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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D. C. 20549
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FORM 10-K
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[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
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
COMMISSION FILE NUMBER: 1-9743
ENRON OIL & GAS COMPANY
(Exact name of registrant as specified in its charter)
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DELAWARE 47-0684736
(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
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1400 SMITH STREET, HOUSTON, TEXAS 77002-7369
(Address of principal executive offices) (zip code)
REGISTRANT'S TELEPHONE NUMBER, INCLUDING AREA CODE: 713-853-6161
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SECURITIES REGISTERED PURSUANT TO SECTION 12(B) OF THE ACT:
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NAME OF EACH EXCHANGE
TITLE OF EACH CLASS ON WHICH REGISTERED
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Common Stock, $.01 par value New York Stock Exchange
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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 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X] No [ ].
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [X].
Aggregate market value of the voting stock held by nonaffiliates of the
registrant, based on the closing sale price in the daily composite list for
transactions on the New York Stock Exchange on February 27, 1998 was
$1,450,296,850. As of March 1, 1998, there were 154,762,377 shares of the
registrant's Common Stock, $.01 par value, outstanding.
DOCUMENTS INCORPORATED BY REFERENCE. Certain portions of the registrant's
definitive Proxy Statement for the May 5, 1998 Annual Meeting of Shareholders
("Proxy Statement") are incorporated in Part III by reference.
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TABLE OF CONTENTS
PART I
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Item 1. Business
General..................................................... 1
Business Segments........................................... 2
Exploration and Production.................................. 2
Marketing................................................... 5
Wellhead Volumes and Prices, and Lease and Well Expenses.... 7
Competition................................................. 8
Regulation.................................................. 8
Relationship Between the Company and Enron Corp............. 11
Other Matters............................................... 15
Current Executive Officers of the Registrant................ 17
Item 2. Properties
Oil and Gas Exploration and Production Properties and
Reserves.................................................. 18
Item 3. Legal Proceedings........................................... 20
Item 4. Submission of Matters to a Vote of Security Holders......... 21
PART II
Item 5. Market for the Registrant's Common Equity and Related
Shareholder Matters....................................... 21
Item 6. Selected Financial Data..................................... 22
Item 7. Management's Discussion and Analysis of Financial Condition
and Results of
Operations.................................................. 23
Item 8. Financial Statements and Supplementary Data................. 29
Item 9. Disagreements on Accounting and Financial Disclosure........ 29
PART III
Item 10. Directors and Executive Officers of the Registrant.......... 29
Item 11. Executive Compensation...................................... 29
Item 12. Security Ownership of Certain Beneficial Owners and
Management................................................ 29
Item 13. Certain Relationships and Related Transactions.............. 30
PART IV
Item 14. Financial Statements and Financial Statement Schedule,
Exhibits and Reports on Form 8-K.......................... 30
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PART I
ITEM 1. BUSINESS
GENERAL
Enron Oil & Gas Company (the "Company"), a Delaware corporation organized
in 1985, is engaged, either directly or through a marketing subsidiary with
regard to domestic operations or through various subsidiaries with regard to
international operations, in the exploration for, and the development,
production and marketing of, natural gas and crude oil primarily in major
producing basins in the United States, as well as in Canada, Trinidad and India
and, to a lesser extent, selected other international areas. The Company's
principal producing areas are further described under "Exploration and
Production" below. At December 31, 1997, the Company's estimated net proved
natural gas reserves were 4,001 billion cubic feet ("Bcf"), including 1,180 Bcf
of proved undeveloped methane reserves in the Big Piney deep Paleozoic
formations, and estimated net proved crude oil, condensate and natural gas
liquids reserves were 78 million barrels ("MMBbl"). (See "Supplemental
Information to Consolidated Financial Statements"). At such date, approximately
67% of the Company's reserves (on a natural gas equivalent basis) was located in
the United States, 10% in Canada, 8% in Trinidad and 15% in India. As of
December 31, 1997, the Company employed approximately 825 persons.
The Company's business strategy is to maximize the rate of return on
investment of capital by controlling both operating and capital costs and
enhancing the certainty of future revenues through the selective use of various
marketing mechanisms. This strategy enhances the generation of both income and
cash flow from each unit of production and allows for the growth of production
on a cost-effective basis by optimizing the reinvestment of cash flow. The
Company continued to focus its 1997 drilling activity toward natural gas
deliverability in addition to natural gas reserve enhancement and crude oil
exploitation in the United States in response to the higher United States
natural gas prices in recent periods. The Company also is focusing on the
cost-effective utilization of advances in technology associated with gathering,
processing and interpretation of 3-D seismic data, developing reservoir
simulation models and drilling operations through the use of new and/or improved
drill bits, mud motors, mud additives, formation logging techniques and
reservoir fracturing methods. These advanced technologies are used, as
appropriate, throughout the Company to reduce the risks associated with all
aspects of oil and gas reserve exploration, exploitation and development. The
Company implements its strategy by emphasizing the drilling of internally
generated prospects in order to find and develop low cost reserves. Achieving
and maintaining the lowest possible operating cost structure are also important
goals in the implementation of the Company's strategy. Consistent with the
Company's desire to optimize the use of its assets, it also maintains a strategy
of selling selected oil and gas properties that for various reasons may no
longer fit into future operating plans, or which are not assessed to have
sufficient future growth potential and when the economic value to be obtained by
selling the properties and reserves in the ground is evaluated to be greater
than what would be obtained by holding the properties and producing the reserves
over time. As a result, the Company typically receives each year a varying but
substantial level of proceeds related to such sales which proceeds are available
for general corporate use.
As of December 31, 1997, Enron Corp. owned 55% of the outstanding shares of
the common stock of the Company. (See "Relationship Between the Company and
Enron Corp.").
Unless the context otherwise requires, all references herein to the Company
include Enron Oil & Gas Company, its predecessors and subsidiaries, and any
reference to the ownership of interests or pursuit of operations in any
international areas by the Company recognizes that all such interests are owned
and operations are pursued by subsidiaries of Enron Oil & Gas Company. Unless
the context otherwise requires, all references herein to Enron Corp. include
Enron Corp., its predecessors and affiliates, other than the Company and its
predecessors and subsidiaries.
With respect to information on the Company's working interest in wells or
acreage, "net" oil and gas wells or acreage are determined by multiplying
"gross" oil and gas wells or acreage by the Company's working interest in the
wells or acreage. Unless otherwise defined, all references to wells are gross.
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BUSINESS SEGMENTS
The Company's operations are all natural gas and crude oil exploration and
production related. Accordingly, such operations are classified as one business
segment.
EXPLORATION AND PRODUCTION
NORTH AMERICA OPERATIONS
United States. The Company's eight principal United States producing areas
are the Big Piney area of Wyoming, South Texas area, East Texas area, Offshore
Gulf of Mexico area, Canyon/Strawn Trend area of West Texas, Sand Tank and
Pitchfork Ranch areas of New Mexico and Vernal area of Utah. Properties in these
areas comprised approximately 82% of the Company's United States reserves (on a
natural gas equivalent basis) and 79% of the Company's United States net natural
gas deliverability as of December 31, 1997 and are substantially all operated by
the Company.
The Company's other United States natural gas and crude oil producing
properties are located primarily in other areas of Texas, Utah, New Mexico,
Oklahoma, California, Mississippi and Kansas.
At December 31, 1997, 94% of the Company's proved United States reserves,
including the reserves in the Big Piney deep Paleozoic formations (on a natural
gas equivalent basis), was natural gas and 6% was crude oil, condensate and
natural gas liquids. A substantial portion of the Company's United States
natural gas reserves is in long-lived fields with well-established production
histories. The Company believes that opportunities exist to increase production
in many of these fields through continued infill and other development drilling.
Big Piney Area. The Company's largest reserve accumulation is located in
the Big Piney area in Sublette and Lincoln counties in southwestern Wyoming. The
Company is the holder of the largest productive acreage base in this area, with
approximately 263,000 net acres under lease directly within field limits. The
Company operates approximately 780 oil and natural gas wells in this area in
which it owns an 85% average working interest. Deliveries from the area net to
the Company averaged 114 million cubic feet ("MMcf") per day of natural gas and
3.7 thousand barrels ("MBbl") per day of crude oil, condensate, and natural gas
liquids in 1997. At December 31, 1997, natural gas deliverability net to the
Company was approximately 130 MMcf per day.
The current principal producing intervals are the Frontier and Mesaverde
formations. The Frontier formation, which occurs at 6,500 to 10,000 feet,
contains approximately 62% of the Company's Big Piney proved developed reserves.
The Company drilled 87 wells in the Big Piney area in 1997 and anticipates an
active drilling program will continue for several years.
The Company has recorded as proved undeveloped reserves 1,180 Bcf of
methane contained, along with high concentrations of carbon dioxide as well as
small amounts of other gaseous substances, in the deep Wyoming Paleozoic
formation located under acreage leased by the Company and held by production in
the Big Piney area. The Company is actively pursuing the consummation of a
market or markets from several different potential sources to facilitate
realizing the value of these reserves.
South Texas Area. The Company's activities in South Texas are focused in
the Lobo, Wilcox and Frio producing horizons. The principal areas of activity
are in the Lobo and Wilcox Trends which occur primarily in Webb, Zapata and
Starr counties.
During 1997, the Company acquired an interest in a significant Wilcox Trend
property in Duval County. Net production from the acquired property as of
December 31, 1997 was 15 MMcf of natural gas equivalent per day.
The Company now operates approximately 427 wells in the South Texas area.
Production is primarily from the Upper Wilcox and Lobo sands at depths ranging
from 5,000 to 16,000 feet. The Company has approximately 240,000 net leasehold
acres and more than 40,000 net mineral fee acres in this area. Natural gas
deliveries net to the Company averaged approximately 182 MMcf per day in 1997.
At December 31, 1997,
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natural gas deliverability from this area net to the Company was approximately
180 MMcf per day. The Company drilled 65 wells in the South Texas area in 1997
and participated in sizable 3-D seismic and leasehold acquisition efforts during
the year. An active drilling program in this area is anticipated to continue for
several years.
East Texas Area. The Company's activities in the East Texas area are
primarily in the Carthage field, located in Panola County, the North Milton
field, located in northern Harris County and the Stowell field, located in
Jefferson and Chambers Counties.
The Carthage field production is primarily from the Cotton Valley, Travis
Peak and Pettit formations. The Company holds approximately 17,900 net acres
under lease with an average 77% working interest in this area. The Company
drilled 30 wells in the Carthage field in 1997 and anticipates an active
drilling program will continue for several years. The Company has continued its
activity in the North Milton field where it now operates 22 wells and holds a
100% working interest in the acreage. Further drilling is planned for 1998. The
Company drilled 3 wells in the Stowell field in 1997 and expects to expand the
program substantially in 1998. At December 31, 1997, deliverability from the
East Texas area was approximately 50 MMcf per day of natural gas with 1.9 MBbl
per day of crude oil, condensate and natural gas liquids both net to the
Company. The Company holds 60,000 net acres in southern Anderson County in the
East Texas Jurassic reef play and is presently shooting an 83.5 square mile 3-D
seismic survey to define drilling locations.
