0.4 million increase in depreciation
and amortization charges. The increase in taxes - other than income taxes, was
due primarily to higher property tax assessments in 1997 and increased sales
taxes in 1997. The increase in operating, general and administrative expenses
was primarily attributable to an increase in throughput-related power expense,
increased labor and benefits expense and rental expense of the Colonial
capacity lease, partially offset by credits recorded during the third and
fourth quarters of 1997 for insurance reimbursement of past litigation costs
related to the Seymour terminal, decreased outside service costs for System
maintenance and lower product measurement losses in 1997.
Interest expense decreased $1.2 million during the year ended December
31, 1997, compared with 1996, due to the $13.0 million principal payment on the
First Mortgage Notes in March 1997. Interest capitalized
13
<PAGE> 16
increased $0.1 million over the prior year as a result of higher construction
balances related to capital projects, which commenced during 1996, and were
completed during 1997.
Other income - net decreased during the year ended December 31, 1997,
compared with the prior year, due primarily to lower interest income earned on
cash balances as a result of lower cash balances during 1997, and a $0.5
million loss recorded on the sale of the Partnership's Arkansas City, Arkansas,
terminal.
1996 Compared to 1995
Net income for the year ended December 31, 1996 increased 25% to $58.6
million, compared with net income of $46.7 million for the year ended December
31, 1995. Net income for 1995 included $7.4 million of charges for the
settlement of certain litigation and remediation costs at the Partnership's
Seymour, Indiana, terminal. Excluding such charges, net income for 1996 would
have increased by $4.5 million, or 8%. The increase in net income for 1996
resulted from a $12.3 million increase in operating revenues, a $0.9 million
decrease in interest expense and a $0.5 million increase in interest
capitalized. These increases for 1996 were partially offset by a $1.4 million
increase in costs and expenses.
Operating revenues for the year ended 1996 increased 6% to $216.0
million from $203.7 million for the year ended 1995. This $12.3 million
increase resulted from a $9.6 million increase in LPGs transportation revenues,
a $2.5 million increase in refined products transportation revenues and a $2.4
million increase in other operating revenues. These increases were partially
offset by a $1.8 million decrease in revenues generated from Mont Belvieu
operations and a $0.4 million decrease in product inventory sales.
Refined products transportation revenues increased $2.5 million for the
year ended December 31, 1996, compared with the prior year, as a result of the
5% increase in volumes delivered. Jet fuel deliveries increased to 20.7
million barrels due to the completion of the pipeline connection to the United
States Air Force Base near Little Rock, Arkansas, in June 1996, as well as
higher demand from commercial airlines in the Midwest. Motor fuel deliveries
also increased during 1996 as a result of higher demand in the Central and
Midwest market areas. These increases were partially offset by lower
deliveries of MTBE, reformulated gasoline and gasoline blendstocks in the
Chicago area, coupled with lower feedstock demand along the upper Texas Gulf
Coast.
LPGs transportation revenues increased $9.6 million, or 14%, for the
year ended December 31, 1996, compared with the prior year, due to the 9%
increase in volumes delivered and the 4% increase in the LPGs average tariff
per barrel. Propane deliveries increased to a record 35.2 million barrels as a
result of colder winter weather during the first and second quarters of 1996,
lower inventory supplies and favorable price differentials. The increase in
propane deliveries was partially offset by a 2.8 million barrel decrease in
butane deliveries attributable to increased Canadian supply imported into the
Midwest, higher Gulf Coast prices and the shut-down in early 1996 of a refinery
in the Northeast that was supplied by the Pipeline System. The 4% increase in
the LPGs average tariff per barrel during 1996 resulted from increased
long-haul propane deliveries in the upper Midwest and Northeast, coupled with
lower deliveries along the upper Texas Gulf Coast.
Revenues generated from Mont Belvieu operations decreased $1.8 million
during 1996, compared with the prior year, due to decreased storage revenue and
lower terminaling fees on butane received into the system. Additionally,
shuttle deliveries decreased 25% from the prior year due primarily to low
butane and propane inventory supplies and lower petrochemical demand for
propane along the upper Texas Gulf Coast. The Mont Belvieu operations average
tariff per barrel for shuttle deliveries increased to $0.17 per barrel in 1996,
due to a lower percentage of contract deliveries, which generally carry lower
tariffs.
Gains on the sale of inventory decreased $0.4 million during 1996,
compared with the prior year, as a result of lower volumes of product sold in
1996.
Other operating revenues increased $2.4 million during the year ended
December 31, 1996, compared with 1995, due to higher propane imports at the
Partnership's marine terminal at Providence, Rhode Island, increased
14
<PAGE> 17
LPGs terminaling fees and increased revenues resulting from greater volumes
marketed between customers at the Mont Belvieu complex.
Costs and expenses increased $1.4 million during the year ended
December 31, 1996, compared with the prior year, due primarily to a $1.1
million increase in taxes - other than income taxes, and a $0.1 million
increase in operating, general and administrative expenses. The increase in
taxes - other than income taxes, was attributable to a $0.9 million adjustment
recorded during 1995 related to the reclassification of the Partnership as a
non-utility for Ohio property taxes. Operating, general and administrative
expenses increased in 1996 as a result of higher throughput-related expenses
including higher mainline power costs, increased usage of propane odorant and
gasoline additives, and expenses for external barges utilized during the fourth
quarter of 1996. Additionally, expenses were higher during 1996 due to
increased System maintenance, coupled with increased labor and benefits costs.
These increases were largely offset by $7.4 million of charges during 1995
related to the settlement of certain claims and environmental remediation costs
at the Partnership's Seymour, Indiana, terminal.
Interest expense decreased $0.9 million during the year ended December
31, 1996, compared with 1995, due to the $10.0 million principal payment on the
First Mortgage Notes in March 1996. Interest capitalized increased $0.5
million over the prior year as a result of increased capital spending during
1996.
FINANCIAL CONDITION AND LIQUIDITY
Net cash from operations for the year ended December 31, 1997, totaled
$83.6 million, comprised of $85.1 million of income before charges for
depreciation and amortization, partially offset by $1.5 million used for
working capital changes. This compares with cash flows from operations of
$86.1 million for the year ended 1996, which was comprised of $82.1 million of
income before charges for depreciation and amortization and $4.0 million from
working capital changes. The $2.5 million decrease in cash provided by
operations in 1997 resulted from higher accounts receivable balances at
December 31, 1997, as compared to December 31, 1996, and lower product
inventory sales during 1997, partially offset by higher income earned in 1997
and lower cash payments for accrued expenses in 1997. Net cash from operations
for the year ended December 31, 1995 totaled $78.5 million, which was comprised
of $70.0 million of income before charges for depreciation and amortization and
$8.5 million of cash provided by other working capital changes. Net cash from
operations include interest payments related to the First Mortgage Notes (the
"Notes") of $33.6 million, $34.7 million and $35.5 million for each of the
years ended 1997, 1996 and 1995, respectively.
The Partnership routinely invests excess cash in liquid investments as
part of its cash management program. Investments of cash in discounted
commercial paper and Eurodollar time deposits with original maturities at date
of purchase of 90 days or less are included in cash and cash equivalents.
Short-term investments of cash consist of investment-grade corporate notes with
maturities during 1998. Long-term investments are comprised of investment-grade
corporate notes with varying maturities between 1999 and 2002. Interest income
earned on all investments is included in cash from operations. Cash flows
from investing activities included proceeds from investments of $25.0 million,
$18.6 million and $69.0 million for each of the years ended 1997, 1996 and
1995, respectively. Cash flows from investing activities also included
additional investments of $6.2 million, $14.4 million and $62.4 million for
each of the years ended 1997, 1996 and 1995, respectively. Cash balances
related to the investment of cash and proceeds from the investment of cash were
$56.1 million, $65.0 million and $74.9 million for the years ended December 31,
1997, 1996 and 1995, respectively. The increase in cash investments in 1995
was in anticipation of an increase in capital expenditures which were incurred
in 1996 and were funded by proceeds from investments. Capital expenditures
were $32.9 million, $51.3 million and $26.0 million for the years ended
December 31, 1997, 1996 and 1995, respectively.
Capital expenditures totaled $32.9 million for the year ended December
31, 1997, compared with capital expenditures of $51.3 million for the year
ended December 31, 1996. The decrease in 1997 reflects a $25.3 million
decrease in spending for revenue-generating projects due to higher construction
costs incurred in 1996 for the replacement of approximately 54 miles of an
8-inch diameter line with a 10-inch diameter line between Shreveport,
Louisiana, and El Dorado, Arkansas, which was placed in service on March 31,
1997; pipeline modifications to
15
<PAGE> 18
increase mainline capacity by 50,000 barrels per day between El Dorado and
Seymour, Indiana, which was completed during the first quarter of 1997; and the
completion of facilities required to deliver jet fuel to the United States Air
Force Base near Little Rock, Arkansas, which became operational in June 1996.
Capital expenditures for 1995 totaled $26.0 million. Capital expenditures for
System integrity projects and for sustaining existing operations totaled $18.9
million, $12.1 million and $16.1 million for each of the years ended 1997, 1996
and 1995, respectively.
During 1995, the Partnership received $9.8 million in insurance
proceeds related to the failure of a LPGs storage cavern in Ohio during April
1993. Pursuant to the agreements relating to the Notes, these proceeds were
held in a trust account and were invested in discounted commercial paper. The
proceeds and interest income were released by the trustee during August 1996
after storage and capacity modifications were completed along the Pipeline
System to replace the reduced storage capacity of the failed storage cavern in
Ohio.
The Partnership paid cash distributions of $49.0 million ($3.10 per
Limited Partner Unit), $45.2 million ($2.90 per Limited Partner Unit) and $40.3
million ($2.65 per Limited Partner Unit) for each of the years ended December
31, 1997, 1996 and 1995, respectively. On January 16, 1998, the Partnership
declared a cash distribution of $0.85 per Limited Partner Unit for the quarter
ended December 31, 1997. The distribution was paid on February 6, 1998, to
Unitholders of record on January 30, 1998.
On January 27, 1998, TE Products Pipeline Company, Limited Partnership
(the "Operating Partnership") completed the issuance of $180 million principal
amount of 6.45% Senior Notes due 2008, and $210 million principal amount of
7.51% Senior Notes due 2028 (collectively the "Senior Notes"). The 6.45%
Senior Notes due 2008 are not subject to redemption prior to January 15, 2008.
The 7.51% Senior Notes due 2028 may be redeemed at any time after January 15,
2008, at the option of the Operating Partnership, in whole or in part, at a
premium. Net proceeds from the issuance of the Senior Notes totaled
approximately $387 million and was used to repay in full the $326.5 million
principal amount of the Partnership's First Mortgage Notes, together with a
redemption premium of approximately $70.1 million. The repayment of the First
Mortgage Notes and the issuance of the Senior Notes will reduce the level of
cash required for debt service until 2008. The Partnership will record an
extraordinary charge during the first quarter of 1998 of approximately $73.5
million, which represents the redemption premium of approximately $70.1 million
and unamortized debt issue costs related to the First Mortgage Notes of
approximately $3.4 million.
The Senior Notes do not have sinking fund requirements. Interest on
the Senior Notes will be paid semiannually in arrears on January 15 and July 15
of each year, commencing July 15, 1998. The Senior Notes are unsecured
obligations of the Operating Partnership and will rank on a parity with all
other unsecured and unsubordinated indebtedness of the Operating Partnership.
The indenture governing the Senior Notes contain covenants, including, but not
limited to, covenants limiting (i) the creation of liens securing indebtedness
and (ii) sale and leaseback transactions. However, the indenture does not
limit the Partnership's ability to incur additional indebtedness.
OTHER MATTERS
The operations of the Partnership are subject to federal, state and
local laws and regulations relating to protection of the environment. Although
the Partnership believes the operations of the Pipeline System are in material
compliance with applicable environmental regulations, risks of significant
costs and liabilities are inherent in pipeline operations, and there can be no
assurance that significant costs and liabilities will not be incurred.
Moreover, it is possible that other developments, such as increasingly strict
environmental laws and regulations and enforcement policies thereunder, and
claims for damages to property or persons resulting from the operations of the
Pipeline System, could result in substantial costs and liabilities to the
Partnership. The Partnership does not anticipate that changes in environmental
laws and regulations will have a material adverse effect on its financial
position, operations or cash flows in the near term.
16
<PAGE> 19
The Partnership and the Indiana Department of Environmental Management
("IDEM") have entered into an Agreed Order that will ultimately result in a
remediation program for any on-site and off-site groundwater contamination
attributable to the Partnership's operations at the Seymour, Indiana, terminal.