Offshore Gulf of Mexico Area. During 1997, the Company participated in two
lease sales offering leases in the Gulf of Mexico and acquired approximately
81,200 net acres (17 leases). As a result of the lease sale activity, the
Company continued to build its deepwater portfolio by acquiring eight deepwater
(greater than 600 feet) tracts in 1997 to add to the seven tracts acquired in
1996. At December 31, 1997, the Company held an interest in 192 blocks in the
Offshore Gulf of Mexico area totaling approximately 546,000 net acres. Of the
192 blocks, 141 are operated by the Company. These interests are located
predominantly in federal waters offshore Texas and Louisiana. Natural gas
deliveries from this area averaged 111 MMcf per day during 1997 net to the
Company. A substantial portion of such deliveries was from interests in the
Matagorda trend with significant volumes also coming from the Mustang Island
area. Deliverability from the offshore Gulf of Mexico area at December 31, 1997
was approximately 110 MMcf per day net to the Company sourced principally as
noted above. During 1997, the Company participated in the drilling of 10 wells
(5.2 net wells) in the Gulf of Mexico, a decrease in drilling activity of
approximately 50% as compared to 1996 and 1995. In 1998, the Company anticipates
participating in the drilling of 15 to 20 wells.
Canyon/Strawn Trend Area. The Company's activities in this area have been
concentrated in Crockett, Terrell and Val Verde Counties in Texas where the
Company drilled 51 natural gas wells during 1997. The Company holds
approximately 63,000 net acres and now operates approximately 325 natural gas
wells in this area in which it owns a 90% average working interest. Production
is from the Canyon sands and Strawn limestone at depths from 5,500 to 12,500
feet. At December 31, 1997, natural gas deliverability net to the Company was
approximately 35 MMcf per day. The Company plans an aggressive program on
several new prospects in 1998, including the potential for some horizontal
drilling.
Sand Tank Area. The Sand Tank area located in Eddy County, New Mexico
produces from the Chester, Morrow, and Atoka formations. In 1997, the Company
acquired 42 square miles of 3-D seismic and drilled 13 wells, increasing natural
gas deliverability to approximately 20 MMcf per day at year end. The Company
holds 12,000 net acres and has an average working interest of approximately 57%.
Several wells are planned in 1998 for this stacked-pay area.
Pitchfork Ranch Area. The Pitchfork Ranch area located in Lea County, New
Mexico, produces primarily from the Bone Spring, Atoka and Morrow formations. In
1997, deliveries net to the Company averaged 21 MMcf per day of natural gas and
approximately 2 MBbl per day of crude oil, condensate and natural gas liquids.
At December 31, 1997, deliverability net to the Company was approximately 15
MMcf per day of natural gas and 1.9 MBbl per day of crude oil, condensate and
natural gas liquids. The Company holds approximately 28,000 net acres and is
continuing to interpret a 3-D seismic survey shot over this entire area. The
Company expects to maintain a drilling program in this area for several years.
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Vernal Area. In the Vernal area, located primarily in Uintah County, Utah,
the Company operates approximately 245 producing wells and presently controls
approximately 74,000 net acres. In 1997, natural gas deliveries net to the
Company from the Vernal area averaged 15 MMcf per day. Deliverability at
December 31, 1997, was approximately 16 MMcf per day. Production is from the
Green River and Wasatch formations located at depths between 4,500 and 8,000
feet. The Company has an average working interest of approximately 60%. Numerous
drilling opportunities will be available in this area for several years.
Canada. The Company is engaged in the exploration for and the development,
production and marketing of natural gas and crude oil and the operation of
natural gas processing plants in Western Canada, principally in the provinces of
Alberta, Saskatchewan, and Manitoba. The Company conducts operations from
offices in Calgary, and produces natural gas from seven major areas and crude
oil from four major areas. Additional interests were acquired in the Blackfoot
producing area through two separate transactions in July 1997 and September
1997. Net production from the acquired properties at December 31, 1997 was 13
MMcf of natural gas equivalent per day. The Sandhills area in southwestern
Saskatchewan is the largest single producing area in Canada. In 1997, 93 wells
were drilled in the area resulting in deliverability of approximately 40 MMcf
per day net to the Company at December 31, 1997. Total Canadian natural gas
deliverability net to the Company at December 31, 1997 was approximately 100
MMcf per day, and the Company held approximately 490,000 net undeveloped acres
in Canada. The Company expects to maintain an active drilling program for
several years.
OUTSIDE NORTH AMERICA OPERATIONS
The Company has producing operations offshore Trinidad and India, and is
evaluating and conducting exploration, exploitation and development in selected
other international areas.
Trinidad. In November 1992, the Company was awarded a 95% working interest
concession in the South East Coast Consortium ("SECC") Block offshore Trinidad,
encompassing three undeveloped fields, previously held by three government-owned
energy companies. The Kiskadee field has since been developed. The Ibis field is
under development and the Oil Bird field is anticipated to be developed over the
next several years. Existing surplus processing and transportation capacity at
the Pelican field facilities owned and operated by Trinidad and Tobago
government-owned companies is being used to process and transport the
production. Natural gas is being sold into the local market under a take-or-pay
agreement with the National Gas Company of Trinidad and Tobago. In 1997,
deliveries net to the Company averaged 113 MMcf per day of natural gas and 3.4
MBbl per day of crude oil and condensate. At December 31, 1997, the Company held
approximately 168,000 net undeveloped acres in Trinidad.
In 1995, the Company was awarded the right to develop the modified U(a)
block adjacent to the SECC Block. A production sharing contract was signed with
the Government of Trinidad and Tobago in 1996. A 3-D seismic data gathering
project has been completed and is being evaluated. Initial drilling is planned
to occur during 1998.
India. In December 1994, the Company signed agreements covering profit
sharing, joint operations and product sales and representing a 30% working
interest in, and was designated operator of, the Tapti, Panna and Mukta Blocks
located offshore Bombay, India. The blocks were previously operated by the
Indian national oil company, Oil & Natural Gas Corporation Limited, which
retained a 40% working interest. The 363,000 acre Tapti Block contains two major
proved natural gas accumulations delineated by 22 expendable exploration wells
that have been plugged. The Company has substantially implemented an initial
development plan for the Tapti Block accumulations and production began during
1997. At December 31, 1997, production, net to the Company, from Tapti was 48
MMcf per day. The 106,000 acre Panna Block and the 192,000 acre Mukta Block are
partially developed with 29 wells producing from six production platforms
located in the Panna and Mukta fields. The fields were producing approximately
4.3 MBbl per day of crude oil net to the Company as of December 31, 1997.
Natural gas sales began from the Panna field during the first quarter of 1998.
The Company intends to continue development of the fields.
Venezuela. The Company was awarded exploration, exploitation and
development rights for a block offshore the eastern state of Sucre, Venezuela in
early 1996. The Company signed agreements with the
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government of Venezuela and other participants associated with a concession
awarded in the Gulf of Paria East. The Company holds an initial 90 percent
working interest in the joint venture and acts as operator. A 3-D seismic data
project is currently underway and initial drilling is anticipated in 1998.
China. In August 1997, the Company signed a 30-year production sharing
contract with the China National Petroleum Corporation for the appraisal and
potential development of crude oil and natural gas reserves within the
Chuanzhong Block situated in one of China's oldest producing areas in the
central Sichuan Province. The Company holds a 100 percent interest in the fields
and is the operator.
The contract provides for a two-year evaluation period during which the
Company will perform three workover/stimulations to improve productivity in
existing wells and will drill three new wells in the areas of proven production.
Further commitments, if any, would arise from entering into the development
period as specified in the contract.
Other International. The Company continues to evaluate other selected
conventional natural gas and crude oil opportunities outside North America by
pursuing other exploitation opportunities in countries where indigenous natural
gas and crude oil reserves have been identified, particularly where synergies in
natural gas transportation, processing and power generation can be optimized
with other Enron Corp. affiliated companies. In early 1995, the Company, an
Enron Corp. affiliate and the Qatar General Petroleum Corporation signed a
nonbinding letter of intent concerning the possible development of a liquefied
natural gas project for natural gas to be produced from a block within the North
Dome Field. The Company and the Enron Corp. affiliate may jointly hold up to a
35% equity interest in the project. The Company has also completed the extension
and enhancement of an existing Memorandum of Understanding with Uzbekneftegaz
covering the pursuit of joint development and marketing opportunities for proven
hydrocarbon reserves in eleven fields in the Surhandarya and Bukhara regions of
Uzbekistan. The Company is also participating in discussions concerning the
potential for natural gas development opportunities in Mozambique as well as
other opportunities in Trinidad, India, Venezuela and Bangladesh. (See
"Relationship Between the Company and Enron Corp. - Business Opportunity
Agreement" for a further discussion of the relationship between the Company and
Enron Corp. in the projects in Qatar, Uzbekistan and Mozambique.)
MARKETING
Wellhead Marketing. The Company's North America wellhead natural gas
production is currently being sold on the spot market and under long-term
natural gas contracts at market responsive prices. In many instances, the
long-term contract prices closely approximate the prices received for natural
gas being sold on the spot market. Wellhead natural gas volumes from Trinidad
are sold at prices that are based on a fixed price schedule with annual
escalations. Under terms of the production sharing contracts, natural gas
volumes in India are to be sold to a nominee of the Government of India at a
price linked to a basket of world market fuel oil quotations with floor and
ceiling limits. Approximately 15% of the Company's wellhead natural gas
production is currently being sold to pipeline and marketing subsidiaries of
Enron Corp. The Company believes that the terms of its transactions and
agreements with Enron Corp. are and intends that future such transactions and
agreements will be at least as favorable to the Company as could be obtained
from third parties.
Substantially all of the Company's wellhead crude oil and condensate is
sold under various terms and arrangements at market responsive prices.
Approximately 10% of the Company's wellhead crude oil and condensate production
is currently being sold to affiliated companies.
Other Marketing. Enron Oil & Gas Marketing, Inc. ("EOGM"), a wholly-owned
subsidiary of the Company, is a marketing company engaging in various marketing
activities. Both the Company and EOGM contract to provide, under short and
long-term agreements, natural gas to various purchasers and then aggregate the
necessary supplies for the sales with purchases from various sources including
third-party producers, marketing companies, pipelines or from the Company's own
production and arrange for any necessary transportation to the points of
delivery. In addition, EOGM has purchased and constructed several small
gathering systems in order to facilitate its entry into the gathering business
on a limited basis. Both the Company and EOGM utilize other short and long-term
hedging and trading mechanisms including sales and
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purchases utilizing NYMEX-related commodity market transactions. These marketing
activities have provided an effective balance in managing a portion of the
Company's exposure to commodity price risks for both natural gas and crude oil
and condensate wellhead prices. (See "Other Matters - Risk Management").
In September 1992, the Company sold a volumetric production payment for
$326.8 million to a limited partnership. (See "Management's Discussion and
Analysis of Financial Condition and Results of Operations - Capital Resources
and Liquidity - Sale of Volumetric Production Payment").
In March 1995, in a series of transactions with Enron Corp., the Company
exchanged all of its fuel supply and purchase contracts and related price swap
agreements associated with a Texas City cogeneration plant (the "Cogen
Contracts") for certain natural gas price swap agreements (the "Swap
Agreements") of equivalent value. As a result of the transactions, the Company
was relieved of all performance obligations associated with the Cogen Contracts.
The Company will realize net operating revenues and receive corresponding cash
payments of approximately $91 million during the period extending through
December 31, 1999, under the terms of the Swap Agreements. The estimated fair
value of the Swap Agreements was approximately $81 million at the date the Swap
Agreements were received. The net effect of this series of transactions has
resulted in increases in net operating revenues and cash receipts for the
Company during 1995 and 1996 of approximately $13 million and $7 million,
respectively, with offsetting decreases in 1998 and 1999 versus that anticipated
under the Cogen Contracts.
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WELLHEAD VOLUMES AND PRICES, AND LEASE AND WELL EXPENSES
The following table sets forth certain information regarding the Company's
wellhead volumes of and average prices for natural gas per thousand cubic feet
("Mcf"), crude oil and condensate, and natural gas liquids per barrel ("Bbl"),
and average lease and well expenses per thousand cubic feet equivalent
("Mcfe" - natural gas equivalents are determined using the ratio of 6.0 Mcf of
natural gas to 1.0 Bbl of crude oil, condensate or natural gas liquids)
delivered during each of the three years in the period ended December 31, 1997:
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YEAR ENDED DECEMBER 31,
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1997 1996 1995
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VOLUMES (PER DAY)
Natural Gas (MMcf)
United States(1)....................................... 657 608 560
Canada................................................. 101 98 76
Trinidad............................................... 113 124 107
India.................................................. 18 - -
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Total............................................. 889 830 743
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Crude Oil and Condensate (MBbl)
United States.......................................... 11.7 9.2 9.1
Canada................................................. 2.5 2.4 2.4
Trinidad............................................... 3.4 5.2 5.1
India.................................................. 2.3 2.8 2.5
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Total............................................. 19.9 19.6 19.1
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Natural Gas Liquids (MBbl)
United States.......................................... 2.6 1.3 1.0
Canada................................................. 1.3 1.2 .4
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Total............................................. 3.9 2.5 1.4
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AVERAGE PRICES
Natural Gas ($/Mcf)
United States(2)....................................... $ 2.32 $ 2.04 $ 1.39
Canada................................................. 1.43 1.15 .97
Trinidad............................................... 1.05 1.00 .97
India.................................................. 2.79 - -
Composite......................................... 2.07 1.78 1.29
Crude Oil and Condensate ($/Bbl)
United States.......................................... $19.81 $21.88 $17.32
Canada................................................. 17.16 18.01 16.22
Trinidad............................................... 18.68 19.76 16.07
India.................................................. 20.05 20.17 16.81
Composite......................................... 19.30 20.60 16.78
Natural Gas Liquids ($/Bbl)
United States.......................................... $12.76 $14.67 $11.88
Canada................................................. 8.94 9.14 9.74
Composite......................................... 11.54 11.99 11.31
LEASE AND WELL EXPENSES ($/MCFE)
United States.......................................... $ .23 $ .19 $ .19
Canada................................................. .39 .34 .35
Trinidad............................................... .16 .16 .15
India.................................................. .64 .99 1.25(3)
Composite......................................... .26 .22 .22
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(1) Includes 48 MMcf per day in 1997, 1996 and 1995 delivered under the terms of
a volumetric production payment agreement effective October 1, 1992, as
amended.
(2) Includes an average equivalent wellhead value of $1.73 per Mcf in 1997,
$1.17 per Mcf in 1996, and $.80 per Mcf in 1995 for the volumes described in
note (1), net of transportation costs.
(3) Includes certain nonrecurring startup costs.
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COMPETITION
The Company actively competes for reserve acquisitions and
exploration/exploitation leases, licenses and concessions, frequently against
companies with substantially larger financial and other resources. To the extent
the Company's exploration budget is lower than that of certain of its
competitors, the Company may be disadvantaged in effectively competing for
certain reserves, leases, licenses and concessions. Competitive factors include
price, contract terms, and quality of service, including pipeline connection
times and distribution efficiencies. In addition, the Company faces competition
from other producers and suppliers, including competition from other world wide
energy supplies, such as natural gas from Canada.
REGULATION
United States Regulation of Natural Gas and Crude Oil Production. Natural
gas and crude oil production operations are subject to various types of
regulation, including regulation in the United States by state and federal
agencies.
United States legislation affecting the oil and gas industry is under
constant review for amendment or expansion. Also, numerous departments and
agencies, both federal and state, are authorized by statute to issue and have
issued rules and regulations which, among other things, require permits for the
drilling of wells, regulate the spacing of wells, prevent the waste of natural
gas and liquid hydrocarbon resources through proration and restrictions on
flaring, require drilling bonds and regulate environmental and safety matters.
The regulatory burden on the oil and gas industry increases its cost of doing
business and, consequently, affects its profitability.
A substantial portion of the Company's oil and gas leases in the Big Piney
area and in the Gulf of Mexico, as well as some in other areas, are granted by
the federal government and administered by the Bureau of Land Management (the
"BLM") and the Minerals Management Service (the "MMS") federal agencies.
Operations conducted by the Company on federal oil and gas leases must comply
with numerous statutory and regulatory restrictions concerning the above and
other matters. Certain operations must be conducted pursuant to appropriate
permits issued by the BLM and the MMS.
MMS leases contain relatively standardized terms requiring compliance with
detailed MMS regulations and, in the case of offshore leases, orders pursuant to
the Outer Continental Shelf Lands Act ("OCSLA") (which are subject to change by
the MMS). For such offshore operations, lessees must obtain MMS approval for
exploration, development, and production plans prior to the commencement of such
operations. The MMS has promulgated regulations requiring offshore production
facilities located on the OCS to meet stringent engineering and construction
specifications. The MMS also has proposed additional safety-related regulations
concerning the design and operating procedures for OCS production platforms and
pipelines, but these proposed regulations were withdrawn pending further
discussions among interested federal agencies. With respect to conservation, the
MMS has regulations restricting the flaring or venting of natural gas and has
proposed to amend such regulations to prohibit the flaring of liquid
hydrocarbons and oil without prior authorization. The MMS has also promulgated
other regulations governing the plugging and abandonment of wells located
offshore and the removal of all production facilities. Under certain
circumstances, the MMS may require operations on federal leases to be suspended
or terminated. Any such suspension or termination could adversely affect the
Company's interests.
The MMS has issued a notice of proposed rulemaking in which it proposes to
amend its regulations governing the calculation of royalties and the valuation
of crude oil produced from federal leases. This proposed rule would modify the
valuation procedures for both arm's length and non-arm's length crude oil
transactions to decrease reliance on oil posted prices and assign a value to
crude oil that better reflects its market value, establish a new MMS form for
collecting differential data, and amend the valuation procedure for the sale of
federal royalty oil. The Company cannot predict what action the MMS will take on
this matter, nor can it predict how the Company will be affected by any change
to this regulation.
In April 1997, after two years of study, the MMS withdrew proposed changes
to the way it values natural gas for royalty payments. These proposed changes
would have established an alternative market-based method
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to calculate royalties on certain natural gas sold to affiliates or pursuant to
non-arm's length sales contracts. Informal discussions among the MMS and
industry officials are continuing, although it is uncertain whether, and what
changes may be proposed regarding gas royalty valuation. In addition, MMS has
recently announced its intention to issue a proposed rule that would require all
but the smallest producers to be capable of reporting production information
electronically by the end of 1998. The MMS has recently issued a final rule to
clarify the types of costs that are deductible transportation costs for purposes
of royalty valuation of production sold off the lease. In particular, the MMS
will not allow deduction of costs associated with marketer fees, cash out and
other pipeline imbalance penalties, or long-term storage fees. The Company
cannot predict what, if any, effect the new rule will have on its operations.
Sales of crude oil, condensate and natural gas liquids by the Company are
made at unregulated market prices.
The transportation and sale for resale of natural gas in interstate
commerce are regulated pursuant to the Natural Gas Act of 1938 (the "NGA") and
the Natural Gas Policy Act of 1978 (the "NGPA"). These statutes are administered
by the Federal Energy Regulatory Commission (the "FERC"). Effective January 1,
1993, the Natural Gas Wellhead Decontrol Act of 1989 deregulated natural gas
prices for all "first sales" of natural gas, which includes all sales by the
Company of its own production. Consequently, sales of the Company's natural gas
currently may be made at market prices, subject to applicable contract
provisions.
Since 1985, the FERC has endeavored to make natural gas transportation more
accessible to natural gas buyers and sellers on an open and nondiscriminatory
basis. These efforts have significantly altered the marketing and pricing of
natural gas. Commencing in April 1992, the FERC issued Order Nos. 636, 636A and
636B ("Order No. 636"), which mandate a fundamental restructuring of interstate
natural gas pipeline sales and transportation services, including the
"unbundling" by interstate natural gas pipelines of the sales, transportation,
storage, and other components of their previously existing city-gate sales
service, and to separately state the rates for each unbundled service. Under
Order No. 636, unbundled pipeline sales can be made only in the production
areas. The purpose of Order No. 636 is to further enhance competition in the
natural gas industry by assuring the comparability of pipeline sales service and
services offered by a pipeline's competitors. The FERC issued final orders
accepting most pipelines' Order No. 636 compliance filings, and has commenced a
series of one-year reviews of individual pipeline implementations of Order No.
636. The federal appellate courts have largely affirmed the significant features
of Order No. 636 and numerous related orders pertaining to the individual
pipelines. Order No. 636 does not directly regulate the Company's activities,
but has had and will have an indirect effect because of its broad scope. Because
further review of certain of these orders is still possible, various appeals
remain pending and the FERC continues to review and modify its open access
regulations, the outcome of such proceedings and their ultimate impact on the
Company's business is difficult to predict with precision. In many instances,
however, Order No. 636 has substantially reduced or brought to an end interstate
pipelines' traditional role as wholesalers of natural gas in favor of providing
only storage and transportation services. Order No. 636 has also substantially
increased competition in natural gas markets, even though there remains
significant uncertainty with respect to the marketing and transportation of
natural gas. In spite of this uncertainty, Order No. 636 may enhance the
Company's ability to market and transport its natural gas production, although
it may also subject the Company to more restrictive pipeline imbalance
tolerances and greater penalties for violation of such tolerances.
In July 1994, the FERC eliminated a regulation that had rendered virtually
all sales of natural gas by pipeline affiliates, such as the Company, to be
deregulated first sales. As a result, only sales by the Company of its own
production now qualify for this status. All other sales of natural gas by the
Company, such as those of natural gas purchased from third parties, are now
jurisdictional sales subject to a blanket sales certificate issued by the FERC
under the NGA. The Company does not anticipate this change will have any
significant current adverse effects in light of the flexible terms and
conditions of the existing blanket certificate. Such sales are subject to the
future possibility of greater federal oversight, however, including the
possibility the FERC might prospectively impose more restrictive conditions on
such sales.
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The FERC has extended indefinitely its regulations (Order No. 497
regulations) governing relationships between interstate pipelines and their
marketing affiliates, subject to revisions to delete an out-of-date standard and
revise certain reporting and record keeping requirements. Among other matters,
these new rules require pipelines to post on their electronic bulletin boards,
within 24 hours of gas flow, information concerning discounted transportation
provided to marketing affiliates to enable competing marketers to request
comparable discounts. Order No. 497 does not directly regulate the Company's
activities, although a substantial portion of the Company's natural gas
production is sold to or transported by interstate pipeline affiliates which are
subject to the Order. The Company's activities may therefore be indirectly
affected by these regulations.
The Company owns, directly or indirectly, certain natural gas pipelines
that it believes meet the traditional tests the FERC has used to establish a
pipeline's status as a gatherer not subject to FERC jurisdiction under the NGA.
State regulation of gathering facilities generally includes various safety,
environmental, and in some circumstances, nondiscriminatory take requirements,
but does not generally entail rate regulation. Natural gas gathering may receive
greater regulatory scrutiny at both the state and federal levels as the pipeline
restructuring under Order No. 636 is implemented. For example, the State of
Oklahoma in 1995 enacted legislation that essentially requires gatherers to
provide open access, non-discriminatory service. In addition, the FERC has
reiterated that, except in situations in which the gatherer acts in concert with
an interstate pipeline affiliate to frustrate the FERC's transportation
policies, it does not have jurisdiction over natural gas gathering facilities
and services and that such facilities and services are properly regulated by
state authorities. This FERC action may further encourage regulatory scrutiny of
natural gas gathering by state agencies. Indeed, the Texas Railroad Commission
recently approved changes to its regulations governing transportation and
gathering services performed by intrastate pipelines and gatherers, which
prohibit such entities from unduly discriminating in favor of their affiliates.