As part of the Agreed Order, the Partnership has completed the remedial
investigation sampling for groundwater contamination. In November 1997, IDEM
approved the final remedial investigation report for the Seymour terminal. The
Partnership is currently negotiating with IDEM the clean-up levels to be
attained at the Seymour terminal. The Partnership estimates that the costs of
the remediation program to be proposed by the Partnership for the Seymour
terminal will not exceed the amount accrued therefore (approximately $1.7
million at December 31, 1997). In the opinion of the Company, the completion
of the remediation program to be proposed by the Partnership, if such program
is approved by IDEM, will not have a material adverse impact on the
Partnership.
During June 1997, the Partnership filed rate increases on selective
refined products tariffs and LPGs tariffs, averaging 1.7%. These rate
increases became effective July 1, 1997 without suspension or refund
obligation.
In October 1995, the Financial Accounting Standards Board ("FASB")
issued Statement of Financial Accounting Standards ("SFAS") 123, "Accounting
for Stock-Based Compensation." This standard addresses the timing and
measurement of stock-based compensation expense. The Partnership has elected
to retain the approach of Accounting Principles Board Opinion ("APB") No. 25,
"Accounting for Stock issued to Employees," (the intrinsic value method) for
recognizing stock-based expense in the consolidated financial statements. The
Partnership adopted SFAS 123 in 1996 with respect to the disclosure
requirements set forth therein for companies retaining the intrinsic value
approach of APB No. 25. See Note 10 of the Notes to Consolidated Financial
Statements of the Partnership included elsewhere in this report.
In December 1997, the Partnership adopted SFAS 128, "Earnings per
Share." This statement established standards for computing and presenting net
income per Limited Partner Unit and requires, among other things, dual
presentation of basic and diluted net income per Limited Partner Unit on the
face of the consolidated statements of income. The Partnership has restated
net income per Limited Partner Unit for the years ended December 31, 1996 and
1995 to include diluted net income per Limited Partner Unit.
In June 1997, the FASB issued SFAS 130, "Reporting Comprehensive
Income." This statement establishes standards for reporting and display of
comprehensive income and its components in a full set of financial statements.
In June 1997, the FASB also issued SFAS 131, "Disclosures about Segments of an
Enterprise and Related Information." This statement establishes standards for
reporting information about operating segments in annual financial statements
and requires that enterprises report selected information about operating
segments in interim reports issued to shareholders. Both of these statements
are effective for financial statements for periods beginning after December 15,
1997. As both SFAS 130 and 131 establish standards for reporting and display,
the Partnership does not expect the adoption of these statements to have a
material impact on its financial condition or results of operations.
The Partnership periodically enters into futures contracts to hedge its
exposure to price risk on product inventory transactions. Recognized gains and
losses related to futures contracts which qualify as hedges are recognized in
income when the related inventory transactions are completed. Gains and losses
related to futures contracts, which have been insignificant, are reported as a
component of product inventory in the consolidated balance sheet until
recognized as income. At December 31, 1997, there were no outstanding future
contracts.
In 1997, the Company initiated a program to prepare the Partnership's
process controls and business computer systems for the "Year 2000 issue."
Process controls are the automated equipment including hardware and software
systems which run operational activities. Business computer systems are the
computer hardware and software used by the Partnership. The Partnership
expects to incur internal staff costs as well as consulting and other expenses
related to testing and conversion of these assets. The Company continues to
evaluate appropriate courses of corrective action, including replacement of
certain systems whose associated costs would be recorded as assets and
amortized. The Company estimates that the amounts required to be expensed
during 1998 and 1999 will range between approximately $4.0 million and $6.0
million. The amount expensed in 1997 was immaterial.
17
<PAGE> 20
Testing and conversion is expected to be completed by mid-year 1999. The
Partnership has initiated formal communications with all of its significant
suppliers and large customers to determine the extent to which the Partnership
is vulnerable to those third parties' failure to remediate their own Year 2000
issue. However, there can be no guarantee that the systems of other companies,
on which the Partnership's systems rely, will be timely converted, or that a
failure to convert by another company, or a conversion that is incompatible
with the Partnership's systems, would not have a material adverse effect on the
Partnership.
The matters discussed herein include "forward-looking statements"
within the meaning of various provisions of the Securities Act of 1933 and the
Securities Exchange Act of 1934. All statements, other than statements of
historical facts, included in this document that address activities, events or
developments that the Partnership expects or anticipates will or may occur in
the future, including such things as estimated future capital expenditures
(including the amount and nature thereof), business strategy and measures to
implement strategy, competitive strengths, goals, expansion and growth of the
Partnership's business and operations, plans, references to future success,
references to intentions as to future matters and other such matters are
forward-looking statements. These statements are based on certain assumptions
and analyses made by the Partnership in light of its experience and its
perception of historical trends, current conditions and expected future
developments as well as other factors it believes are appropriate under the
circumstances. However, whether actual results and developments will conform
with the Partnership's expectations and predictions is subject to a number of
risks and uncertainties, including general economic, market or business
conditions, the opportunities (or lack thereof) that may be presented to and
pursued by the Partnership, competitive actions by other pipeline companies,
changes in laws or regulations, and other factors, many of which are beyond the
control of the Partnership. Consequently, all of the forward-looking
statements made in this document are qualified by these cautionary statements
and there can be no assurance that actual results or developments anticipated
by the Partnership will be realized or, even if substantially realized, that
they will have the expected consequences to or effect on the Partnership or its
business or operations.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The consolidated financial statements of the Partnership, together with
the independent auditors' report thereon of KPMG Peat Marwick LLP, appears on
pages F-2 through F-17 of this report. See Index to Financial Statements on
page F-1 of this report.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
NONE
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The Partnership does not have directors or officers. Set forth below
is certain information concerning the directors and executive officers of the
General Partner. All directors of the General Partner are elected annually by
Duke Energy. All officers serve at the discretion of the directors.
William L. Thacker, age 52, was elected a director of the General
Partner in 1992 and Chairman of the Board in October 1997. Mr. Thacker was
elected President and Chief Operating Officer in September 1992 and Chief
Executive Officer in January 1994. Prior to joining the Company, Mr. Thacker
was President of Unocal Pipeline Company from 1986 until 1992.
Paul M. Anderson, age 52, is Vice Chairman of the Board of the General
Partner and is Chairman of the Compensation Committee. He was elected a
director in March 1991. Mr. Anderson was elected President of PanEnergy in 1993
and Chief Executive Officer in April 1995 and is President and Chief Operating
Officer of Duke Energy and a director of Duke Energy. Mr. Anderson joined
PanEnergy in 1991 as group Vice President and
18
<PAGE> 21
President of Panhandle Eastern Pipe Line Company. Mr. Anderson is a director
of Temple-Inland, Inc., and Kerr-McGee Corporation.
James T. Hackett, age 44, is a director of the General Partner, having
been elected in March 1997. Mr. Hackett is group president, Energy Services of
Duke Energy. Mr. Hackett was previously executive vice president of PanEnergy
from 1996 to 1997 and was senior vice president of NGC Corporation from 1990 to
1995.
Jim W. Mogg, age 49, was elected a director of the General Partner in
October 1997. Mr. Mogg is president and chief executive officer of Duke Energy
Field Services, Inc. Mr. Mogg was previously president of Centana Energy
Corporation and senior vice president for Panhandle Eastern Pipe Line Company.
Mr. Mogg joined Panhandle Eastern Pipe Line Company in 1973.
Ruth G. Shaw, age 50, was elected a director of the General Partner in
December 1997. Ms. Shaw is executive vice president and chief administrative
officer of Duke Energy. Ms. Shaw joined Duke Energy in 1992 as vice president
of corporate communications. In April 1994, she was elected senior vice
president, corporate resources and chief administrative officer. Ms. Shaw is a
director of First Union Corp. and Apple South, Inc.
Carl D. Clay, age 65, is a director of the General Partner and a
member of the Compensation and Audit Committees. He was elected in January
1995. Mr. Clay retired from Marathon Oil Company in 1994 after 33 years during
which he served as director of transportation and logistics and president of
Marathon Pipe Line Company.
Derrill Cody, age 59, is a director of the General Partner having been
elected in 1989. He is the Chairman of the Audit Committee and serves on the
Compensation Committee of the General Partner. Mr. Cody is presently of counsel
to McKinney, Stringer & Webster, P.C., which represents PanEnergy in certain
matters. He is also an advisor to PanEnergy pursuant to a personal contract.
Mr. Cody served as Chief Executive Officer of Texas Eastern Gas Pipeline
Company from 1987 to 1989. Mr. Cody is also a director of Barrett Resources
Corporation.
John P. DesBarres, age 58, is a director of the General Partner,
having been elected in May 1995. He is a member of the Compensation and Audit
Committees. Mr. DesBarres was formerly chairman, president and chief executive
officer of Transco Energy Company from 1992 to 1995. He joined Transco in 1991
as president and chief executive officer. Prior to joining Transco, Mr.
DesBarres served as chairman, president and chief executive officer for Santa
Fe Pacific Pipelines, Inc. from 1988 to 1991.
Milton Carroll, age 48, was elected a director of the General Partner
in November 1997 and is a member of the Compensation and Audit Committees. Mr.
Carroll founded and has been president and chief executive officer of
Instrument Products, Inc., a manufacturer of oil field tools and other
precision products, since 1977. Mr. Carroll is a director of Houston
Industries, Inc., Seagull Energy Corp., and Blue Cross Blue Shield of Texas.
Charles H. Leonard, age 49, is Senior Vice President, Chief Financial
Officer and Treasurer of the General Partner. Mr. Leonard joined the Company in
1988 as Vice President and Controller. In November 1989, he was elected Vice
President and Chief Financial Officer. He was elected Senior Vice President in
March 1990, and Treasurer in October 1996.
James C. Ruth, age 50, is Vice President and General Counsel of the
General Partner, having been elected in 1991. He also serves as Assistant
Secretary, having been elected in 1992. Mr. Ruth was Vice President and
Assistant General Counsel of the General Partner from 1989 to 1991.
Thomas R. Harper, age 57, is Vice President, Product Transportation
and Refined Products Marketing of the General Partner. Mr. Harper joined the
Company in 1987 as Director of Product Transportation, and was elected to his
present position in 1988.
19
<PAGE> 22
David L. Langley, age 50, is Vice President, Business Development and
LPG Services of the General Partner. Mr. Langley has been with the Company in
various managerial positions since 1975 and was elected Vice President, LPG
Business Center, in 1988. He was elected to his current position in 1990.
O. Horton Cunningham, age 49, is Vice President, Technical Services,
of the General Partner, having been elected in October 1996. Mr. Cunningham
served as Vice President, Operations, from 1990 until October 1996. Mr.
Cunningham joined the Company in 1987 as Manager of Environmental Affairs and
was promoted to Director of Safety and Environmental Affairs in 1988 and
Director of Engineering and Compliance in 1989.
Ernest P. Hagan, age 53, is Vice President, Operations, of the General
Partner, having been elected in October 1996. Mr. Hagan was previously
Director of Engineering and Right-of-Way from 1994 until October 1996, and from
1986 until 1994 he was Region Manager of the Southwest Region. Mr. Hagan
joined the Company in 1971.
Based on information furnished to the Company and written
representation that no other reports were required, to the Company's knowledge,
all applicable Section 16(a) filing requirements were complied with during the
year ended December 31, 1997.
ITEM 11. EXECUTIVE COMPENSATION
The officers of the General Partner manage and operate the
Partnership's business. The Partnership does not directly employ any of the
persons responsible for managing or operating the Partnership's operations, but
instead reimburses the General Partner for the services of such persons.
Directors of the General Partner who are neither officers nor
employees of either the Company or Duke Energy receive a stipend of $15,000 per
annum, $750 for attendance at each meeting of the Board of Directors, $750 for
attendance at each meeting of a committee of the Board of Directors and
reimbursement of expenses incurred in connection with attendance at a meeting
of the Board of Directors or a committee of the Board of Directors. Each
outside director who serves as chairman of a committee of the Board of
Directors receives an additional stipend of $2,000 per annum.
Messrs. Thacker, Anderson, Hackett and Mogg and Ms. Shaw were not
compensated for their services as directors, and it is not anticipated that any
compensation for service as a director will be paid in the future to directors
who are full-time employees of Duke Energy, the General Partner or any of
their affiliates.
The following table reflects cash compensation paid or accrued by the
General Partner for the years ended December 31, 1997, 1996 and 1995, with
respect to its Chief Executive Officer and the executive officers
(collectively, the "Named Officers").