In addition, the FERC has approved several transfers by interstate pipelines,
including certain of the Company's pipeline affiliates, of gathering facilities
to unregulated independent or affiliated gathering companies. This could
increase competition among gatherers in the affected areas. Certain of the
FERC's orders delineating its new gathering policy are subject to pending court
appeals. The Company's gathering operations could be adversely affected should
they be subject in the future to the application of state or federal regulation
of rates and services.
The FERC has recently announced its intention to reexamine certain of its
transportation-related policies, including the manner in which interstate
pipelines release transportation capacity under Order No. 636, and has announced
new policies concerning the use of alternative, non-cost based methods for
setting rates for interstate natural gas transmission. A number of pipelines
have obtained FERC authorization to charge negotiated rates as one such
alternative. Additionally, the FERC has recently requested comments on the
financial outlook of the gas pipeline industry, including, among other matters,
whether the FERC's current ratemaking policies are suitable in the current
industry environment. Finally, the FERC has recently issued a notice of proposed
rulemaking to further standardize pipeline transportation tariffs, which if
implemented as proposed, may adversely affect the reliability of scheduled
interruptible transportation. While any resulting FERC action would affect the
Company only indirectly, these inquiries are intended to further enhance
competition in natural gas markets.
The FERC has also recently acted on rehearing in a proceeding involving its
regulatory treatment of pipelines located in offshore federal waters, and has
applied the announced policy in several individual proceedings to assert
jurisdiction over several proposed projects.
The Company's natural gas gathering operations may be or become subject to
safety and operational regulations relating to the design, installation,
testing, construction, operation, replacement, and management of facilities.
Pipeline safety issues have recently become the subject of increasing focus in
various political and administrative arenas at both the state and federal
levels. For example, an industry supported bill was enacted in 1996. Additional
pending legislation would, among other things, increase the frequency with which
certain pipelines must be inspected, as well as increase potential civil and
criminal penalties for violations of pipeline safety requirements. The Company
cannot predict what effect, if any, such legislation might have on its
operations, but the industry could be required to incur additional capital
expenditures and increased costs depending on future legislative and regulatory
changes.
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The Company cannot predict the effect that any of the aforementioned orders
or the challenges to such orders will ultimately have on the Company's
operations. Additional proposals and proceedings that might affect the natural
gas industry are considered from time to time by Congress, the FERC and the
courts. The Company cannot predict when or whether any such proposals or
proceedings may become effective. It should also be noted that the natural gas
industry historically has been very heavily regulated; therefore, there is no
assurance that the less regulated approach currently being pursued by the FERC
will continue indefinitely. Thus, the Company cannot predict the ultimate
outcome or durability of the unbundled regulatory regime mandated by Order No.
636.
Environmental Regulation. Various federal, state and local laws and
regulations covering the discharge of materials into the environment, or
otherwise relating to the protection of the environment, may affect the
Company's operations and costs as a result of their effect on natural gas and
crude oil exploration, development and production operations. It is not
anticipated that the Company will be required in the near future to expend
amounts that are material in relation to its total exploration and development
expenditure program by reason of environmental laws and regulations, but
inasmuch as such laws and regulations are frequently changed, the Company is
unable to predict the ultimate cost of compliance.
Canadian Regulation. In Canada, the petroleum industry operates under
federal and provincial legislation and regulations governing land tenure,
royalties, production rates, environmental protection, exports and other
matters. The price of natural gas and crude oil in Canada has been deregulated
and is now determined by market conditions and negotiations between buyers and
sellers.
Various matters relating to the transportation and export of natural gas
continue to be subject to regulation by both provincial and federal agencies;
however, the North American Free Trade Agreement may have reduced the risk of
altering cross-border commercial transactions.
Canadian governmental regulations may have a material effect on the
economic parameters for engaging in oil and gas activities in Canada and may
have a material effect on the advisability of investments in Canadian oil and
gas drilling activities. The Company is monitoring political, regulatory and
economic developments in Canada.
Other International Regulation. The Company's exploration and production
operations outside North America are subject to various types of regulations
imposed by the respective governments of the countries in which the Company's
operations are conducted, and may affect the Company's operations and costs
within that country. The Company currently has producing operations offshore
Trinidad and India and exploration, exploitation and development activities in
other selected international areas.
RELATIONSHIP BETWEEN THE COMPANY AND ENRON CORP.
Ownership of Common Stock. Enron Corp. owns a majority of the outstanding
shares of Common Stock of the Company. Through its ability to elect all of the
directors of the Company, Enron Corp. generally has the ability to control
matters relating to the management and policies of the Company, including
determination with respect to acquisition or disposition of Company assets, the
Company's exploration, development, and operating expenditure plans, future
issuances of Common Stock or other securities of the Company and dividends
payable on the Common Stock.
Effective December 14, 1995, the Company ceased to be included in the
consolidated federal income tax return filed by Enron Corp., and the tax
allocation agreement (the "Base Agreement") previously in effect between the
Company and Enron Corp. was terminated. In addition, effective December 14,
1995, the Company and Enron Corp. entered into a new tax agreement (the "1995
Agreement") pursuant to which, among other things, Enron Corp. agreed (in
exchange for the payment of $13 million by the Company) to be liable for, and
indemnify the Company against, all U.S. federal and state income taxes and
certain foreign taxes imposed on the Company for periods prior to the date Enron
Corp. reduced its ownership in the Company to less than 80%. In 1997, the
Company and Enron Corp. agreed to terminate the 1995 Agreement and enter into a
new tax allocation agreement. In the new agreement, Enron Corp. agreed to refund
the $13 million payment made by the Company pursuant to the 1995 Agreement, the
Company agreed to release
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Enron Corp. from the liabilities assumed related to the $13 million payment and
the parties agreed to indemnify each other in a manner consistent with the Base
Agreement. Enron Corp. also advanced the Company approximately $50 million to
fund certain federal income taxes related to the 1995 taxable year. This advance
is to be repaid in annual installments through January 1, 2001. The Company does
not believe that the cessation of consolidated tax reporting with Enron Corp.,
the termination of the Base Agreement concurrent with deconsolidation, the
signing of the 1995 Agreement and/or the newest tax allocation agreement with
Enron Corp. have had or will have in the future a material adverse effect on its
financial condition or results of operations.
Conflicts of Interest. The nature of the respective businesses of the
Company and Enron Corp. and its other affiliates ("Enron") is such as to give
rise to conflicts of interest between the companies from time to time. Conflicts
may arise, for example, with respect to transactions involving purchases, sales
and transportation of natural gas and other business dealings between the
Company and Enron, potential acquisitions of businesses or crude oil and natural
gas properties or the payment of dividends by the Company. In connection with
its finance and trading business conducted by its subsidiaries, Enron Capital &
Trade Resources Corp. ("ECT") and Enron International Capital & Trade Corp.
("EICT"), Enron provides or arranges financing for others, including exploration
and production companies, some of which compete with the Company. Enron may make
investments in the debt or equity of such companies, may make loans secured by
crude oil and natural gas properties or securities of crude oil and natural gas
companies, may acquire production payments or may receive interests in crude oil
and natural gas properties as equity components of lending transactions. As a
result of its finance and trading business, Enron may also acquire crude oil and
natural gas properties or companies upon foreclosure of secured loans or as part
of a borrower's rearrangement of its obligations. Enron also has interests in
entities such as Joint Energy Development Investments Limited Partnership, which
makes debt and equity investments in energy-related businesses, including
exploration and production companies. The acquisition, exploration, development
and production activities of entities in which Enron has interests may directly
or indirectly compete with the Company's business.
Business Opportunity Agreement. In December 1997, Enron Corp. and the
Company entered into an Equity Participation and Business Opportunity Agreement
(the "Business Opportunity Agreement") that defines certain obligations that
Enron owes to the Company and relieves Enron from certain obligations to the
Company that it might otherwise have, including the obligation to offer certain
business opportunities to the Company. Enron has advised the Company that,
although it believes that it has conducted its business in a manner that is
consistent with its duties as a majority shareholder of the Company, it was
motivated to enter into the Business Opportunity Agreement because of the
difficulty of determining the applicability of the law relating to duties that
Enron may owe to the Company in connection with Enron's finance and trading
business and because of Enron's desire to have more flexibility in pursuing
business opportunities identified by or developed solely by Enron personnel. The
Business Opportunity Agreement was approved by the Board of Directors of the
Company after it was approved unanimously by a special committee of the Board of
Directors consisting of the Company's independent directors. The special
committee retained its own legal and financial advisers in connection with its
evaluation of Enron's proposal, and the Business Opportunity Agreement as
executed reflects significant concessions on Enron's part resulting from its
negotiations with members of the special committee.
The Business Opportunity Agreement provides generally that, so long as such
activities are conducted in compliance with the Business Opportunity Agreement
in all material respects, Enron may pursue business opportunities independently
of the Company. The Business Opportunity Agreement contains an acknowledgment by
the Company that Enron's finance and trading business may result in the
acquisition by Enron of oil and gas properties or companies and that in certain
cases Enron or entities in which Enron has an interest may acquire such assets
pursuant to bidding or auction processes in which the Company is also a bidder.
In the Business Opportunity Agreement, the Company acknowledges and agrees that
such activities may have an impact on the Company or the price it pays for
properties or securities it purchases from others, that Enron or entities in
which it has an interest may acquire direct or indirect interests in oil and gas
properties or companies as a result of such activities, may own, operate and
control any such assets in connection therewith, and may acquire additional oil
and gas properties or companies or pursue opportunities related thereto in
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connection therewith, in each case without any duty to offer all or any portion
of such assets or opportunities to the Company. The Business Opportunity
Agreement contains an acknowledgment and agreement by the Company that, to the
extent that a court might hold that the conduct of such activity is a breach of
a duty to the Company (and without admitting that the conduct of such activity
is such a breach of duty), the Company waives any and all claims and causes of
action that it may have to claim that the conduct of such activity is a breach
of a duty to the Company.
The Business Opportunity Agreement contains certain restrictions on the
conduct of Enron's business. It also provides that, except with respect to
business opportunities pursued jointly by Enron and the Company and except as
otherwise agreed to between Enron and the Company, Enron's business will be
conducted through the use of its own personnel and assets and not with the use
of any personnel or assets of the Company. Thus, without the consent of the
Company, the finance and trading business conducted by ECT, EICT or other Enron
entities may only involve business opportunities identified by or presented to
ECT personnel, EICT personnel or other Enron personnel and developed and pursued
solely through the use of the personnel and assets of ECT, EICT or other Enron
entities. Enron has agreed that, so long as it controls the Company, it will not
pursue any business opportunity a majority of the value of which involves oil
and gas properties if the opportunity is first presented to an officer or
director of Enron who is also an officer or director of the Company at the time
such opportunity is presented, unless Enron first offers such opportunity to the
Company. The Business Opportunity Agreement states that its provisions relate
exclusively to the duties that Enron owes the Company and that nothing in the
Business Opportunity Agreement affects the fiduciary or other duties owed to the
Company by any individual director or officer of the Company in his or her
capacity as such. In this connection, Enron has agreed that its representatives
on the Board of Directors of the Company will not, for the purpose of enabling
Enron to pursue an opportunity in the oil and gas business, vote in such a
manner as to effectively prevent, prohibit or restrict the Company from pursuing
such opportunity.
In consideration for the Company's agreements in the Business Opportunity
Agreement, Enron provided valuable consideration to the Company, including
options to purchase common stock of Enron that will give the Company the
opportunity to participate in future appreciation in value of Enron, including
any appreciation in value resulting from activities that the Company has agreed
to permit Enron and its subsidiaries to pursue. Enron granted the Company ten
year options to purchase 3,200,000 shares of Enron common stock at $39.1875 per
share, the closing price per share on the date that the Company's Board of
Directors approved the Business Opportunity Agreement. The options vest in
accordance with a schedule that provides that 25% vested immediately, 15% vest
on the anniversary of the Business Opportunity Agreement in 1998 and 10% vest
each anniversary thereafter until all of the options are vested. Vesting will be
accelerated in the event of a change of control of the Company. For such
purposes a "change of control" means that (a) Enron no longer owns capital stock
of the Company representing at least 35% of the voting power for the election of
directors and (b) a majority of the members of the Board of Directors of the
Company consists of persons who are not officers or directors of Enron or any
affiliate of Enron other than the Company. The Business Opportunity Agreement
also included (i) an agreement to replace the existing services agreement, under
which Enron provides certain services to the Company, with a new services
agreement under which the Company's maximum payments to Enron for allocated
indirect costs will be reduced by $2.8 million per year, (ii) an agreement by
Enron relieving the Company of the obligation to bear the costs of any
registration of sales by Enron of shares of common stock of the Company, (iii)
an agreement by Enron to pay the costs of registration of the Company's sales of
Enron common stock acquired upon exercise of the options granted in the Business
Opportunity Agreement, (iv) an agreement that if Enron takes any action that
results in the loss by the Company of its status as an "independent producer"
under the Internal Revenue Code, Enron will pay the Company each year through
2006 the lesser of (a) $1 million and (b) an amount which, after payment of
applicable taxes, will compensate the Company for the additional income tax
liability resulting from the loss of independent producer status, (v) an
agreement that if Enron requests that the Company relocate its offices, and if
the Company agrees to do so, Enron will pay the Company's moving expenses,
including expenses of building out or refurbishing the space in its new offices
and expenses of removing and reinstalling the Company's telecommunications and
information systems facilities and (vi) an agreement by Enron to reimburse the
Company for the costs and expenses of legal and financial consultants retained
to assist the special committee in connection with the Business Opportunity
Agreement. In addition, pursuant to the
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Business Opportunity Agreement Enron agreed to cause its subsidiary, Houston
Pipe Line Company, to enter into various agreements with the Company rearranging
certain existing contractual arrangements between them, and Enron and the
Company entered into a licensing agreement covering the Enron name and mark and
recognizing that the EOG and EOGI names and marks belong to the Company. In the
Business Opportunity Agreement Enron and the Company also entered into
agreements in principle regarding the manner in which they will share the
burdens and benefits of the integrated projects under joint development by Enron
and the Company in Qatar, Mozambique and Uzbekistan. The agreements in principle
provide generally that the Company's interests in these projects will be 20%,
20% and 80%, respectively, of the combined ownership interest of the Company and
Enron.
The Business Opportunity Agreement also contains provisions that give Enron
the right to maintain its equity interest in the Company at certain levels. It
provides that if the Company issues additional shares of its capital stock Enron
will have the right to purchase additional shares of capital stock of the
Company as follows: (i) if Enron owns a majority interest, Enron will have the
right to purchase sufficient shares to permit it to retain its majority
interest; (ii) if Enron does not own a majority interest but accounts for the
assets and operations of the Company on a consolidated basis for financial
reporting purposes Enron will have the right to purchase sufficient shares to
permit it to continue to account for the Company on a consolidated basis; and
(iii) if Enron accounts for the assets and operations of the Company using the
equity method for financial reporting purposes Enron will have the right to
purchase sufficient shares to permit it to continue to account for the Company
using the equity method. Any such purchase by Enron will be for cash at 97% of
the average closing price per share over a specified 20 day period (reflecting a
3% private placement discount).
Contractual Arrangements. As part of the Business Opportunity Agreement,
the Company entered into a Services Agreement (the "Services Agreement") with
Enron Corp. effective January 1, 1997, pursuant to which Enron Corp. provides
various services, such as maintenance of certain employee benefit plans,
provision of certain telecommunications and computer services, lease of certain
office space and the provision of certain purchasing and operating services and
certain other corporate staff and support services. Such services historically
have been supplied to the Company by Enron Corp., and the Services Agreement
provides for the further delivery of such services substantially identical in
nature and quality to those services previously provided. The Company has agreed
to a fixed rate for the rental of office space and to reimburse Enron Corp. for
all other direct costs incurred in rendering services to the Company under the
contract and to pay Enron Corp. for allocated indirect costs incurred in
rendering such services up to a maximum of approximately $5.3 million in 1997.
The limit on cost for the allocated indirect services provided by Enron Corp. to
the Company will increase in subsequent years for inflation and certain changes
in the Company's allocation bases. The Services Agreement is for an initial term
of ten years through December 2006 and will continue thereafter until terminated
by either party.
In March 1995, in a series of transactions with Enron Corp., the Company
exchanged all of its fuel supply and purchase contracts and related price swap
agreements associated with a Texas City cogeneration plant (the "Cogen
Contracts") for certain natural gas price swap agreements (the "Swap
Agreements") of equivalent value. As a result of the transactions, the Company
was relieved of all performance obligations associated with the Cogen Contracts.
The Company will realize net operating revenues and receive corresponding cash
payments of approximately $91 million during the period extending through
December 31, 1999 under the terms of the Swap Agreements. The estimated fair
value of the Swap Agreements was approximately $81 million at the date the Swap
Agreements were received. The net effect of this series of transactions has
resulted in increases in net operating revenues and cash receipts for the
Company during 1995 and 1996 of approximately $13 million and $7 million,
respectively, with offsetting decreases in 1998 and 1999 versus that anticipated
under the Cogen Contracts.
The Company and Enron Corp. have in the past entered into material
intercompany transactions and agreements incident to their respective
businesses, and they may be expected to enter into such transactions and
agreements in the future. Such transactions and agreements have related to,
among other things, the purchase and sale of natural gas and crude oil, hedging
and trading activities, the financing of exploration and development efforts by
the Company, and the provision of certain corporate services. (See "Marketing"
and the Consolidated Financial Statements and notes thereto). The Company
believes that its existing
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transactions and agreements with Enron Corp. have been at least as favorable to
the Company as could be obtained from third parties, and the Company intends
that the terms of any future transactions and agreements between the Company and
Enron Corp. will be at least as favorable to the Company as could be obtained
from third parties.
OTHER MATTERS
Energy Prices. Since the Company is primarily a natural gas company, it is
more significantly impacted by changes in natural gas prices than in the prices
for crude oil, condensate or natural gas liquids. During recent periods,
domestic natural gas has been priced significantly below parity with crude oil
and condensate based on the energy equivalency of, and differences in
transportation and processing costs associated with, the respective products
although that relationship improved during 1996. This imbalance in parity has
been primarily driven by, among other things, a supply of domestic natural gas
volumes in excess of demand requirements. The Company is unable to predict when
this supply imbalance may be resolved due to the significant impacts of factors
such as general economic conditions, technology developments, weather and other
international energy supplies over which the Company has no control.
Average North America wellhead natural gas prices have fluctuated, at times
rather dramatically, during the last three years. While these fluctuations
resulted in a decrease in average wellhead natural gas prices realized by the
Company of 20% from 1994 to 1995, the average North America wellhead natural gas
price received by the Company increased 43% from 1995 to 1996 and 15% from 1996
to 1997. Wellhead natural gas volumes from Trinidad are sold at prices that are
based on a fixed schedule with periodic escalations. Natural gas deliveries in
India commenced in June 1997 and, under the terms of the production sharing
contracts, the price of such deliveries are indexed to a basket of world market
fuel oil quotations structured to include floor and ceiling limits. Due to the
many uncertainties associated with the world political environment, the
availabilities of other world wide energy supplies and the relative competitive
relationships of the various energy sources in the view of the consumers, the
Company is unable to predict what changes may occur in natural gas prices in the
future.
Substantially all of the Company's wellhead crude oil and condensate is
sold under various terms and arrangements at market responsive prices. Crude oil
and condensate prices also have fluctuated during the last three years. Due to
the many uncertainties associated with the world political environment, the
availabilities of other world wide energy supplies and the relative competitive
relationships of the various energy sources in the view of the consumers, the
Company is unable to predict what changes may occur in crude oil and condensate
prices in the future.
Risk Management. The Company engages in price risk management activities
from time to time primarily for non-trading and to a lesser extent for trading
purposes. Derivative financial instruments (primarily price swaps and costless
collars) are utilized for non-trading purposes to hedge the impact of market
fluctuations of natural gas and crude oil market prices on net income and cash
flow.
At December 31, 1997, the Company had outstanding natural gas costless
collar transactions, designated as hedges, covering approximately 37 trillion
British thermal units ("TBtu") of natural gas for 1998 and price swaps covering
approximately 4 TBtu of natural gas for each of the years 1999 and 2000 and
approximately 1.3 MMBbl and .7 MMBbl of crude oil and condensate for the years
1998 and 1999, respectively. The fair value of the positions was a net revenue
increase of $1 million at December 31, 1997.
At December 31, 1997, the Company had outstanding options, exercisable by a
counterparty, covering notional natural gas volumes averaging 3 TBtu per month
during 1998. The fair value of these options at December 31, 1997 was a revenue
reduction of $10.5 million. The Company also had outstanding at December 31,
1997 natural gas price swap positions in the same notional quantities as the
1998 options with a fair value revenue increase of $4.2 million.
At December 31, 1997, based on the portion of the Company's anticipated
natural gas volumes for 1998 for which prices have not, in effect, been hedged
using NYMEX-related commodity market transactions and long-term marketing
contracts, the Company's net income and cash flow sensitivity to changing
natural gas
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prices is approximately $19 million for each $.10 per Mcf change in average
wellhead natural gas prices. While the Company is not impacted as significantly
by changing crude oil prices for those volumes not otherwise hedged, its net
income and cash flow sensitivity is approximately $5 million for $1.00 per
barrel change in average wellhead crude oil prices.
Tight Gas Sand Tax Credits (Section 29) and Severance Tax Exemption. United
States federal tax law provides a tax credit for production of certain fuels
produced from nonconventional sources (including natural gas produced from tight
formations), subject to a number of limitations. Fuels qualifying for the credit
must be produced from a well drilled or a facility placed in service after
November 5, 1990 and before January 1, 1993, and must be sold before January 1,
2003.
The credit, which is currently approximately $.52 per million British
thermal units ("MMBtu") of natural gas, is computed by reference to the price of
crude oil, and is phased out as the price of crude oil exceeds $23.50 in 1980
dollars (adjusted for inflation) with complete phaseout if such price exceeds
$29.50 in 1980 dollars (similarly adjusted). Under this formula, the
commencement of phaseout would be triggered if the average price for crude oil
rose above approximately $47 per barrel in current dollars. Significant benefits
from the tax credit have accrued and continue to accrue to the Company since a
portion (and in some cases a substantial portion) of the Company's natural gas
production from new wells drilled after November 5, 1990, and before January 1,
1993, on the Company's leases in several of the Company's significant producing
areas qualify for this tax credit.
Natural gas production from wells spudded or completed after May 24, 1989
and before September 1, 1996 in tight formations in Texas qualifies for a
ten-year exemption, ending August 31, 2001, from severance taxes, subject to
certain limitations. In 1995, the drilling qualification period was extended in
a modified and somewhat reduced form from September 1996 through August 2002.
Consequently, new qualifying production will be added prospectively to that
presently qualified.