20
<PAGE> 23
SUMMARY COMPENSATION TABLE
<TABLE>
<CAPTION>
LONG TERM COMPENSATION
-----------------------------
AWARDS PAYOUTS
ANNUAL COMPENSATION OTHER ------------ -------------
---------------------------- ANNUAL SECURITIES LTICP AND ALL OTHER
NAME AND BONUS COMPENSATION UNDERLYING 1994 LTIP COMPENSATION
PRINCIPAL POSITION YEAR SALARY ($) ($) (1) ($) (2) OPTIONS (#)(3) PAYOUTS ($)(4) ($) (5)
------------------ ---- ---------- ------- ------- ------------- -------------- ------------
<S> <C> <C> <C> <C> <C> <C> <C>
William L. Thacker ......... 1997 237,708 98,200 78,551 4,400 358,168 21,529
Chairman, President and 1996 224,667 107,500 79,988 - 113,447 19,723
Chief Executive Officer 1995 216,667 108,200 61,319 - 71,000 19,291
Charles H. Leonard ......... 1997 145,750 52,000 29,985 - 25,444 12,960
Senior Vice President, 1996 142,958 54,800 35,691 - 16,094 12,780
Chief Financial Officer 1995 140,042 55,400 28,437 7,000 - 12,435
and Treasurer
James C. Ruth .............. 1997 134,333 46,000 39,276 - 27,901 14,968
Vice President and 1996 130,417 48,600 39,994 - 20,052 13,506
General Counsel 1995 126,742 48,400 30,659 7,000 - 13,326
O. Horton Cunningham ....... 1997 130,333 43,000 36,821 - 27,029 11,799
Vice President 1996 126,000 45,300 37,495 - 23,597 11,052
1995 121,450 46,000 28,743 7,000 - 10,555
David L. Langley ........... 1997 129,292 42,800 23,565 - 52,028 12,992
Vice President 1996 123,750 47,800 23,997 - 20,080 12,000
1995 119,508 46,500 18,396 7,000 - 11,759
Thomas R. Harper ........... 1997 129,083 43,000 23,565 - 33,533 15,243
Vice President 1996 123,125 46,500 23,997 - 14,370 13,339
1995 118,542 45,800 18,396 7,000 - 12,999
Ernest P. Hagan (6) ........ 1997 120,417 39,200 - 1,150 - 10,769
Vice President 1996 29,375 6,525 - - - 2,257
1995 - - - - - -
</TABLE>
- --------------
(1) Amounts represent bonuses accrued during the year under the Management
Incentive Compensation Plan ("MICP"). Payments under the MICP were
made in the subsequent year.
(2) Amounts shown for 1997, 1996 and 1995 are for quarterly distribution
equivalents under the terms of the Company's Long Term Incentive
Compensation Plan ("LTICP").
(3) Amounts represent awards pursuant to the Texas Eastern Products
Pipeline Company 1994 Long Term Incentive Plan ("1994 LTIP"). See
"Compensation Pursuant to General Partner Plans" for further
discussion of the 1994 LTIP.
(4) Amounts represent the value of redemptions under the 1995 amendment to
the LTICP and credits earned to Performance Unit accounts and options
exercised under the terms of 1994 LTIP. Also, for Mr. Thacker in
1997, 1996 and 1995, amounts include crediting of phantom units
awarded in a prior year under the terms of the LTICP.
(5) Includes amounts contributed by the Company for the Named Officers
under the Employees' Savings Plan of PanEnergy ("ESP") and under the
PanEnergy Key Executive Deferred Compensation Plan, an
21
<PAGE> 24
unfunded, defined contribution plan that allows eligible employees to
elect deferral of base salary and bonus, and receive matching Company
contributions, whenever and to the extent that their participation in
the ESP is limited by provisions of the Internal Revenue Code, and the
imputed value of premiums paid by the Company for insurance on the
Named Officers' lives.
(6) Mr. Hagan was named Vice President, Operations, effective October 1,
1996. Amounts for 1996 represent compensation for the period October
1, 1996, through December 31, 1996.
EXECUTIVE EMPLOYMENT CONTRACTS AND TERMINATION OF EMPLOYMENT ARRANGEMENTS
On September 1, 1992, William L. Thacker, Jr. and the Company entered
into an employment agreement, which set a minimum base salary of $190,000 per
year. The Company may terminate the employment agreement for cause, death or
disability. In addition, the Company or Mr. Thacker may terminate the agreement
upon written notice. Additionally, the Company granted 8,000 phantom units with
distribution equivalents to Mr. Thacker pursuant to the LTICP discussed below.
Mr. Thacker participates in other Company sponsored benefit plans on the same
basis as other senior executives of the Company.
COMPENSATION PURSUANT TO GENERAL PARTNER PLANS
Management Incentive Compensation Plan
The General Partner has established the MICP, which provides for the
payment of additional cash compensation to participants if certain Partnership
performance and personal objectives are met each year. The Compensation
Committee (the "Committee") determines at the beginning of each year which
employees are eligible to become participants in the MICP. Each participant is
assigned a target award by the Committee. Such target award determines the
additional compensation to be paid if all Partnership performance and personal
objectives are met and all Minimum Quarterly Distributions have been made for
the year. The amount of the awards may range from 10% to 56% of a participant's
base salary. Awards are paid as soon as practicable following approval by the
Committee after the close of a year.
Long Term Incentive Compensation Plan
The LTICP provides key employees with an incentive award based upon
the grant of phantom units. The LTICP is administered by the Committee, which
has sole and absolute discretion to determine the amount of an award. The
credit of phantom units under the terms of the LTICP is contingent upon all
cash distributions being made to the Unitholders and the General Partner. The
Committee may also establish performance targets for crediting of phantom
units. The award consists of phantom units with a total market value, as of the
date of the award, that may not exceed 100% of the base salary of a
participant. The phantom units are credited to each participant at the rate of
10% per year beginning on the first anniversary date of the award. A final
credit of 60% of the phantom units awarded will occur on the fifth anniversary
date of the award. The phantom units may be redeemed by a participant at any
time following credit to a participant in accordance with terms and conditions
prescribed by the Committee. The redemption price of the phantom units is based
on the market value of a Unit as of the date of redemption. In the event of a
change of control, all phantom units awarded to a participant will be redeemed.
Each participant also receives a quarterly distribution equivalent in cash
based upon a percentage of the distributions to the General Partner for such
quarter. In 1995, the LTICP was amended to require annual redemptions,
effective January 1, 1996, of 20% of the phantom units previously credited to
each participant. See Item 13, "Certain Relationships and Related
Transactions."
1994 Long Term Incentive Plan
The 1994 LTIP provides key employees with an incentive award whereby a
participant is granted an option to purchase Units together with a stipulated
number of Performance Units. Each Performance Unit creates a credit
22
<PAGE> 25
to a participant's Performance Unit account when earnings exceed a threshold,
which was $2.00, $2.50 and $3.75 per Limited Partner Unit for the awards made
in 1994, 1995, and 1997, respectively. No awards were granted during 1996.
When earnings for a calendar year (exclusive of certain special items) exceed
the threshold, the excess amount is credited to the participant's Performance
Unit account. The balance in the account may be used to exercise Unit options
granted in connection with the Performance Units or may be withdrawn two years
after the underlying options expire, usually 10 years from the date of grant.
Under the agreement for such Unit options, the options become exercisable in
equal installments over periods of one, two, and three years from the date of
the grant. Options may also be exercised by normal means once vesting
requirements are met.
The following table provides information concerning the unit options
exercised by each of the Named Executive Officers during 1997 and the value of
unexercised unit options to the Named Executive Officers as of December 31,
1997. The value assigned to each unexercised, "in the money" option is based
on the positive spread between the exercise price of such option and the fair
market value of a Unit on December 31, 1997. The fair market value is the
average of the high and low prices of a Unit on that date as reported in The
Wall Street Journal. In assessing the value, it should be kept in mind that no
matter what theoretical value is placed on an option on a particular date, its
ultimate value will be dependent on the market value of the Partnership's Unit
price at a future date. The future value will depend in part on the efforts of
the Named Executive Officers to foster the future success of the Partnership
for the benefit of all Unitholders.
AGGREGATED OPTIONS/SAR EXERCISES IN LAST FISCAL YEAR AND
FY-END OPTION/SAR VALUES
<TABLE>
<CAPTION>
VALUE OF
UNEXERCISED
NUMBER OF SECURITIES IN-THE MONEY
UNDERLYING UNEXERCISED OPTIONS/SARS
SHARES OPTIONS/SARS AT FY-END AT FY-END ($)
ACQUIRED ON VALUE (#) EXERCISABLE/ EXERCISABLE/
NAME EXERCISE (#) REALIZED($) UNEXERCISABLE (1) UNEXERCISABLE
- ---- ------------ ----------- ----------------- -------------
<S> <C> <C> <C> <C>
Mr. Thacker (2)(4) ....... 2,469 $36,139 12,279/4,400 $292,010/$40,288
Mr. Leonard (3) .......... -- -- 4,414/2,333 $109,660/$57,960
Mr. Ruth (3) ............. 322 $5,055 3,817/2,333 $94,829/$57,960
Mr. Cunningham (3) ....... 322 $5,055 3,280/2,333 $81,488/$57,960
Mr. Langley (3) .......... 2,000 $34,672 1,667/2,333 $41,415/$57,960
Mr. Harper (3) ........... 822 $16,268 3,592/2,333 $89,239/$57,960
Mr. Hagan (4) ........... -- -- 0/1,150 $0/$10,530
</TABLE>
- -----------------
(1) Future exercisability of currently unexercisable options depends on
the grantee remaining employed by the Company throughout the vesting
period of the options, subject to provisions applicable at retirement,
death, or total disability.
(2) On January 17, 1994, Mr. Thacker was granted options to purchase
20,000 Units under the terms of the 1994 LTIP at an exercise price of
$28.6875 per Unit, which was the fair market value of a Unit on the
date of grant. Mr. Thacker also received 40,000 Performance Units
(see discussion above).
(3) On January 16, 1995, Messrs. Leonard, Ruth, Cunningham, Langley and
Harper were each granted options to purchase 7,000 Units under the
terms of the 1994 LTIP at an exercise price of $27.625 per Unit, which
was the fair market value of a Unit on the date of grant. Messrs.
Leonard, Ruth, Cunningham, Langley and Harper also received 7,000
Performance Units (see discussion above).
(4) On January 17, 1997, Mr. Thacker and Mr. Hagan were each granted
options to purchase 4,400 Units and 1,150 Units, respectively, under
the terms of the 1994 LTIP at an exercise price of $43.3125 per Unit,
23
<PAGE> 26
which was the fair market value of a Unit on the date of grant. Mr.
Thacker and Mr. Hagan also received 4,400 Performance Units and 1,150
Performance Units, respectively (see discussion above).
1997 Employee Incentive Compensation Plan
The General Partner has adopted the 1997 Employee Incentive
Compensation Plan ("1997 EICP"), which provides an award of shadow units to all
employees who are not eligible to participate in the MICP. The 1997 EICP is
administered by the Committee, which maintains an incentive award account for
each participant. Each participant is eligible for an annual award of up to
300 shadow units, depending on the level of earnings achieved by the
Partnership each year, which generally entitles such participant to receive a
credit equal to the quarterly distribution that such participant would have
received had the participant been the owner of Units. The Committee may add a
premium from 10% to 30% to the credit if certain safety and operational goals
are attained. Payment of the credits is contingent upon the participant
remaining in the employment of the General Partner during the year in which the
shadow units are outstanding. Awards to participants are paid in cash
following the close of each year in an amount equal to the credits in the
participant's incentive award account with respect to such year.
PENSION PLAN
Officers of the Company are participants in the PanEnergy Corp
Retirement Plan ("PanEnergy Retirement Plan"). The PanEnergy Retirement Plan
provides benefits expressed in the form of a single life annuity commencing at
normal retirement date (age 65 or, if later, the fifth anniversary of
participation in the PanEnergy Retirement Plan) based on a benefit formula
that, in part, uses final five-year average pay, which considers the regular
compensation of the participant, including overtime payments, bonus payments
and some other forms of deferred compensation.
Qualified retirement plan benefits may be subject to statutory
limitations if the participant receives compensation in excess of a maximum
amount, is covered by other qualified plans, if benefits are paid before social
security retirement age, if the participant has less than 10 years of plan
participation or if benefits are paid in a more valuable form than a single
life annuity. Benefits are not reduced by the amount of any social security
payments received by the participant. When qualified plan benefits are limited
by statute, non-qualified plans restore certain benefits for participants
covered by the non-qualified plans to a level which would have been available
if such statutory limits did not exist.
The table below shows the estimated annual benefits payable at age 65
under the qualified and non-qualified retirement plans at various levels of
final average compensation and assuming various years of benefit accrual
service (dollars in thousands):
<TABLE>
<CAPTION>
YEARS OF SERVICE
-----------------------------------------------------
15 20 25 30 35
---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C>
$175 ...................... $ 40 $ 53 $ 67 $ 80 $ 93
200 ...................... 46 61 77 92 107
225 ...................... 52 69 87 104 121
250 ...................... 58 77 97 116 135
300 ...................... 70 93 117 140 163
400 ...................... 94 125 157 188 219
</TABLE>
The years of benefit accrual service for the Named Officers, are as
follows: William L. Thacker, 5; Charles H. Leonard, 9; James C. Ruth, 27; O.
Horton Cunningham, 10; David L. Langley, 27; Thomas Harper, 10; and Ernest P.