Other. All of the Company's natural gas and crude oil activities are
subject to the risks normally incident to the exploration for and development
and production of natural gas and crude oil, including blowouts, cratering and
fires, each of which could result in damage to life and property. Offshore
operations are subject to usual marine perils, including hurricanes and other
adverse weather conditions, and governmental regulations as well as interruption
or termination by governmental authorities based on environmental and other
considerations. In accordance with customary industry practices, insurance is
maintained by the Company against some, but not all, of the risks. Losses and
liabilities arising from such events could reduce revenues and increase costs to
the Company to the extent not covered by insurance.
The Company's operations outside of North America are subject to certain
risks, including expropriation of assets, risks of increases in taxes and
government royalties, renegotiation of contracts with foreign governments,
political instability, payment delays, limits on allowable levels of production
and current exchange and repatriation losses, as well as changes in laws,
regulations and policies governing operations of foreign companies generally.
16
<PAGE> 19
CURRENT EXECUTIVE OFFICERS OF THE REGISTRANT
The current executive officers of the Company and their names and ages are
as follows (all positions are with the Company unless otherwise noted):
<TABLE>
<CAPTION>
NAME AGE POSITION
---- --- --------
<S> <C> <C>
Forrest E. Hoglund.............................. 64 Chairman of the Board and Chief
Executive Officer; Director
Mark G. Papa.................................... 51 President and Chief Operating Officer
and President, North America Operations
Edmund P. Segner, III........................... 44 Vice Chairman and Chief of Staff
Dennis M. Ulak.................................. 44 President, International Operations and
Chairman of the Board and Chief
Executive Officer, Enron Oil & Gas
International, Inc.
Jeffrey B. Sherrick............................. 43 President and Chief Operating Officer,
Enron Oil & Gas International, Inc.
Barry Hunsaker, Jr.............................. 47 Senior Vice President and General
Counsel
Loren M. Leiker................................. 44 Senior Vice President, Exploration
Walter C. Wilson................................ 55 Senior Vice President and Chief
Financial Officer
Ben B. Boyd..................................... 56 Vice President and Controller
</TABLE>
Forrest E. Hoglund joined the Company as Chairman of the Board, Chief
Executive Officer and Director in September 1987. He also served as President of
the Company from May 1990 until December 1996. Mr. Hoglund is an advisory
director of Chase Bank of Texas, National Association.
Mark G. Papa was elected President and Chief Operating Officer in September
1997 and President of the Company in December 1996 and has been
President - North America Operations since February 1994. From May 1986 through
January 1994, Mr. Papa served as Senior Vice President - Operations. Mr. Papa
joined Belco Petroleum Corporation, a predecessor of the Company, in 1981.
Edmund P. Segner, III became Vice Chairman and Chief of Staff of the
Company in September 1997. Mr. Segner was a director of the Company from January
1997 to October 1997. Mr. Segner joined Enron Corp. in 1988 and was Executive
Vice President and Chief of Staff.
Dennis M. Ulak has been President - International Operations since January
1996 with responsibility for activities outside North America. Mr. Ulak also
serves as Chairman and Chief Executive Officer of Enron Oil & Gas International,
Inc. Mr. Ulak joined the Company in March 1987 as Senior Counsel and was named
Assistant General Counsel for international operations in February 1989,
Assistant General Counsel in August 1990 and Vice President and General Counsel
in March 1992.
Jeffrey B. Sherrick joined the Company in July 1989 and has been President
and Chief Operating Officer of Enron Oil & Gas International, Inc., since
September 1997. Mr. Sherrick was previously Senior Vice President, Acquisitions
and Engineering of the Company.
Barry Hunsaker, Jr. has been Senior Vice President and General Counsel
since he joined the Company in May 1996. Prior to joining the Company, Mr.
Hunsaker was a partner in the law firm of Vinson & Elkins L.L.P.
Loren M. Leiker joined the Company in April 1989 and has been Senior Vice
President, Exploration since March 1997. Mr. Leiker was previously Vice
President, Exploration of the Company.
Walter C. Wilson joined the Company in November 1987 and has been Senior
Vice President and Chief Financial Officer since May 1991.
Ben B. Boyd joined the Company in March 1989 and has been Vice President
and Controller since March 1991.
17
<PAGE> 20
ITEM 2. PROPERTIES
OIL AND GAS EXPLORATION AND PRODUCTION PROPERTIES AND RESERVES
Reserve Information. For estimates of the Company's net proved and proved
developed reserves of natural gas and liquids, including crude oil, condensate
and natural gas liquids, see "Supplemental Information to Consolidated Financial
Statements."
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future rates of production and timing of
development expenditures, including many factors beyond the control of the
producer. The reserve data set forth in Supplemental Information to Consolidated
Financial Statements represent only estimates. Reserve engineering is a
subjective process of estimating underground accumulations of natural gas and
liquids, including crude oil, condensate and natural gas liquids, that cannot be
measured in an exact manner. The accuracy of any reserve estimate is a function
of the amount and quality of available data and of engineering and geological
interpretation and judgment. As a result, estimates of different engineers
normally vary. In addition, results of drilling, testing and production
subsequent to the date of an estimate may justify revision of such estimate.
Accordingly, reserve estimates are often different from the quantities
ultimately recovered. The meaningfulness of such estimates is highly dependent
upon the accuracy of the assumptions upon which they were based.
In general, the volume of production from oil and gas properties owned by
the Company declines as reserves are depleted. Except to the extent the Company
acquires additional properties containing proved reserves or conducts successful
exploration and development activities, or both, the proved reserves of the
Company will decline as reserves are produced. Volumes generated from future
activities of the Company are therefore highly dependent upon the level of
success in finding or acquiring additional reserves and the costs incurred in so
doing. The Company's estimates of reserves filed with other federal agencies
agree with the information set forth in Supplemental Information to Consolidated
Financial Statements.
18
<PAGE> 21
Acreage. The following table summarizes the Company's developed and
undeveloped acreage at December 31, 1997. Excluded is acreage in which the
Company's interest is limited to owned royalty, overriding royalty and other
similar interests.
<TABLE>
<CAPTION>
DEVELOPED UNDEVELOPED TOTAL
--------------------- --------------------- ---------------------
GROSS NET GROSS NET GROSS NET
--------- --------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C> <C>
United States
California.................... 17,691 14,951 746,318 727,230 764,009 742,181
Texas......................... 275,995 182,999 518,376 364,083 794,371 547,082
Offshore Gulf of Mexico....... 312,726 141,080 541,891 404,956 854,617 546,036
Wyoming....................... 148,999 113,124 262,786 218,658 411,785 331,782
Oklahoma...................... 148,637 85,494 113,274 83,123 261,911 168,617
New Mexico.................... 60,136 31,070 84,224 52,519 144,360 83,589
Utah.......................... 57,820 46,512 33,062 27,564 90,882 74,076
Kansas........................ 9,698 8,699 4,013 2,987 13,711 11,686
Colorado...................... 8,353 1,233 26,380 13,645 34,733 14,878
Mississippi................... 4,761 4,516 33,161 25,524 37,922 30,040
Pennsylvania.................. 1,103 735 16,089 10,727 17,192 11,462
Louisiana..................... 6,131 4,938 4,608 1,592 10,739 6,530
Other......................... 5,793 3,396 6,788 4,766 12,581 8,162
--------- --------- --------- --------- --------- ---------
Total................. 1,057,843 638,747 2,390,970 1,937,374 3,448,813 2,576,121
Canada
Alberta....................... 359,080 228,908 288,887 245,067 647,967 473,975
Saskatchewan.................. 191,483 175,677 223,228 217,182 414,711 392,859
Manitoba...................... 11,743 9,954 23,848 21,956 35,591 31,910
British Columbia.............. 656 164 6,138 6,138 6,794 6,302
--------- --------- --------- --------- --------- ---------
Total Canada.......... 562,962 414,703 542,101 490,343 1,105,063 905,046
Other International
China......................... - - 1,849,531 924,766 1,849,531 924,766
Venezuela..................... - - 268,413 241,572 268,413 241,572
India......................... 98,300 29,490 564,307 169,292 662,607 198,782
Trinidad...................... 4,200 3,990 171,459 167,716 175,659 171,706
France........................ - - 168,032 168,032 168,032 168,032
--------- --------- --------- --------- --------- ---------
Total Other
International....... 102,500 33,480 3,021,742 1,671,378 3,124,242 1,704,858
--------- --------- --------- --------- --------- ---------
Total............... 1,723,305 1,086,930 5,954,813 4,099,095 7,678,118 5,186,025
========= ========= ========= ========= ========= =========
</TABLE>
Producing Well Summary. The following table reflects the Company's
ownership in gas and oil wells located in Texas, the Gulf of Mexico, Oklahoma,
New Mexico, Utah, Wyoming, and various other states, Canada, Trinidad and India
at December 31, 1997. Gross gas and oil wells include 279 with multiple
completions.
<TABLE>
<CAPTION>
PRODUCTIVE WELLS
----------------
GROSS NET
------ ------
<S> <C> <C>
Gas......................................................... 4,622 3,413
Oil......................................................... 703 464
----- -----
Total............................................. 5,325 3,877
===== =====
</TABLE>
19
<PAGE> 22
Drilling and Acquisition Activities. During the years ended December 31,
1997, 1996 and 1995 the Company spent approximately $693 million, $599 million
and $514 million, respectively, for exploratory and development drilling and
acquisition of leases and producing properties. The Company drilled,
participated in the drilling of or acquired wells as set out in the table below
for the periods indicated:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------------------
1997 1996 1995
-------------- -------------- --------------
GROSS NET GROSS NET GROSS NET
----- ------ ----- ------ ----- ------
<S> <C> <C> <C> <C> <C> <C>
Development Wells Completed
North America
Gas......................................... 467 352.90 396 325.04 334 251.06
Oil......................................... 94 74.85 80 57.46 69 55.16
Dry......................................... 101 80.01 80 68.77 61 49.21
--- ------ --- ------ --- ------
Total.................................. 662 507.76 556 451.27 464 355.43
Outside North America
Gas......................................... 12 3.60 - - 3 2.85
Oil......................................... 6 1.80 1 .30 3 2.85
Dry......................................... - - - - 1 .95
--- ------ --- ------ --- ------
Total.................................. 18 5.40 1 .30 7 6.65
--- ------ --- ------ --- ------
Total Development.............................. 680 513.16 557 451.57 471 362.08
--- ------ --- ------ --- ------
Exploratory Wells Completed
North America
Gas......................................... 8 5.12 14 10.36 5 4.13
Oil......................................... - - 1 .78 8 3.61
Dry......................................... 12 7.53 26 19.00 21 13.28
--- ------ --- ------ --- ------
Total.................................. 20 12.65 41 30.14 34 21.02
Outside North America
Gas......................................... - - - - 6 4.90
Oil......................................... - - - - - -
Dry......................................... - - 1 .50 - -
--- ------ --- ------ --- ------
Total.................................. - - 1 .50 6 4.90
--- ------ --- ------ --- ------
Total Exploratory.............................. 20 12.65 42 30.64 40 25.92
--- ------ --- ------ --- ------
Total.................................. 700 525.81 599 482.21 511 388.00
Wells in Progress at end of period............... 44 36.39 87 61.08 52 32.71
--- ------ --- ------ --- ------
Total.................................. 744 562.20 686 543.29 563 420.71
=== ====== === ====== === ======
Wells Acquired
Gas......................................... 227 82.45* 350 148.20* 277 101.70*
Oil......................................... 48 20.50* 5 .65 5 .46*
--- ------ --- ------ --- ------
Total.................................. 275 102.95 355 148.85 282 102.16
=== ====== === ====== === ======
</TABLE>
- ---------------
* Includes the acquisition of additional interests in certain wells in which the
Company previously held an interest.