Hagan, 27. The covered compensation is the sum of the salary from the current
year and bonus from the previous year reported in the Summary Compensation
Table on page 21.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
(a) Security Ownership of Certain Beneficial Owners
24
<PAGE> 27
The Company owns 1,250,000 Units, representing 8.62% of the Units
outstanding as of February 24, 1998 (an effective 8.45% limited partner
interest in the Partnership).
(b) Security Ownership of Management
The following table sets forth certain information, as of February 24,
1998, concerning the beneficial ownership of Units by each director and Named
Officers of the General Partner and by all directors and officers of the
General Partner as a group. Such information is based on data furnished by the
persons named. Based on information furnished to the General Partner by such
persons, no director or officer of the General Partner owned beneficially, as
of February 24, 1998, more than 1% of the Units outstanding at that date.
<TABLE>
<CAPTION>
NUMBER OF
NAME UNITS (1)
---- ---------
<S> <C>
Paul M. Anderson ......................................................................... 2,000
Milton Carroll ........................................................................... --
Carl D. Clay (2) ......................................................................... 1,600
Derrill Cody ............................................................................. 7,000
John P. DesBarres ........................................................................ 10,000
James T. Hackett ......................................................................... --
Jim W. Mogg .............................................................................. 100
Ruth G. Shaw ............................................................................. --
William L. Thacker ....................................................................... 11,870
Charles H. Leonard ....................................................................... 1,703
James C. Ruth ............................................................................ 1,304
O. Horton Cunningham (3) ................................................................. 3,444
David L. Langley ......................................................................... 10,000
Thomas R. Harper (4) ..................................................................... 2,100
Ernest P. Hagan .......................................................................... 6,000
All directors and officers (consisting of 18 people, including those named above) ........ 57,221
</TABLE>
- ------------------
(1) Unless otherwise indicated, the persons named above have sole voting
and investment power over the Units reported.
(2) Includes 900 Units in wife's name.
(3) Includes 100 Units in daughter's name.
(4) Includes 1,075 Units in wife's name.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The Partnership is managed and controlled by the General Partner
pursuant to the Partnership Agreements. Under the Partnership Agreements, the
General Partner is reimbursed for all direct and indirect expenses it incurs or
payments it makes on behalf of the Partnership. These expenses include
salaries, fees and other compensation and benefit expenses of employees,
officers and directors, insurance, data processing, other administrative or
overhead expenses and all other expenses necessary or appropriate to conduct
the Partnership's business. The costs allocated to the Partnership by the
General Partner for administrative services and overhead totaled $2.7 million
in 1997.
The Partnership Agreements provide for incentive distributions payable
to the General Partner out of the Partnership's Available Cash (as defined in
the Partnership Agreements) in the event quarterly distributions to Unitholders
exceed certain specified targets. In general, subject to certain limitations,
if a quarterly distribution
25
<PAGE> 28
exceeds a target of $0.55 per Unit, the General Partner will receive incentive
distributions equal to (i) 15% of that portion of the distribution per Unit
which exceeds the minimum quarterly distribution amount of $0.55 but is not
more than $0.65, plus (ii) 25% of that portion of the quarterly distribution
per Unit which exceeds $0.65 but is not more than $0.90, plus (iii) 50% of that
portion of the quarterly distribution per Unit which exceeds $0.90. During
1997, incentive distributions paid to the General Partner totaled $3.2 million.
In connection with the formation of the Partnership in 1990, the
Company received 1,250,000 Deferred Partnership Interests ("DPIs"), which
represent an effective 8.45% limited partner interest in the Partnership.
Effective April 1, 1994, the DPIs began participating in distributions of cash
and allocations of profit and loss. As of December 31, 1997, 94% of the DPIs
have been converted into an equal number of Units, and the balance of such DPIs
may be converted immediately prior to the sale of the DPIs by the Company.
Pursuant to its Partnership Agreement, the Partnership has registered the
resale of such Units with the Securities and Exchange Commission. Such Units
may be sold from time to time on the New York Stock Exchange or otherwise at
prices and terms then prevailing or in negotiated transactions. As of December
31, 1997, no such Units had been sold by the Company.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) The following documents are filed as a part of this Report:
(1) Financial Statements: See Index to Financial Statements on
page F-1 of this report for financial statements filed as
part of this report.
(2) Financial Statement Schedules: None
(3) Exhibits.
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------ -----------
<S> <C>
3.1 Certificate of Limited Partnership of the Partnership
(Filed as Exhibit 3.2 to the Partnership's Registration
Statement (Commission File No. 33-32203) and incorporated
herein by reference).
4.1 Form of Certificate representing Units (Filed as Exhibit
4.1 to the Partnership's Registration Statement (Commission
File No. 33-32203) and incorporated herein by reference).
4.2 Agreement of Limited Partnership of TEPPCO Partners, L.P.,
dated March 7, 1990 (Filed as Exhibit 4(a) to Form 10-Q of
TEPPCO Partners, L.P. (Commission File No. 1-10403) for the
quarter ended March 31, 1990 and incorporated herein by
reference).
4.3 Note Agreement, 9.60% Series A and 10.20% Series B First
Mortgage Notes, dated February 28, 1990 (Filed as Exhibit
4(b) to Form 10-Q of TEPPCO Partners, L.P. (Commission File
No. 1-10403) for the quarter ended March 31, 1990 and
incorporated herein by reference).
4.4 Amendment to Note Agreement, dated June 1, 1994, 9.60%
Series A and 10.20% Series B First Mortgage Notes (Filed as
Exhibit 4 to Form 10-Q of TEPPCO Partners, L.P. (Commission
File No. 1-10403) for the quarter ended June 30, 1994 and
incorporated herein by reference).
4.5 Amendment to Note Agreement, dated February 24, 1995, 9.60%
Series A and 10.20% Series B First Mortgage Notes (Filed as
Exhibit 4.5 to Form 10-K of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the year ended December
31, 1994 and incorporated herein by reference).
</TABLE>
26
<PAGE> 29
<TABLE>
<S> <C>
4.6 Form of Indenture between TE Products Pipeline Company,
Limited Partnership and The Bank of New York, as Trustee,
dated as of January 27, 1998 (Filed as Exhibit 4.3 to TE
Products Pipeline Company, Limited Partnership's
Registration Statement on Form S-3 (Commission File No.
333-38473) and incorporated herein by reference).
10.1 Agreement of Limited Partnership of TE Products Pipeline
Company, Limited Partnership, dated March 7, 1990 (Filed as
Exhibit 28 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the quarter ended March
31, 1990 and incorporated herein by reference).
10.2 Assignment and Assumption Agreement, dated March 24, 1988,
between Texas Eastern Transmission Corporation and the
Company (Filed as Exhibit 10.8 to the Partnership's
Registration Statement (Commission File No. 33-32203) and
incorporated herein by reference).
10.3 Texas Eastern Products Pipeline Company 1997 Employee
Incentive Compensation Plan executed on July 14, 1997
(Filed as Exhibit 10 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File 1-10403) for the quarter ended September
30, 1997 and incorporated herein by reference).
10.4 Agreement Regarding Environmental Indemnities and Certain
Assets (Filed as Exhibit 10.5 to the Partnership's Form
10-K (Commission File No. 1-10403) for the year ended
December 31, 1990 and incorporated herein by reference).
10.5 Texas Eastern Products Pipeline Company Management
Incentive Compensation Plan executed on January 30, 1992
(Filed as Exhibit 10 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the quarter ended March
31, 1992 and incorporated herein by reference).
10.6 Texas Eastern Products Pipeline Company Long-Term Incentive
Compensation Plan executed on October 31, 1990 (Filed as
Exhibit 10.9 to the Partnership's Form 10-K (Commission
File No. 1-10403) for the year ended December 31, 1990 and
incorporated herein by reference).
10.7 Form of Amendment to Texas Eastern Products Pipeline
Company Long-Term Incentive Compensation Plan (Filed as
Exhibit 10.7 to the Partnership's Form 10-K (Commission
File No. 1-10403) for the year ended December 31, 1995 and
incorporated herein by reference).
10.8 Employees' Savings Plan of Panhandle Eastern Corporation
and Participating Affiliates (Effective January 1, 1991)
(Filed as Exhibit 10.10 to the Partnership's Form 10-K
(Commission File No. 1-10403) for the year ended December
31, 1990 and incorporated herein by reference).
10.9 Retirement Income Plan of Panhandle Eastern Corporation and
Participating Affiliates (Effective January 1, 1991) (Filed
as Exhibit 10.11 to the Partnership's Form 10-K (Commission
File No. 1-10403) for the year ended December 31, 1990 and
incorporated herein by reference).
10.10 Panhandle Eastern Corporation -- Executive Benefit
Equalization Plan as amended November 29, 1989; effective
January 1, 1990 (Filed as Exhibit 10.05 to Form 10-K of
Panhandle (Commission File No. 1-8157) for the year ended
December 31, 1989 and incorporated herein by reference).
10.11 Employment Agreement with William L. Thacker, Jr. (Filed as
Exhibit 10 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the quarter ended
September 30, 1992 and incorporated herein by reference).
10.12 Texas Eastern Products Pipeline Company 1994 Long Term
Incentive Plan executed on March 8, 1994 (Filed as Exhibit
10.1 to Form 10-Q of TEPPCO Partners, L.P. (Commission File
No. 1-10403) for the quarter ended March 31, 1994 and
incorporated herein by reference).
10.13 Panhandle Eastern Corporation Key Executive Deferred
Compensation Plan established effective January 1, 1994
(Filed as Exhibit 10.2 to Form 10-Q of TEPPCO Partners,
L.P.
</TABLE>
27
<PAGE> 30
<TABLE>
<S> <C>
(Commission File No. 1-10403) for the quarter ended March 31,
1994 and incorporated herein by reference).
22.1 Subsidiaries of the Partnership (Filed as Exhibit 22.1 to
the Partnership's Registration Statement (Commission File
No. 33-32203) and incorporated herein by reference).
*23 Consent of KPMG Peat Marwick LLP.
*24 Powers of Attorney.
*27 Financial Data Schedule as of and for the year ended
December 31, 1997.
</TABLE>
- ----------------
* Filed herewith.
(b) Reports on Form 8-K filed during the quarter ended December 31,
1997:
The Partnership filed a report on Form 8-K on December 22, 1997
under Item 5, Other Events.
28
<PAGE> 31
SIGNATURES
TEPPCO Partners, L.P., pursuant to the requirements of Section 13 or
15(d) of the Securities Exchange Act of 1934, has duly caused this report to be
signed on its behalf by the undersigned, thereunto duly authorized.
TEPPCO Partners, L.P.
------------------------------------
(Registrant)
(A Delaware Limited Partnership)
By: Texas Eastern Products Pipeline
Company as General Partner
By: CHARLES H. LEONARD
---------------------------------
Charles H. Leonard,
Senior Vice President, Chief
Financial Officer and Treasurer
DATED: March 3, 1998
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 date indicated.
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
--------- ----- ----
<C> <C> <C>
WILLIAM L. THACKER* Chairman of the Board, President and Chief Executive March 3, 1998
- ----------------------------------- Officer of Texas Eastern Products Pipeline Company
William L. Thacker
CHARLES H. LEONARD Senior Vice President, Chief Financial Officer and March 3, 1998
- ----------------------------------- Treasurer of Texas Eastern Products Pipeline Company
Charles H. Leonard (Principal Accounting and Financial Officer)
PAUL M. ANDERSON* Vice Chairman of the Board of Texas March 3, 1998
- ----------------------------------- Eastern Products Pipeline Company
Paul M. Anderson
MILTON CARROLL* Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
Milton Carroll
CARL D. CLAY* Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
Carl D. Clay
DERRILL CODY* Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
Derrill Cody
JOHN P. DESBARRES* Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
John P. DesBarres
JAMES T. HACKETT* Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
James T. Hackett
JIM W. MOGG * Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
Jim W. Mogg
RUTH G. SHAW* Director of Texas Eastern March 3, 1998
- ----------------------------------- Products Pipeline Company
Ruth G. Shaw
* Signed on behalf of the Registrant and each of these persons:
By: CHARLES H. LEONARD
--------------------------------------
(Charles H. Leonard, Attorney-in-Fact)
</TABLE>
29
<PAGE> 32
CONSOLIDATED FINANCIAL STATEMENTS
OF TEPPCO PARTNERS, L.P.