All of the Company's drilling activities are conducted on a contract basis
with independent drilling contractors. The Company owns no drilling equipment.
ITEM 3. LEGAL PROCEEDINGS
The Company and its subsidiaries and related companies are named defendants
in numerous lawsuits and named parties in numerous governmental proceedings
arising in the ordinary course of business. While the outcome of lawsuits or
other proceedings against the Company cannot be predicted with certainty,
management does not expect these matters to have a material adverse effect on
the financial condition or results of operations of the Company.
20
<PAGE> 23
Enron Oil & Gas India Ltd. ("EOGIL"), a wholly-owned subsidiary of the
Company, is a respondent in two public interest lawsuits filed in the Delhi High
Court, India. The first (the "Wadehra Action") was brought by B. L. Wadehra, an
Indian public interest lawyer, against the Union of India, EOGIL, EOGIL co-
participants in the Panna and Mukta fields, Reliance Industries Limited
("Reliance") and Oil & Natural Gas Corporation Limited ("ONGC"), and certain
other respondents. ONGC is the Indian national oil company and is wholly-owned
by the Union of India. The second suit (the "CPIL Action") was brought by the
Centre for Public Interest Litigation and the National Alliance of People's
Movement against the Union of India, the Central Bureau of Investigation, ONGC,
Reliance and EOGIL. Petitioners in both the Wadehra Action and the CPIL Action
allege various improprieties in the award of the Panna and Mukta fields to
EOGIL, Reliance and ONGC, and seek the cancellation of the Production Sharing
Contract for the Panna and Mukta fields. The Union of India is vigorously
disputing these allegations. The Company believes that the public competitive
bidding process for the fields was fair and that the award of these fields to
EOGIL, Reliance and ONGC was proper. Although no assurances can be given, based
on currently available information the Company believes that the claims made by
the petitioners in both actions are without merit, and that the ultimate
resolution of these matters will not have a material adverse effect on its
financial condition or results of operations.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no matters submitted to a vote of security holders during the
fourth quarter of 1997.
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED SHAREHOLDER
MATTERS
The following table sets forth, for the periods indicated, the high and low
sales prices per share for the common stock of the Company, as reported on the
New York Stock Exchange Composite Tape, and the amount of cash dividends paid
per share.
<TABLE>
<CAPTION>
PRICE RANGE
---------------- CASH
HIGH LOW DIVIDENDS
------ ------ ---------
<S> <C> <C> <C>
1995
First Quarter......................................... $24.88 $17.13 $.03
Second Quarter........................................ 24.75 20.25 .03
Third Quarter......................................... 25.38 20.00 .03
Fourth Quarter........................................ 24.88 18.75 .03
1996
First Quarter......................................... $28.50 $22.38 $.03
Second Quarter........................................ 28.63 23.88 .03
Third Quarter......................................... 30.63 22.88 .03
Fourth Quarter........................................ 28.38 23.25 .03
1997
First Quarter......................................... $27.00 $19.88 $.03
Second Quarter........................................ 21.75 17.50 .03
Third Quarter......................................... 25.06 17.69 .03
Fourth Quarter........................................ 23.81 18.50 .03
</TABLE>
As of March 1, 1998, there were approximately 376 record holders of the
Company's common stock, including individual participants in security position
listings. There are an estimated 21,000 beneficial owners of the Company's
common stock, including shares held in street name.
The Company currently intends to continue to pay quarterly cash dividends
on its outstanding shares of common stock. However, the determination of the
amount of future cash dividends, if any, to be declared and paid will depend
upon, among other things, the financial condition, funds from operations, level
of exploration and development expenditure opportunities and future business
prospects of the Company.
21
<PAGE> 24
ITEM 6. SELECTED FINANCIAL DATA
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------------------------------------
1997 1996 1995 1994 1993
---------- ---------- ---------- ---------- ----------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
STATEMENT OF INCOME DATA:
Net operating revenues....... $ 783,501 $ 730,648 $ 648,702 $ 625,823 $ 581,020
Operating expenses
Lease and well............. 96,064 76,618 69,463 60,384 59,344
Exploration................ 57,696 55,009 42,044 41,811 36,921
Dry hole................... 17,303 13,193 12,911 17,197 18,355
Impairment of unproved oil
and gas properties...... 27,213 21,226 23,715 24,936 20,467
Depreciation, depletion and
amortization............ 278,179 251,278 216,047 242,182 249,704
General and
administrative.......... 54,415 56,405 56,626 51,418 45,274
Taxes other than income.... 59,856 48,089 32,587 28,254 35,396
---------- ---------- ---------- ---------- ----------
Total.............. 590,726 521,818 453,393 466,182 465,461
---------- ---------- ---------- ---------- ----------
Operating income............. 192,775 208,830 195,309 159,641 115,559
Other income (expense), net
........................... (1,588) (5,007) 669 2,783 6,635
Interest expense (net of
interest capitalized)...... 27,717 12,861 11,924 8,489 9,921
---------- ---------- ---------- ---------- ----------
Income before income taxes
........................... 163,470 190,962 184,054 153,935 112,273
Income tax provision
(benefit)(1)............... 41,500(2) 50,954(3) 41,936(4) 5,937(5) (25,752)(6)
---------- ---------- ---------- ---------- ----------
Net income................... $ 121,970 $ 140,008 $ 142,118 $ 147,998 $ 138,025
========== ========== ========== ========== ==========
Earnings per share of common
stock(7)
Basic...................... $ .78 $ .88 $ .89 $ .93 $ .86
========== ========== ========== ========== ==========
Diluted.................... $ .77 $ .87 $ .88 $ .92 $ .85
========== ========== ========== ========== ==========
Average number of common
shares(7)
Basic...................... 157,376 159,853 159,917 159,845 159,966
========== ========== ========== ========== ==========
Diluted.................... 158,160 161,525 161,132 160,654 161,784
========== ========== ========== ========== ==========
</TABLE>
<TABLE>
<CAPTION>
AT DECEMBER 31,
------------------------------------------------------------------
1997 1996 1995 1994 1993
---------- ---------- ---------- ---------- ----------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
BALANCE SHEET DATA:
Oil and gas
properties - net........... $2,387,207 $2,099,589 $1,881,545 $1,684,811 $1,546,045
Total assets................. 2,723,355 2,458,353 2,147,258 1,861,867 1,811,162
Long-term debt
Trade...................... 548,775 466,089 147,559 165,337 153,000
Affiliate.................. 192,500 - 141,520 25,000 -
Deferred revenue............. 39,918 56,383 205,453 184,183 227,528
Shareholders' equity......... 1,281,049 1,265,090 1,163,659 1,043,419 933,073
</TABLE>
- ---------------
(1) Includes benefits of approximately $12 million, $16 million, $22 million,
$36 million and $65 million in 1997, 1996, 1995, 1994 and 1993,
respectively, relating to tight gas sand federal income tax credits.
(2) Includes a benefit of $15 million primarily associated with the refiling of
certain Canadian tax returns and the sale of certain international assets
and subsidiaries.
(3) Includes a benefit of $9 million primarily associated with a reassessment of
deferred tax requirements and the successful resolution on audit of Canadian
income taxes for certain prior years.
(4) Includes a benefit of approximately $14 million associated with the
successful resolution on audit of federal income taxes for certain prior
years.
(5) Includes a benefit of approximately $8 million related to reduced estimated
state income taxes and certain franchise taxes, a portion of which is
treated as income tax under Statement of Financial Accounting Standards
("SFAS") No. 109 - "Accounting for Income Taxes", and a $5 million benefit
22
<PAGE> 25
from the reduction of the Company's deferred federal income tax liability
resulting from a reevaluation of deferred tax requirements.
(6) Includes a benefit of $12 million from the reduction of the Company's
deferred federal income tax liability resulting from a reevaluation of
deferred tax requirements partially offset by an approximate $7 million
predominantly noncash charge primarily to adjust the Company's accumulated
deferred federal income tax liability for the increase in the corporate
federal income tax rate from 34% to 35%.
(7) In May 1994, the Board of Directors declared a two-for-one split of the
common stock of the Company to be effected as a nontaxable dividend of one
share for each share outstanding. Shares were issued on June 15, 1994 to
shareholders of record as of May 31, 1994. All per share amounts presented
herein are reflected on a post-split basis.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
The following review of operations for each of the three years in the
period ended December 31, 1997 should be read in conjunction with the
consolidated financial statements of the Company and notes thereto beginning
with page F-1.
RESULTS OF OPERATIONS
Net Operating Revenues. Wellhead volume and price statistics for the
specified years were as follows:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Natural Gas Volumes (MMcf per day)
North America(1).......................................... 758 706 636
Trinidad.................................................. 113 124 107
India..................................................... 18 - -
------ ------ ------
Total............................................. 889 830 743
====== ====== ======
Average Natural Gas Prices ($/Mcf)
North America(2).......................................... $ 2.20 $ 1.92 $ 1.34
Trinidad.................................................. 1.05 1.00 .97
India..................................................... 2.79 - -
Composite......................................... 2.07 1.78 1.29
Crude Oil and Condensate Volumes (MBbl per day)
North America............................................. 14.2 11.6 11.5
Trinidad.................................................. 3.4 5.2 5.1
India..................................................... 2.3 2.8 2.5
------ ------ ------
Total............................................. 19.9 19.6 19.1
====== ====== ======
Average Crude Oil and Condensate Prices ($/Bbl)
North America............................................. $19.33 $21.08 $17.09
Trinidad.................................................. 18.68 19.76 16.07
India..................................................... 20.05 20.17 16.81
Composite.............................................. 19.30 20.60 16.78
Natural Gas Liquids Volumes (MBbl per day)
North America............................................. 3.9 2.5 1.4
====== ====== ======
Average Natural Gas Liquids Prices ($/Bbl)
North America............................................. $11.54 $11.99 $11.31
Natural Gas Equivalent Volumes (MMcfe per day)
North America............................................. 867 790 713
Trinidad.................................................. 133 156 138
India..................................................... 32 17 15
------ ------ ------
Total............................................. 1,032 963 866
====== ====== ======
Total Bcfe Deliveries....................................... 377 353 316
</TABLE>
- ---------------
(1) Includes 48 MMcf per day in 1997, 1996 and 1995 delivered under the terms of
a volumetric production payment agreement effective October 1, 1992, as
amended.
(2) Includes an average equivalent wellhead value of $1.73 per Mcf in 1997,
$1.17 per Mcf in 1996, and $.80 per Mcf in 1995 for the volumes detailed in
note (1), net of transportation costs.
23
<PAGE> 26
1997 compared to 1996. During 1997, net operating revenues increased $53
million to $784 million. Total wellhead revenues of $828 million increased by
$129 million, or 18%, as compared to 1996.
Average wellhead natural gas prices for 1997 were up approximately 16% from
the comparable period in 1996 increasing net operating revenues by approximately
$82 million. Wellhead natural gas volumes were up 7% from 1996 adding net
operating revenues of approximately $49 million. This is primarily attributable
to a 7% increase in North America wellhead natural gas volumes and commencement
of natural gas production from the Tapti field in India. Wellhead crude oil and
condensate average prices decreased 6%, reducing net operating revenues by
approximately $10 million from 1996. Wellhead crude oil and condensate volumes
increased slightly from the comparable period a year ago and added approximately
$2 million to net operating revenues as a 23% increase in North America wellhead
crude oil and condensate volumes was partially offset by a natural decline in
crude oil production from the Ibis field offshore Trinidad.
Gains on the sales of reserves and related assets totaled $9 million in
1997 as compared to $20 million realized in 1996, reflecting a lower level of
sales activity.