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Independent Auditors' Report ............................................................................ F-2
Consolidated Balance Sheets as of December 31, 1997 and 1996 ............................................ F-3
Consolidated Statements of Income for the years ended December 31, 1997, 1996 and 1995 .................. F-4
Consolidated Statements of Cash Flows for the years ended December 31, 1997, 1996 and 1995 .............. F-5
Consolidated Statements of Partners' Capital for the years ended December 31, 1997,
1996 and 1995 ........................................................................................ F-6
Notes to Consolidated Financial Statements .............................................................. F-7
</TABLE>
F-1
<PAGE> 33
INDEPENDENT AUDITORS' REPORT
To the Partners of
TEPPCO Partners, L.P.:
We have audited the accompanying consolidated balance sheets of TEPPCO
Partners, L.P. as of December 31, 1997 and 1996, and the related consolidated
statements of income, partners' capital, and cash flows for each of the years in
the three-year period ended December 31, 1997. These consolidated financial
statements are the responsibility of the Partnership's management. Our
responsibility is to express an opinion on these consolidated 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 consolidated financial statements referred to above
present fairly, in all material respects, the financial position of TEPPCO
Partners, L.P. as of December 31, 1997 and 1996, and the results of their
operations and their cash flows for each of the years in the three-year period
ended December 31, 1997 in conformity with generally accepted accounting
principles.
KPMG PEAT MARWICK LLP
Houston, Texas
January 16, 1998, except as to Note 7,
which is as of January 27, 1998
F-2
<PAGE> 34
TEPPCO PARTNERS, L.P.
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------
1997 1996
-------- --------
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents ............................................... $ 43,961 $ 34,047
Short-term investments .................................................. 2,105 24,085
Accounts receivable, trade .............................................. 19,826 18,326
Inventories ............................................................. 21,094 18,914
Other ................................................................... 4,173 3,371
-------- --------
Total current assets ............................................ 91,159 98,743
-------- --------
Property, plant and equipment, at cost (Net of accumulated depreciation
and amortization of $170,063 and $149,597) .............................. 567,681 561,068
Investments ................................................................ 10,010 6,936
Other assets ............................................................... 5,059 4,494
-------- --------
Total assets .................................................... $673,909 $671,241
======== ========
LIABILITIES AND PARTNERS' CAPITAL
Current liabilities:
Current maturities, First Mortgage Notes ................................ $ 17,000 $ 13,000
Accounts payable and accrued liabilities ................................ 9,615 8,300
Accounts payable, general partner ....................................... 3,735 3,007
Accrued interest ........................................................ 10,539 10,930
Other accrued taxes ..................................................... 6,246 5,455
Other ................................................................... 6,740 6,861
-------- --------
Total current liabilities ....................................... 53,875 47,553
-------- --------
First Mortgage Notes ....................................................... 309,512 326,512
Other liabilities and deferred credits ..................................... 4,462 3,902
Minority interest .......................................................... 3,093 2,963
Partners' capital:
General partner's interest .............................................. 5,760 4,616
Limited partners' interests ............................................. 297,207 285,695
-------- --------
Total partners' capital ......................................... 302,967 290,311
-------- --------
Commitments and contingencies
Total liabilities and partners' capital ......................... $673,909 $671,241
======== ========
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
F-3
<PAGE> 35
TEPPCO PARTNERS, L.P.
CONSOLIDATED STATEMENTS OF INCOME
(IN THOUSANDS, EXCEPT PER LIMITED PARTNER UNIT AMOUNTS)
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
---------------------------------------
1997 1996 1995
--------- --------- ---------
<S> <C> <C> <C>
Operating revenues:
Transportation -- Refined products ..................... $ 107,304 $ 98,641 $ 96,190
Transportation -- LPGs ................................. 79,371 80,219 70,576
Gain on sale of inventory .............................. 2,261 3,674 4,115
Mont Belvieu operations ................................ 12,815 11,811 13,570
Other .................................................. 20,342 21,680 19,265
--------- --------- ---------
Total operating revenues ....................... 222,093 216,025 203,716
--------- --------- ---------
Costs and expenses:
Operating, general and administrative .................. 97,133 96,541 96,419
Depreciation and amortization .......................... 23,772 23,409 23,286
Taxes -- other than income taxes ....................... 9,638 8,641 7,519
--------- --------- ---------
Total costs and expenses ....................... 130,543 128,591 127,224
--------- --------- ---------
Operating income ............................... 91,550 87,434 76,492
Interest expense, First Mortgage Notes ................. (33,707) (34,922) (35,844)
Interest capitalized ................................... 1,478 1,388 857
Other income -- net .................................... 2,604 5,346 5,689
--------- --------- ---------
Income before minority interest ................ 61,925 59,246 47,194
Minority interest ......................................... (625) (598) (477)
--------- --------- ---------
Net income ..................................... $ 61,300 $ 58,648 $ 46,717
========= ========= =========
Basic net income per Limited Partner Unit ...... $ 3.90 $ 3.79 $ 3.08
========= ========= =========
Diluted net income per Limited Partner Unit .... $ 3.90 $ 3.78 $ 3.07
========= ========= =========
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
F-4
<PAGE> 36
TEPPCO PARTNERS, L.P.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
---------------------------------------
1997 1996 1995
--------- --------- ---------
<S> <C> <C> <C>
Cash flows from operating activities:
Net income ....................................................... $ 61,300 $ 58,648 $ 46,717
Adjustments to reconcile net income to cash provided by
operating activities:
Depreciation and amortization ................................. 23,772 23,409 23,286
Decrease (increase) in accounts receivable .................... (1,500) 1,705 (2,051)
Decrease (increase) in inventories ............................ (2,180) 3,997 5,483
Increase in other current assets .............................. (802) (226) (878)
Increase (decrease) in accounts payable and accrued expenses .. 2,322 (3,478) 4,276
Other ......................................................... 692 2,066 1,623
--------- --------- ---------
Net cash provided by operating activities ................ 83,604 86,121 78,456
--------- --------- ---------
Cash flows from investing activities:
Proceeds from investments ........................................ 25,040 18,584 68,963
Purchases of investments ......................................... (6,180) (14,436) (62,436)
Insurance proceeds related to damaged assets ..................... 1,046 -- 9,750
Restricted investments designated for property additions ......... -- 10,553 (10,328)
Proceeds from the sale of property, plant and equipment .......... 1,377 -- --
Capital expenditures ............................................. (32,931) (51,264) (25,967)
--------- --------- ---------
Net cash used in investing activities .................... (11,648) (36,563) (20,018)
--------- --------- ---------
Cash flows from financing activities:
Principal payment, First Mortgage Notes .......................... (13,000) (10,000) (7,000)
Distributions .................................................... (49,042) (45,174) (40,342)
--------- --------- ---------
Net cash used in financing activities .................... (62,042) (55,174) (47,342)
--------- --------- ---------
Net increase (decrease) in cash and cash equivalents ................ 9,914 (5,616) 11,096
Cash and cash equivalents at beginning of year ...................... 34,047 39,663 28,567
--------- --------- ---------
Cash and cash equivalents at end of year ............................ $ 43,961 $ 34,047 $ 39,663
========= ========= =========
Supplemental disclosure of cash flows:
Interest paid during the year (net of capitalized interest) ...... $ 32,084 $ 33,278 $ 34,625
========= ========= =========
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
F-5
<PAGE> 37
TEPPCO PARTNERS, L.P.
CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL
(IN THOUSANDS)
<TABLE>
<CAPTION>
GENERAL LIMITED
PARTNER'S PARTNERS'
INTEREST INTERESTS TOTAL
--------- --------- ---------
<S> <C> <C> <C>
Partners' capital at December 31, 1994 ... $ 2,953 $ 266,646 $ 269,599
1995 net income allocation ........... 2,118 44,599 46,717
1995 cash distributions .............. (1,510) (38,425) (39,935)
--------- --------- ---------
Partners' capital at December 31, 1995 ... 3,561 272,820 276,381
1996 net income allocation ........... 3,723 54,925 58,648
1996 cash distributions .............. (2,668) (42,050) (44,718)
--------- --------- ---------
Partners' capital at December 31, 1996 ... 4,616 285,695 290,311
1997 net income allocation ........... 4,740 56,560 61,300
1997 cash distributions .............. (3,596) (44,951) (48,547)
Other ................................ -- (97) (97)
--------- --------- ---------
Partners' capital at December 31, 1997 ... $ 5,760 $ 297,207 $ 302,967
========= ========= =========
</TABLE>
See accompanying Notes to Consolidated Financial Statements.
F-6
<PAGE> 38
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1. PARTNERSHIP ORGANIZATION
TEPPCO Partners, L.P. is a Delaware limited partnership which operates
through TE Products Pipeline Company, Limited Partnership, a Delaware limited
partnership (collectively the "Partnership"), in which TEPPCO Partners, L.P.
holds a 99% interest as the sole limited partner. Texas Eastern Products
Pipeline Company (the "Company"), is the general partner of the Partnership and
has agreed not to voluntarily withdraw as the general partner of the
Partnership, subject to certain limited exceptions, prior to January 1, 2000. On
June 18, 1997, PanEnergy Corp and Duke Power Company completed a previously
announced merger. At closing, the combined companies became Duke Energy
Corporation ("Duke Energy"). The Company, previously a wholly-owned subsidiary
of PanEnergy Corp became an indirect wholly-owned subsidiary of Duke Energy on
the date of the merger.
The Company, as general partner, performs all management and operating
functions required for the Partnership pursuant to the Agreements of Limited
Partnership of TEPPCO Partners, L.P. and TE Products Pipeline Company, Limited
Partnership (the "Partnership Agreements"). The general partner is reimbursed by
the Partnership for all reasonable direct and indirect expenses incurred in
managing the Partnership.
During 1990, the Partnership completed an initial public offering of
13,250,000 Units representing Limited Partner Interests ("Units") at $20 per
Unit. In connection with the formation of the Partnership, the Company received
1,250,000 Deferred Participation Interests ("DPIs"), which represent an
effective 8.45% limited partner interest in the Partnership. Effective April 1,
1994, the DPIs began participating in distributions of cash and allocations of
profit and loss. As of December 31, 1997, 94% of the DPIs have been converted
into an equal number of Units, and the balance of such DPIs may be converted
immediately prior to the sale of the DPIs by the Company. Pursuant to its
Partnership Agreement, the Partnership has registered the resale of such Units
with the Securities and Exchange Commission. Such Units may be sold from time to
time on the New York Stock Exchange or otherwise at prices and terms then
prevailing or in negotiated transactions. As of December 31, 1997, no such Units
had been sold by the Company.
NOTE 2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
BASIS OF PRESENTATION
The financial statements include the accounts of the Partnership on a
consolidated basis. The Company's 1% general partner interest in TE Products
Pipeline Company, Limited Partnership, is accounted for as a minority interest.
All significant intercompany items have been eliminated in consolidation.
Certain amounts from prior years have been reclassified to conform to current
presentation.
ACCOUNTING POLICY CHANGES
Effective January 1, 1996, the Partnership adopted Statement of
Financial Accounting Standards ("SFAS") 121, "Accounting for the Impairment of
Long-Lived Assets and for Long-Lived Assets to be Disposed of," with no impact
to the Partnership's consolidated financial statements. Assets were grouped and
evaluated based on the ability to identify their respective cash flows.
In October 1995, the Financial Accounting Standards Board ("FASB")
issued SFAS 123, "Accounting for Stock-Based Compensation." This standard allows
a company to adopt a fair value based method of accounting for its stock-based
compensation plans and addresses the timing and measurement of stock-based
compensation expense. The Partnership has elected to retain the approach of
Accounting Principles Board Opinion ("APB") No. 25, "Accounting for Stock issued
to Employees," (the intrinsic value method) for recognizing stock-based expense
F-7
<PAGE> 39
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
in the consolidated financial statements. The Partnership adopted SFAS 123 in
1996 with respect to the disclosure requirements set forth therein for companies
retaining the intrinsic value approach of APB No. 25 (see Note 10).
In December 1997, the Partnership adopted SFAS 128, "Earnings per
Share." This statement established standards for computing and presenting net
income per Limited Partner Unit and requires, among other things, dual
presentation of basic and diluted net income per Limited Partner Unit on the
face of the consolidated statements of income. The Partnership has restated net
income per Limited Partner Unit for the years ended December 31, 1996 and 1995
and included diluted net income per Limited Partner Unit.
In June 1997, the FASB issued SFAS 130, "Reporting Comprehensive
Income." This statement establishes standards for reporting and display of
comprehensive income and its components in a full set of financial statements.
In June 1997, the FASB also issued SFAS 131, "Disclosures about Segments of an
Enterprise and Related Information." This statement establishes standards for
reporting information about operating segments in annual financial statements
and requires that enterprises report selected information about operating
segments in interim reports issued to shareholders. The Partnership will adopt
these standards in 1998. As both SFAS 130 and 131 establish standards for
reporting and display, the Partnership does not expect the adoption of these
statements to have a material impact on its financial condition or results of
operations.
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.
ENVIRONMENTAL EXPENDITURES
The Partnership accrues for environmental costs that relate to existing
conditions caused by past operations. Environmental costs include initial site
surveys and environmental studies of potentially contaminated sites, costs for
remediation and restoration of sites determined to be contaminated and ongoing
monitoring costs, as well as fines, damages and other costs, when estimable. The
Partnership's accrued undiscounted environmental liabilities are monitored on a
regular basis by management. Liabilities for environmental costs at a specific
site are initially recorded when the Partnership's liability for such costs,
including direct internal and legal costs, is probable and a reasonable estimate
of the associated costs can be made. Adjustments to initial estimates are
recorded, from time to time, to reflect changing circumstances and estimates
based upon additional information developed in subsequent periods. Estimates of
the Partnership's ultimate liabilities associated with environmental costs are
particularly difficult to make with certainty due to the number of variables
involved, including the early stage of investigation at certain sites, the
lengthy time frames required to complete remediation alternatives available, the
uncertainty of potential recoveries from third parties and the evolving nature
of environmental laws and regulations.
BUSINESS SEGMENT
The Partnership has one business segment: the transportation, storage
and terminaling of refined petroleum products and liquefied petroleum gases
("LPGs"). Refined petroleum products and LPGs are referred to herein,
collectively, as "petroleum products" or "products." The Partnership's
interstate transportation operations, including rates charged to customers, are
subject to regulations prescribed by the Federal Energy Regulatory Commission
("FERC").
F-8
<PAGE> 40
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
REVENUE RECOGNITION
Substantially all revenues are derived from interstate and intrastate
transportation, storage and terminaling of petroleum products. Transportation
revenues are recognized as products are delivered to customers. Storage revenues
are recognized upon receipt of products into storage and upon performance of
storage services. Terminaling revenues are recognized as products are
out-loaded. Revenues from the sale of product inventory are recognized net of
product cost when the products are sold.
INVENTORIES
Inventories consist primarily of petroleum products and are valued at
the lower of cost (weighted average cost method) or market. The Partnership
acquires and disposes of various products under exchange agreements. Receivables
and payables arising from these transactions are usually satisfied with products
rather than cash. The net balances of exchange receivables and payables are
valued at weighted average cost and included in inventories.
The Partnership periodically enters into futures contracts to hedge its
exposure to price risk on product inventory transactions. Recognized gains and
losses related to futures contracts which qualify as hedges are recognized in
income when the related inventory transactions are completed. Gains and losses
related to futures contracts, which have been insignificant, are reported as a
component of product inventory in the consolidated balance sheet until
recognized as income. At December 31, 1997 and 1996, there were no outstanding
futures contracts.
PROPERTY, PLANT AND EQUIPMENT
Additions to property, plant and equipment, including major
replacements or betterments, are recorded at cost. Replacements and renewals of
minor items of property are charged to maintenance expense. Depreciation expense
is computed on the straight-line method using rates based upon expected useful
lives of various classes of assets (ranging from 2% to 20% per annum).
Upon sale or retirement of depreciable carrier properties, cost less
salvage is normally charged to accumulated depreciation, and no gain or loss is
recognized. During 1997, the Partnership recorded a loss of $0.5 million on the
sale of its Arkansas City, Arkansas, terminal. The Arkansas City terminal was
classified as a non-carrier facility.
CAPITALIZATION OF INTEREST
In connection with the construction of facilities regulated by the
FERC, interest is capitalized in accordance with a FERC-established method. The
rate used to capitalize interest on borrowed funds was 10.09%, 10.07% and 10.06%
for 1997, 1996 and 1995, respectively.
INCOME TAXES
The Partnership is a limited partnership. As a result, the
Partnership's income or loss for federal income tax purposes is included in the
tax return of the individual partners, and may vary substantially from income or
loss reported for financial reporting purposes. Accordingly, no recognition has
been given to federal income taxes for the Partnership's operations. At December
31, 1997 and 1996, the Partnership's reported amount of net assets for financial
reporting purposes exceeded its tax basis by approximately $223 million and $222
million, respectively.
F-9
<PAGE> 41
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
CASH FLOWS
For purposes of reporting cash flows, all liquid investments with
maturities at date of purchase of 90-days or less are considered cash
equivalents.
NET INCOME PER LIMITED PARTNER UNIT
Basic net income per Limited Partner Unit is computed by dividing net
income, after deduction of the general partner's interest, by the weighted
average number of Limited Partner Units outstanding (a total of 14.5 million
Units for 1997, 1996 and 1995). The general partner's percentage interest in net
income is based on its percentage of cash distributions from Available Cash for
each year (see Note 9). The general partner was allocated $4.7 million, $3.7
million and $2.1 million (representing 7.73%, 6.35% and 4.53%) of net income for
each of the years ended 1997, 1996 and 1995, respectively.
Diluted net income per Limited Partner Unit is similar to the
computation of basic net income per Limited Partner Unit above, except that the
denominator was increased to include the dilutive effect of outstanding Unit
options by application of the treasury stock method. For 1997, 1996 and 1995 the
denominator was increased by 19,560 Units, 14,228 Units and 5,724 Units,
respectively.
NOTE 3. RELATED PARTY TRANSACTIONS
The Partnership has no employees and is managed by the Company.
Pursuant to the Partnership Agreements, the Company is entitled to reimbursement
of all direct and indirect expenses related to business activities of the
Partnership (see Note 1).
For 1997, 1996 and 1995, direct expenses incurred by the general
partner in the amount of $38.2 million, $36.0 million and $34.0 million,
respectively, were charged to the Partnership. Substantially all such costs
related to payroll and payroll related expenses, which included $1.8 million,
$1.9 million and $1.8 million of expense for incentive compensation plans for
each of the years ended 1997, 1996 and 1995, respectively.
For 1997, 1996 and 1995, expenses for administrative service and
overhead allocated to the Partnership by the general partner (including Duke
Energy and its affiliates) amounted to $2.7 million, $2.6 million and $2.5
million, respectively. Such costs incurred by the general partner included
general and administrative costs related to business activities of the
Partnership.
NOTE 4. INVESTMENTS
SHORT-TERM INVESTMENTS
The Partnership routinely invests cash in liquid short-term investments
as part of its cash management program. Investments with maturities at date of
purchase of 90-days or less are considered cash and cash equivalents. All
short-term investments are classified as held-to-maturity securities and are
stated at amortized cost. At December 31, 1997 and 1996, short-term investments
consisted of $2.1 million and $24.1 million, respectively, of investment-grade
corporate notes, with maturities at such date of less than one-year. The
aggregate fair value of such securities approximates amortized cost at December
31, 1997 and 1996.
F-10
<PAGE> 42
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
LONG-TERM INVESTMENTS
At December 31, 1997 and 1996, the Partnership had $10.0 million and
$6.9 million, respectively, invested in investment-grade corporate notes, which
have varying maturities until 2002. These securities are classified as
held-to-maturity securities and are stated at amortized cost. At December 31,
1997, the aggregate fair value and unrealized gain for these securities was
$10.1 million and $0.1 million, respectively. At December 31, 1996, the
aggregate fair value and unrealized gain for these securities was $7.0 million
and $0.1 million, respectively. At December 31, 1997 and 1996, such investments
included a $0.9 million investment in Duke Power Company corporate notes, which
matures in 1999.
NOTE 5. INVENTORIES
Inventories are valued at the lower of cost (based on weighted average
cost method) or market. The major components of inventories were as follows:
<TABLE>
<CAPTION>
DECEMBER 31,
-----------------------
1997 1996
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Gasolines .......................................... $ 3,779 $ 3,232
Propane ............................................ 6,872 6,550
Butanes ............................................ 3,152 4,023
Fuel oils .......................................... 82 --
Other products ..................................... 3,099 2,021
Materials and supplies ............................. 4,110 3,088
--------- ---------
Total ................................... $ 21,094 $ 18,914
========= =========
</TABLE>
The costs of inventories were lower than market at December 31, 1997
and 1996.
NOTE 6. PROPERTY, PLANT AND EQUIPMENT
Major categories of property, plant and equipment were as follows:
<TABLE>
<CAPTION>
DECEMBER 31,
-----------------------
1997 1996
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Land and right of way ................................... $ 33,405 $ 33,445
Line pipe and fittings .................................. 443,355 418,096
Storage tanks ........................................... 86,425 89,047
Buildings and improvements .............................. 6,101 5,510
Machinery and equipment ................................. 140,798 114,757
Construction work in progress ........................... 27,660 49,810
--------- ---------
Total property, plant and equipment .......... $ 737,744 $ 710,665
Less accumulated depreciation and amortization 170,063 149,597
--------- ---------
Net property, plant and equipment ....... $ 567,681 $ 561,068
========= =========
</TABLE>
Depreciation and amortization expense was $23.8 million,
$23.4 million and $23.3 million for the years ended December 31,
1997, 1996 and 1995, respectively.
F-11
<PAGE> 43
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 7. LONG TERM DEBT
FIRST MORTGAGE NOTES
In connection with its formation, TE Products Pipeline Company, Limited
Partnership (the "Operating Partnership") issued First Mortgage Notes (the
"Notes") in two series. The outstanding amounts related to the Notes (excluding
current maturities) consist of the following:
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------
1997 1996
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Series A 9.60% due March 7, 2000 ................. $ 44,000 $ 61,000
Series B 10.20% due March 7, 2010 ................ 265,512 265,512
--------- ---------
$ 309,512 $ 326,512
========= =========
</TABLE>
The Notes are secured by a mortgage on substantially all of the
property, plant and equipment of the Partnership. The weighted average interest
rate of the Notes at December 31, 1997 was 10.09%. The Partnership is permitted
to optionally prepay the Notes, in whole or in part, at a premium. Interest on
the Notes is payable semiannually on each March 7 and September 7 until
retirement of the Notes. The Series A First Mortgage Notes have mandatory annual
principal payments through March 7, 2000. The Series B First Mortgage Notes have
mandatory annual principal payments at par of $26.55 million beginning March 7,
2001 through March 7, 2010.
The Note Agreements contain various restrictive covenants applicable to
the Partnership, including prohibition on working capital borrowings in excess
of $35 million (to be increased annually by inflation, if any, subject to a
maximum of $50 million), restrictions on certain other indebtedness and
restrictions on certain liens, mergers, sales of assets and investments. Should
an event of default on the Notes occur, the holders of the Notes may foreclose
upon the mortgaged property. In addition to customary events of default, it is
an event of default under the Note Agreements if any change of the general
partner occurs (other than to an affiliate of the Company) which is not approved
by a majority in principal amount of the Note holders.
At December 31, 1997 and 1996, the estimated fair value of the Notes
(including current maturities) was approximately $390.2 million and $406.1
million, respectively. Market prices for recent transactions and rates currently
available to the Partnership for debt with similar terms and maturities were
used to estimate fair value.
On January 27, 1998, the Operating Partnership completed the issuance
of $180 million principal amount of 6.45% Senior Notes due 2008, and $210
million principal amount of 7.51% Senior Notes due 2028 (collectively the
"Senior Notes"). The 6.45% Senior Notes due 2008 are not subject to redemption
prior to January 15, 2008. The 7.51% Senior Notes due 2028 may be redeemed at
any time after January 15, 2008, at the option of the Operating Partnership, in
whole or in part, at a premium. Net proceeds from the issuance of the Senior
Notes totaled approximately $387 million and was used to repay in full the
$326.5 million principal amount of the Partnership's First Mortgage Notes,
together with a redemption premium of approximately $70.1 million. The
Partnership will record an extraordinary charge during the first quarter of 1998
of approximately $73.5 million, which represents the redemption premium of
approximately $70.1 million and unamortized debt issue costs related to the
First Mortgage Notes of approximately $3.4 million.
The Senior Notes do not have sinking fund requirements. Interest on the
Senior Notes will be paid semiannually in arrears on January 15 and July 15 of
each year, commencing July 15, 1998. The Senior Notes are unsecured obligations
of the Operating Partnership and will rank on a parity with all other unsecured
and unsubordinated indebtedness of the Operating Partnership. The indenture
governing the Senior Notes contain covenants, including, but not limited to,
covenants limiting (i) the creation of liens securing indebtedness and (ii)
F-12
<PAGE> 44
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
sale and leaseback transactions. However, the indenture does not limit the
Partnership's ability to incur additional indebtedness.
NOTE 8. CONCENTRATIONS OF CREDIT RISK
The Partnership's primary market areas are located in the Northeast,
Midwest and Southwest regions of the United States. The Partnership has a
concentration of trade receivable balances due from major integrated oil
companies, independent oil companies and other pipelines and wholesalers. These
concentrations of customers may affect the Partnership's overall credit risk in
that the customers may be similarly affected by changes in economic, regulatory
or other factors. Trade receivables are generally not collateralized; however,
the Partnership's customers' historical and future credit positions are
thoroughly analyzed prior to extending credit (see Note 2).
NOTE 9. QUARTERLY DISTRIBUTIONS OF AVAILABLE CASH
The Partnership makes quarterly cash distributions of all of its
Available Cash, generally defined as consolidated cash receipts less
consolidated cash disbursements and cash reserves established by the general
partner in its sole discretion or as required by the terms of the Notes.
Generally, distributions are made 98% to the Unitholders pro rata and 2% to the
general partner until there has been distributed with respect to each Unit an
amount equal to the Minimum Quarterly Distribution ($0.55 per Unit) for each
quarter. The Company receives incremental incentive distributions of 15%, 25%
and 50% on quarterly distributions of Available Cash that exceed, $0.55, $0.65
and $0.90 per Unit, respectively. During 1997, 1996 and 1995, incentive
distributions paid to the Company totaled $3.2 million, $2.3 million and $1.1
million, respectively.
For the year ended December 31, 1997, cash distributions totaled $49.0
million, resulting from cash distributions of $0.75 per Unit in February and
May, and $0.80 per Unit in August and November. On February 6, 1998, the
Partnership paid the fourth quarter 1997 distribution of $0.85 per Unit. The
distribution increases in August 1997 and February 1998 reflect the
Partnership's success in improving income and cash flow levels.
For the year ended December 31, 1996, cash distributions totaled $45.2
million, resulting from cash distributions of $0.70 per Unit in February and
May, and $0.75 per Unit in August and November. During 1995, the Partnership
paid cash distributions of $40.3 million, resulting from quarterly distributions
of $0.65 per Unit in February, May and August, and $0.70 per Unit in November.
NOTE 10. UNIT OPTION PLAN
During 1994, the Company adopted the Texas Eastern Products Pipeline
Company 1994 Long Term Incentive Plan ("1994 LTIP"). The 1994 LTIP provides key
employees with an incentive award whereby a participant is granted an option to
purchase Units together with a stipulated number of Performance Units. Under the
provisions of the 1994 LTIP, no more than one million options and two million
Performance Units may be granted. Each Performance Unit creates a credit to a
participant's Performance Unit account when earnings exceed a threshold, which
was $2.00, $2.50 and $3.75 per Limited Partner Unit for the awards granted in
1994, 1995 and 1997, respectively. Performance Units grants were 40,000, 35,000
and 5,500 Performance Units during 1994, 1995 and 1997, respectively. No
Performance Units were granted during 1996. When earnings for a calendar year
(exclusive of certain special items) exceed the threshold, the excess amount is
credited to the participant's Performance Unit account. The balance in the
account may be used to exercise Unit options granted in connection with the
Performance Units or may be withdrawn two years after the underlying options
expire, usually 10 years from the date of grant. Under the agreement for such
Unit options, the options become exercisable in equal installments over periods
of one, two, and three years from the date of the grant. Options may also be
exercised by
F-13
<PAGE> 45
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
normal means once vesting requirements are met. A summary of Unit
options granted under the terms of the 1994 LTIP is presented below:
<TABLE>
<CAPTION>
WEIGHTED
AVERAGE
UNITS EXERCISE PRICE
----------- ---------------
<S> <C> <C>
Outstanding at December 31, 1994 .................................... 20,000 $28.6875
Granted ......................................................... 35,000 $27.6250
Exercised ....................................................... (1,561) $28.6875
-----------
Outstanding at December 31, 1995 .................................... 53,439 $27.9916
Granted ......................................................... -- --
Exercised ....................................................... (6,790) $28.2026
-----------
Outstanding at December 31, 1996 .................................... 46,649 $27.9609
Granted ......................................................... 5,550 $43.3125
Exercised ....................................................... (5,935) $28.0670
-----------
Outstanding at December 31, 1997 .................................... 46,264 $29.7889
===========
Exercisable at December 31, 1995 .................................... 5,105 $28.6875
Exercisable at December 31, 1996 .................................... 16,647 $28.1407
Exercisable at December 31, 1997 .................................... 29,049 $28.0741
</TABLE>
As discussed in Note 2, in October 1995, the FASB issued SFAS 123,
"Accounting for Stock-Based Compensation," which allows a company to adopt a
fair value based method of accounting for its stock-based compensation plans.
The Partnership has elected to retain the intrinsic value method of APB No. 25
for recognizing stock-based expense. The exercise price of all options awarded
under the 1994 LTIP equaled the market price of the Partnership's Units on the
date of grant. Accordingly, no compensation was recognized at the date of grant.
Had compensation expense been determined consistent with SFAS 123, compensation
expense for the awards granted in 1995 and 1997 would have totaled $29,875
during 1995, $31,158 during 1996 and $37,138 during 1997. Under the provisions
of SFAS 123, the proforma disclosures above include only the effects of Unit
options granted by the Partnership subsequent to December 31, 1994. During this
initial phase-in period, the disclosures as required by SFAS 123 are not
representative of the effects on reported net income for future years as options
vest over several years and additional awards may be granted in subsequent
years.
For purposes of determining compensation costs using the provisions of
SFAS 123, the fair value of 1995 and 1997 option grants were determined using
the Black-Scholes option-valuation model. The key input variables used in
valuing the options were: risk-free interest rate based on 5-year Treasury
strips - 7.8% and 6.3% for 1995 and 1997, respectively; dividend yield - 8.4%
and 7.2% for 1995 and 1997, respectively; Unit price volatility - 18% for 1995
and 1997; expected option lives - five years for 1995 and 1997.
NOTE 11. LEASES
The Partnership utilizes leased assets in several areas of its
operations. Total rental expense during 1997, 1996 and 1995 was $3.9 million,
$2.5 million and $2.6 million, respectively. The minimum rental payments under
the Partnership's various operating leases for the years 1998 through 2002 are
$4.1 million, $3.8 million, $3.6 million, $3.2 million and $1.8 million,
respectively. Thereafter, payments aggregate $8.2 million through 2007.
In May 1997, the Partnership completed construction to connect the
pipeline system to Colonial Pipeline Company's ("Colonial") pipeline at
Beaumont, Texas. The Partnership has entered into a 10-year capacity lease with
Colonial, whereby the Partnership has guaranteed a minimum monthly through-put
rate for the new connection. The minimum lease payments related to this
agreement are included in the amounts disclosed above.
F-14
<PAGE> 46
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
NOTE 12. EMPLOYEE BENEFITS
PENSION BENEFITS
The Company's employees are included with other affiliates of PanEnergy
in a noncontributory, trustee-administered pension plan. The plan provides
pension benefits to officers and employees of PanEnergy and its subsidiaries.
These benefits are generally based on the employee's years of service and
highest average earnings during a specific period. PanEnergy's policy is to fund
amounts as necessary on an actuarial basis to provide assets sufficient to meet
the benefits to be paid to plan members. The Partnership reimburses the Company
for pension expense on a monthly basis. The significant assumptions affecting
pension expense include: (i) a discount rate of 7.5% for all periods; (ii) rates
of increase in compensation levels of 5% for all periods; and (iii) expected
long-term rates of return on plan assets of 9.5% for all periods. The components
of net pension benefit costs for the years ended December 31, 1997, 1996 and
1995 were as follows (in thousands):
<TABLE>
<CAPTION>
1997 1996 1995
------- ------- -------
<S> <C> <C> <C>
Service cost ............................ $ 1,509 $ 1,414 $ 1,108
Interest cost ........................... 2,359 2,157 1,881
Expected return on plan assets .......... (1,773) (1,641) (1,429)
Amortization of transition asset ........ (33) (39) (39)
------- ------- -------
Net pension benefits costs .............. $ 2,062 $ 1,891 $ 1,521
======= ======= =======
</TABLE>
POSTRETIREMENT BENEFITS OTHER THAN PENSIONS
The Company's employees are included with other affiliates of PanEnergy
in contributory and noncontributory, trustee-administered plans that provide
certain health care and life insurance benefits for retired employees.
Substantially all of the Company's employees may become eligible for these
benefits if they reach retirement age while working for the Company and have
attained 10 years of specified service. The Partnership reimburses the Company
for postretirement benefits cost on a monthly basis. The components of net
postretirement benefits cost for the years ended December 31, 1997, 1996 and
1995 were as follows (in thousands):
<TABLE>
<CAPTION>
1997 1996 1995
------- ----- -----
<S> <C> <C> <C>
Service cost ............................. $ 350 $ 240 $ 169
Interest cost ............................ 703 506 476
Expected return on plan assets ........... (172) (126) (74)
Amortization of transition obligation .... 274 205 201
------- ----- -----
Net postretirement benefits costs ....... $ 1,155 $ 825 $ 772
======= ===== =====
</TABLE>
The transition obligation resulted from the implementation of accrual
accounting for such benefits and is being amortized over approximately 20 years,
commencing in 1993. The weighted average discount rate used in determining the
transition obligation was 7.5%. The assumed health care cost trend rate for
medical costs is 6.5% for 1997. The health care cost trend rate is expected to
decrease, with a 5.5% ultimate trend rate expected to be achieved by 1999. The
health care cost trend rate assumption has a significant effect on the amounts
reported. For example, a 1% increase in the assumed health care cost trend rates
in each future year would increase the transition obligation for the medical
plan by $492,000 as of December 31, 1997, and the annual aggregate of the
service and interest cost components of net postretirement benefits cost by
$33,000.
F-15
<PAGE> 47
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
POSTEMPLOYMENT BENEFITS
The Partnership accrues expense for certain benefits provided to former
or inactive employees after employment but before retirement. During 1997, 1996
and 1995, the Partnership recorded $0.5 million, $0.2 million and $0.1 million,
respectively, of expense for such benefits.
NOTE 13. CONTINGENCIES
The Partnership is involved in various claims and legal proceedings
incidental to its business. In the opinion of management, these claims and legal
proceedings will not have a material adverse effect on the Partnership's
consolidated financial position or results of operations.
The operations of the Partnership are subject to federal, state and
local laws and regulations relating to protection of the environment. Although
the Partnership believes the operations of the pipeline system are in material
compliance with applicable environmental regulations, risks of significant costs
and liabilities are inherent in pipeline operations, and there can be no
assurance that significant costs and liabilities will not be incurred. Moreover,
it is possible that other developments, such as increasingly strict
environmental laws and regulations and enforcement policies thereunder, and
claims for damages to property or persons resulting from the operations of the
Pipeline System, could result in substantial costs and liabilities to the
Partnership. The Partnership does not anticipate that changes in environmental
laws and regulations will have a material adverse effect on its financial
position, operations or cash flows in the near term.
The Partnership and the Indiana Department of Environmental Management
("IDEM") have entered into an Agreed Order that will ultimately result in a
remediation program for any on-site and off-site groundwater contamination
attributable to the Partnership's operations at the Seymour, Indiana, terminal.
As part of the Agreed Order, the Partnership has completed the remedial
investigation sampling for groundwater contamination. In November 1997, IDEM
approved the final remedial investigation report for the Seymour terminal. The
Partnership is currently negotiating with IDEM the clean-up levels to be
attained at the Seymour terminal. The Partnership estimates that the costs of
the remediation program to be proposed by the Partnership for the Seymour
terminal will not exceed the amount accrued therefore (approximately $1.7
million at December 31, 1997). In the opinion of the Company, the completion of
the remediation program to be proposed by the Partnership, if such program is
approved by IDEM, will not have a material adverse impact on the Partnership's
financial condition, results of operations or liquidity.
In a June 1995 decision, the FERC disallowed the inclusion of imputed
income taxes in the cost-of-service tariff filing of Lakehead Pipeline Company,
Limited Partnership ("Lakehead"), an unrelated oil pipeline limited partnership.
The FERC's decision held that Lakehead was entitled to include an income tax
allowance in its cost-of-service for income attributable to corporate partners
but not on income attributable to individual partners. In 1996, Lakehead reached
an agreement with its shippers on all contested rates and has withdrawn its
appeal of the June 1995 decision. In another FERC proceeding, SFPP, L.P., the
Administrative Law Judge in the Initial Decision Concerning Rates, Terms and
Conditions of Service, and Other Matters, followed the Commission's decision in
Lakehead and held that SFPP may claim an income tax allowance with respect to
income attributable to SFPP, Inc.'s general partnership interest and income
attributable to corporations holding publicly traded limited partnership
interests, but not for income attributable to non-corporate limited partners,
both individuals and other entities. The decision also disallowed the income tax
allowance attributable to SFPP, Inc.'s limited partnership interest under facts
peculiar to the way SFPP held its limited partnership interests. Neither the
FERC's decision in Lakehead nor the Administrative Law Judge's initial decision
in SFPP, L.P. affects the Partnership's current rates and rate structure because
the Partnership uses the index methodology to support its rates and intends to
continue to do so. However, the Lakehead and SFPP precedents might become
relevant to the Partnership should it (i) elect in the future to use the
cost-of-service methodology or (ii) be required to use such methodology to
defend its indexed
F-16
<PAGE> 48
TEPPCO PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
rates against a shipper protest alleging that an indexed rate increase
substantially exceeds actual cost increases. Should such circumstances arise,
there can be no assurance with respect to the effect of such precedents on the
Partnership's rates in view of the uncertainties involved in this issue.
Substantially all of the petroleum products transported and stored by
the Partnership are owned by the Partnership's customers. At December 31, 1997,
the Partnership had approximately 14.2 million barrels of products in its
custody and at third party storage facilities owned by customers. The
Partnership is obligated for the transportation, storage and delivery of such
products on behalf of its customers. The Partnership maintains insurance
adequate to cover product losses through circumstances beyond its control.
At December 31, 1997, the Pipeline System had approximately 165
customers. Transportation revenues (and percentage of total revenues)
attributable to the top 10 shippers were $85 million (38%), $81 million (38%),
and $77 million (38%) for the years ended December 31, 1997, 1996 and 1995,
respectively. During 1997, 1996 and 1995, no single customer accounted for
greater than 10% of total revenues. Loss of a business relationship with a
significant customer could have an adverse affect on the consolidated financial
position, results of operations and liquidity of the Partnership.
In 1997, the Company initiated a program to prepare the Partnership's
process controls and business computer systems for the "Year 2000 issue."
Process controls are the automated equipment including hardware and software
systems which run operational activities. Business computer systems are the
computer hardware and software used by the Partnership. The Partnership expects
to incur internal staff costs as well as consulting and other expenses related
to testing and conversion of these assets. The Company continues to evaluate
appropriate courses of corrective action, including replacement of certain
systems whose associated costs would be recorded as assets and amortized. The
Company estimates that the amounts required to be expensed during 1998 and 1999
will range between approximately $4.0 million and $6.0 million. The amount
expensed in 1997 was immaterial. Testing and conversion is expected to be
completed by mid-year 1999. The Partnership has initiated formal communications
with all of its significant suppliers and large customers to determine the
extent to which the Partnership is vulnerable to those third parties' failure to
remediate their own Year 2000 issue. However, there can be no guarantee that the
systems of other companies, on which the Partnership's systems rely, will be
timely converted by another company, or a conversion that is incompatible with
the Partnership's systems, would not have a material adverse effect on the
Partnership.
NOTE 14. QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
<TABLE>
<CAPTION>
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
-------- -------- -------- --------
(IN THOUSANDS, EXCEPT PER UNIT AMOUNTS)
<S> <C> <C> <C> <C>
1997
- ----
Operating revenues ............................ $ 55,425 $ 52,649 $ 53,305 $ 60,714
Operating income .............................. 24,945 20,516 19,437 26,652
Net income .................................... 17,795 13,125 11,444 18,936
Basic net income per Limited Partner Unit ..... $ 1.14 $ 0.85 $ 0.71 $ 1.20
Diluted net income per Limited Partner Unit ... $ 1.14 $ 0.84 $ 0.71 $ 1.20
1996
- ----
Operating revenues ............................ $ 58,849 $ 48,946 $ 49,528 $ 58,702
Operating income .............................. 27,536 17,497 17,449 24,952
Net income .................................... 20,126 10,304 10,392 17,826
Basic net income per Limited Partner Unit ..... $ 1.32 $ 0.67 $ 0.65 $ 1.15
Diluted net income per Limited Partner Unit ... $ 1.32 $ 0.67 $ 0.65 $ 1.15
</TABLE>
F-17
<PAGE> 49
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------ -----------
<S> <C>
3.1 Certificate of Limited Partnership of the Partnership
(Filed as Exhibit 3.2 to the Partnership's Registration
Statement (Commission File No. 33-32203) and incorporated
herein by reference).
4.1 Form of Certificate representing Units (Filed as Exhibit
4.1 to the Partnership's Registration Statement (Commission
File No. 33-32203) and incorporated herein by reference).
4.2 Agreement of Limited Partnership of TEPPCO Partners, L.P.,
dated March 7, 1990 (Filed as Exhibit 4(a) to Form 10-Q of
TEPPCO Partners, L.P. (Commission File No. 1-10403) for the
quarter ended March 31, 1990 and incorporated herein by
reference).
4.3 Note Agreement, 9.60% Series A and 10.20% Series B First
Mortgage Notes, dated February 28, 1990 (Filed as Exhibit
4(b) to Form 10-Q of TEPPCO Partners, L.P. (Commission File
No. 1-10403) for the quarter ended March 31, 1990 and
incorporated herein by reference).
4.4 Amendment to Note Agreement, dated June 1, 1994, 9.60%
Series A and 10.20% Series B First Mortgage Notes (Filed as
Exhibit 4 to Form 10-Q of TEPPCO Partners, L.P. (Commission
File No. 1-10403) for the quarter ended June 30, 1994 and
incorporated herein by reference).
4.5 Amendment to Note Agreement, dated February 24, 1995, 9.60%
Series A and 10.20% Series B First Mortgage Notes (Filed as
Exhibit 4.5 to Form 10-K of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the year ended December
31, 1994 and incorporated herein by reference).
</TABLE>
<PAGE> 50
<TABLE>
<S> <C>
4.6 Form of Indenture between TE Products Pipeline Company,
Limited Partnership and The Bank of New York, as Trustee,
dated as of January 27, 1998 (Filed as Exhibit 4.3 to TE
Products Pipeline Company, Limited Partnership's
Registration Statement on Form S-3 (Commission File No.
333-38473) and incorporated herein by reference).
10.1 Agreement of Limited Partnership of TE Products Pipeline
Company, Limited Partnership, dated March 7, 1990 (Filed as
Exhibit 28 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the quarter ended March
31, 1990 and incorporated herein by reference).
10.2 Assignment and Assumption Agreement, dated March 24, 1988,
between Texas Eastern Transmission Corporation and the
Company (Filed as Exhibit 10.8 to the Partnership's
Registration Statement (Commission File No. 33-32203) and
incorporated herein by reference).
10.3 Texas Eastern Products Pipeline Company 1997 Employee
Incentive Compensation Plan executed on July 14, 1997
(Filed as Exhibit 10 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File 1-10403) for the quarter ended September
30, 1997 and incorporated herein by reference).
10.4 Agreement Regarding Environmental Indemnities and Certain
Assets (Filed as Exhibit 10.5 to the Partnership's Form
10-K (Commission File No. 1-10403) for the year ended
December 31, 1990 and incorporated herein by reference).
10.5 Texas Eastern Products Pipeline Company Management
Incentive Compensation Plan executed on January 30, 1992
(Filed as Exhibit 10 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the quarter ended March
31, 1992 and incorporated herein by reference).
10.6 Texas Eastern Products Pipeline Company Long-Term Incentive
Compensation Plan executed on October 31, 1990 (Filed as
Exhibit 10.9 to the Partnership's Form 10-K (Commission
File No. 1-10403) for the year ended December 31, 1990 and
incorporated herein by reference).
10.7 Form of Amendment to Texas Eastern Products Pipeline
Company Long-Term Incentive Compensation Plan (Filed as
Exhibit 10.7 to the Partnership's Form 10-K (Commission
File No. 1-10403) for the year ended December 31, 1995 and
incorporated herein by reference).
10.8 Employees' Savings Plan of Panhandle Eastern Corporation
and Participating Affiliates (Effective January 1, 1991)
(Filed as Exhibit 10.10 to the Partnership's Form 10-K
(Commission File No. 1-10403) for the year ended December
31, 1990 and incorporated herein by reference).
10.9 Retirement Income Plan of Panhandle Eastern Corporation and
Participating Affiliates (Effective January 1, 1991) (Filed
as Exhibit 10.11 to the Partnership's Form 10-K (Commission
File No. 1-10403) for the year ended December 31, 1990 and
incorporated herein by reference).
10.10 Panhandle Eastern Corporation -- Executive Benefit
Equalization Plan as amended November 29, 1989; effective
January 1, 1990 (Filed as Exhibit 10.05 to Form 10-K of
Panhandle (Commission File No. 1-8157) for the year ended
December 31, 1989 and incorporated herein by reference).
10.11 Employment Agreement with William L. Thacker, Jr. (Filed as
Exhibit 10 to Form 10-Q of TEPPCO Partners, L.P.
(Commission File No. 1-10403) for the quarter ended
September 30, 1992 and incorporated herein by reference).
10.12 Texas Eastern Products Pipeline Company 1994 Long Term
Incentive Plan executed on March 8, 1994 (Filed as Exhibit
10.1 to Form 10-Q of TEPPCO Partners, L.P. (Commission File
No. 1-10403) for the quarter ended March 31, 1994 and
incorporated herein by reference).
10.13 Panhandle Eastern Corporation Key Executive Deferred
Compensation Plan established effective January 1, 1994
(Filed as Exhibit 10.2 to Form 10-Q of TEPPCO Partners,
L.P.
</TABLE>
<PAGE> 51
<TABLE>
<S> <C>
(Commission File No. 1-10403) for the quarter ended March 31,
1994 and incorporated herein by reference).
22.1 Subsidiaries of the Partnership (Filed as Exhibit 22.1 to
the Partnership's Registration Statement (Commission File
No. 33-32203) and incorporated herein by reference).
*23 Consent of KPMG Peat Marwick LLP.
*24 Powers of Attorney.
*27 Financial Data Schedule as of and for the year ended
December 31, 1997.
</TABLE>
- ----------------
* Filed herewith.
<PAGE> 1
EXHIBIT 23
INDEPENDENT AUDITORS CONSENT
To the Partners of
TEPPCO Partners, L.P.:
We consent to incorporation by reference in the registration statement (No.
33-81976) on Form S-3 of TEPPCO Partners, L.P. of our report dated January 16,
1998, except as to Note 7, which is as of January 27, 1998, relating to the
consolidated balance sheets of TEPPCO Partners, L.P. as of December 31, 1997,
and 1996, and the related consolidated statements of income, partners' capital,
and cash flows for each of the years in the three-year period ended December
31, 1997, which report appears in the December 31, 1997, annual report on Form
10-K of TEPPCO Partners, L.P.
/S/ KPMG PEAT MARWICK LLP
KPMG Peat Marwick LLP
Houston, Texas
March 3, 1998
<PAGE> 1
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS, that each of the undersigned directors
and/or officers of TEXAS EASTERN PRODUCTS PIPELINE COMPANY (Company), a
Delaware corporation, acting in its capacity as general partner of TEPPCO
Partners, L.P., does hereby constitute and appoint WILLIAM L. THACKER, CHARLES
H. LEONARD AND JAMES C. RUTH, and each of them, his true and lawful attorney
and agent to do any and all acts and things, and execute any and all
instruments which, with the advise and consent of Counsel, said attorney and
agent may deem necessary or advisable to enable the Company to comply with the
Securities Act of 1934, as Amended, and any rules, regulations, and
requirements of the Securities and Exchange Commission, including specifically,
but without limitation thereof, to sign his name as a director and/or officer
of the Company to the Form 10-K Report for TEPPCO Partners, L.P. for the year
ended December 31, 1997, and to any instrument or document filed as a part of,
or in accordance with, said Form 10-K or Amendment thereto; and the undersigned
do hereby ratify and confirm all that said attorney and agent shall do or cause
to be done by virtue hereof.
IN WITNESS WHEREOF, the undersigned have subscribed these presents
this 3rd day of March, 1998.
/s/ W. L. THACKER /s/ PAUL M. ANDERSON
- ------------------------- ----------------------------
W. L. Thacker Paul M. Anderson
/s/ JAMES T. HACKETT /s/ JIM W. MOGG
- ------------------------- ----------------------------
James T. Hackett Jim W. Mogg
/s/ RUTH G. SHAW /s/ DERRILL CODY
- ------------------------- ----------------------------
Ruth G. Shaw Derrill Cody
/s/ MILTON CARROLL /s/ CARL D. CLAY
- ------------------------- ----------------------------
Milton Carroll Carl D. Clay
/s/ JOHN P. DESBARRES /s/ CHARLES H. LEONARD
- ------------------------- ----------------------------
John P. DesBarres Charles H. Leonard
Senior Vice President,
CFO & Treasurer
<TABLE> <S> <C>
<ARTICLE> 5
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-START> JAN-01-1997
<PERIOD-END> DEC-31-1997
<CASH> 43,961
<SECURITIES> 2,105
<RECEIVABLES> 19,826
<ALLOWANCES> 0
<INVENTORY> 21,094
<CURRENT-ASSETS> 91,159
<PP&E> 737,744
<DEPRECIATION> 170,063
<TOTAL-ASSETS> 673,909
<CURRENT-LIABILITIES> 53,875
<BONDS> 309,512
0
0
<COMMON> 0
<OTHER-SE> 302,967
<TOTAL-LIABILITY-AND-EQUITY> 673,909
<SALES> 0
<TOTAL-REVENUES> 222,093
<CGS> 0
<TOTAL-COSTS> 130,543
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 33,707
<INCOME-PRETAX> 61,925
<INCOME-TAX> 0
<INCOME-CONTINUING> 61,300
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 61,300
<EPS-PRIMARY> 3.90<F1>
<EPS-DILUTED> 3.90
<FN>
<F1>Amount represents basic net income per Limited Partner
Unit under provisions of SFAS 128.
</FN>
</TABLE>