Other marketing activities associated with sales and purchases of natural
gas, natural gas and crude oil price hedging and trading transactions, and
margins related to the volumetric production payment decreased net operating
revenues by $61 million during 1997, compared to a $4 million increase in 1996.
A $51 million revenue reduction related to natural gas commodity price hedging
activities utilizing NYMEX-related commodity market transactions in 1997
partially offset greater wellhead price benefits noted above and compares to a
$13 million revenue increase associated with similar transactions a year ago. A
decrease in margins associated with sales and purchases of natural gas and the
volumetric production payment reduced net revenues by approximately $9 million
as compared to an $18 million addition in 1996, primarily resulting from higher
costs of natural gas delivered in 1997. Additionally, the Company incurred a $5
million revenue reduction on its NYMEX-related crude oil price swap transactions
in 1997 compared to a $13 million revenue reduction in 1996.
1996 compared to 1995. During 1996, net operating revenues increased $82
million to $731 million as compared to 1995.
Average wellhead natural gas prices for 1996 were up approximately 38% from
the comparable period in 1995 increasing net operating revenues by approximately
$150 million. A 12% increase in wellhead natural gas volumes from 1995 added net
operating revenues of approximately $42 million. The increase in North America
wellhead natural gas volumes was primarily the result of eliminating voluntary
curtailments in the United States during 1996 due to significant increases
realized in average wellhead natural gas prices over the prices realized in
1995. Wellhead crude oil and condensate average prices increased 23% adding
approximately $27 million to net operating revenues over 1995. Wellhead crude
oil and condensate volumes increased 3% from the comparable period a year ago
adding approximately $4 million to net operating revenues.
Gains on the sales of reserves and related assets totaled $20 million in
1996 as compared to $63 million realized in 1995, reflecting a lower level of
sales activity.
Other marketing activities associated with sales and purchases of natural
gas, natural gas and crude oil price hedging and trading transactions, and
margins related to the volumetric production payment increased net operating
revenues by only $4 million during 1996, a decrease of approximately $101
million from 1995. This decrease primarily resulted from a lower revenue
increase on natural gas commodity price hedging activities utilizing
NYMEX-related commodity market transactions in 1996 of $13 million compared to a
$65 million revenue increase on similar transactions in 1995. The Company also
incurred a $13 million revenue reduction related to certain trading transactions
in 1996 compared to a $3 million revenue increase in 1995. A decrease in margins
associated with sales and purchases of natural gas and the volumetric production
payment reduced net revenues by approximately $17 million as compared to 1995 as
a result of the higher costs of natural gas delivered. Additionally, the Company
incurred a $13 million revenue reduction on its NYMEX-related crude oil price
swap transactions in 1996 compared to $2 million revenue increase in 1995.
24
<PAGE> 27
Operating Expenses
1997 compared to 1996. During 1997, operating expenses of $591 million were
approximately $69 million higher than the $522 million incurred in 1996.
Lease and well expenses increased $19 million to $96 million primarily due
to expanded operations and increased North America production activities at
higher costs to maximize the volumes delivered at higher product prices.
Exploration expenses of $58 million and dry hole expenses of $17 million
increased $3 million and $4 million, respectively, from 1996 primarily due to
increased exploratory drilling activities in North America. Impairment of
unproved oil and gas properties increased $6 million to $27 million as a result
of increased acquisition of unproved leases in North America. Depreciation,
depletion and amortization ("DD&A") expense increased approximately $27 million
to $278 million in 1997 primarily reflecting an increase in North America
production volumes. Taxes other than income were up by approximately $12 million
from the prior year primarily due to higher state severance taxes associated
with increased wellhead revenues in the United States.
Total operating costs per unit of production, which include lease and well,
DD&A, general and administrative, taxes other than income and interest expense,
increased 9% to $1.37 per thousand cubic feet equivalent ("Mcfe") in 1997 from
$1.26 per Mcfe in 1996. This increase was primarily attributable to increased
lease and well costs industry-wide, higher per unit DD&A and higher interest
expense associated with expanded worldwide operations, partially offset by lower
per unit general and administrative expenses.
1996 compared to 1995. During 1996, operating expenses of $522 million were
approximately $69 million higher than the $453 million incurred in 1995.
Lease and well expenses increased approximately $7 million to $77 million
primarily due to continually expanding operations and increases in production
activity. Exploration expense increased approximately $13 million to $55 million
primarily due to increased exploratory drilling activities in North America.
DD&A expense increased $35 million to $251 million primarily reflecting
increased production volumes and an increase in the average DD&A rate from $.68
per Mcfe in 1995 to $.71 per Mcfe in 1996 due to a change in volume mix by field
and geographic location and the impact of the adoption of SFAS No.
121 - "Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to be Disposed Of." Taxes other than income were approximately $16
million higher in 1996 as compared to 1995 primarily due to higher state
severance taxes associated with higher taxable wellhead revenues resulting from
higher United States volumes and average prices and lower applicable exploration
cost deductions in Trinidad in 1996.
The Company's total per unit operating costs increased in 1996 for lease
and well, DD&A, general and administrative, interest expense, and taxes other
than income by $.04 per Mcfe, averaging $1.26 per Mcfe during 1996 compared to
$1.22 per Mcfe during 1995. This increase is primarily attributable to increases
in per unit DD&A expense and taxes other than income partially offset by a
decrease in per unit general and administrative expense.
Other Income (Expense). The net expense for 1997 was primarily comprised of
expense related to a provision for litigation partially offset by interest
income.
Interest Expense. The increase in net interest expense of $15 million from
1996 to 1997 and of $1 million from 1995 to 1996 primarily reflects a higher
level of debt outstanding in each subsequent period. (See Note 4 to Consolidated
Financial Statements).
Income Taxes. Income tax provision decreased over $9 million for 1997 as
compared to 1996 primarily due to lower income before income taxes.
Approximately $15 million in benefits related to the sales of certain
international assets and subsidiaries, the refiling of certain Canadian tax
returns and other miscellaneous benefits were essentially equal to the Canadian
benefit and other items reported in 1996, as discussed below.
Income tax provision increased $9 million for 1996 as compared to 1995
primarily as a result of lower benefits associated with tight gas sands federal
income tax credits utilized in 1996 as compared to 1995. Tax benefits associated
with a reassessment of deferred tax requirements and the successful resolution
on audit of
25
<PAGE> 28
Canadian income taxes for certain prior years of $9 million and other
miscellaneous benefits in 1996 were essentially equal to an unrelated $14
million benefit in 1995.
CAPITAL RESOURCES AND LIQUIDITY
Cash Flow. The primary sources of cash for the Company during the
three-year period ended December 31, 1997 included funds generated from
operations, proceeds from the sales of selected oil and gas reserves and related
assets, proceeds from new borrowings and proceeds from the sales of treasury
stock in conjunction with the exercise of stock options. Primary cash outflows
included funds used in operations, exploration and development expenditures,
common stock repurchases, dividends paid to Company shareholders and the
repayment of debt.
Discretionary cash flow, a frequently used measure of performance for
exploration and production companies, is generally derived by adjusting net
income to eliminate the effects of depreciation, depletion and amortization,
impairment of unproved oil and gas properties, deferred income taxes, gains on
sales of oil and gas reserves and related assets, certain other non-cash
amounts, except for amortization of deferred revenue, and exploration and dry
hole expenses and to include proceeds from sales of reserves and related assets.
The Company generated discretionary cash flow of approximately $545 million in
1997, $543 million in 1996, and $525 million in 1995.
Net operating cash flows of $531 million for 1997 increased approximately
$166 million as compared to 1996 due to higher production related net operating
revenues net of cash operating expenses, lower current income taxes and reduced
working capital requirements. The working capital changes primarily reflected
higher 1996 end of year operating revenues collected in 1997 partially offset by
the higher level of end of year 1996 operating related accounts payable paid in
1997.
Net operating cash flows of $365 million for 1996 increased approximately
$30 million as compared to 1995 primarily due to higher production related net
operating revenues net of cash operating expenses partially offset by higher
current federal income taxes and increased working capital requirements
primarily associated with higher accounts receivable due to higher wellhead
prices and an increase in international activities, net of higher accounts
payable, at year end 1996. In accordance with the requirements of SFAS No. 95 -
"Statement of Cash Flows", net proceeds from the sale of selected oil and gas
reserves and related assets are not included in the determination of net
operating cash flows.
Sale of Volumetric Production Payment. In September 1992, the Company sold
a volumetric production payment for $326.8 million to a limited partnership.
(See "Business - Marketing - Other Marketing" and Note 5 to Consolidated
Financial Statements). Under the terms of the production payment agreements, the
Company conveyed a real property interest in approximately 124 Bcfe (136 TBtu)
of certain natural gas and other hydrocarbons to the purchaser. Effective
October 1, 1993, the agreements were amended providing for the extension of the
original term of the volumetric production payment through March 31, 1999 and
including a revised schedule of daily quantities of hydrocarbons to be delivered
which is approximately one-half of the original schedule. The revised schedule
will total approximately 89.1 Bcfe (97.8 TBtu) versus approximately 87.9 Bcfe
(96.4 TBtu) remaining to be delivered under the original agreement. The Company
retains responsibility for its working interest share of the cost of operations.
In accordance with generally accepted accounting principles, the Company
accounted for the proceeds received in the transaction as deferred revenue which
is being amortized into revenue and income as natural gas and other hydrocarbons
are produced and delivered to the purchaser during the term, as revised, of the
volumetric production payment thereby matching those revenues with the
depreciation of asset values which remained on the balance sheet following the
sale and the operating expenses incurred for which the Company retained
responsibility. The Company expects the above transaction, as amended, to have
minimal impact on future earnings. However, cash made available by the sale of
the volumetric production payment has provided considerable financial
flexibility for the pursuit of investment alternatives.
26
<PAGE> 29
Exploration and Development Expenditures. The table below sets out
components of actual exploration and development expenditures for the years
ended December 31, 1997, 1996 and 1995, along with those budgeted for the year
1998.
<TABLE>
<CAPTION>
ACTUAL
-------------------- BUDGETED
EXPENDITURE CATEGORY 1997 1996 1995 1998
-------------------- ---- ---- ---- --------
(IN MILLIONS)
<S> <C> <C> <C> <C>
Capital
Drilling and Facilities.......................... $446 $408 $303
Leasehold Acquisitions........................... 77 45 22
Producing Property Acquisitions.................. 81 69 127
Capitalized Interest and Other................... 22 18 12
---- ---- ----
Total.................................... 626 540 464
Exploration Expenses............................... 75 68 55
---- ---- ---- ----
Total.............................................. $701 $608 $519 $700
==== ==== ==== ====
</TABLE>
Exploration and development expenditures increased $93 million primarily
due to increased exploration and development activities in the United States and
the acquisition of producing properties in South Texas and in the Blackfoot area
in Canada. Partially offsetting these increases were the reduction of
construction expenditures in India related to the Tapti and Panna/Mukta
production facilities which were completed in 1997.
Exploration and development expenditures increased $89 million in 1996 as
compared to 1995 primarily due to increased development expenditures in the
United States and India and increased exploration expenditures in the United
States. Partially offsetting these increases were the reduction in 1996 of
development expenditures in Trinidad due to the completion of a large
development drilling program in 1995 and reduced property acquisition
expenditures. (See "Business - Exploration and Production" for additional
information detailing the specific geographic locations of the Company's
drilling programs and "Outlook" below for a discussion related to 1998
exploration and development expenditure plans).
Hedging Transactions. With the objective of enhancing the certainty of
future revenues, the Company enters into NYMEX-related commodity price swaps
from time to time. Using NYMEX-related commodity price swaps, the Company
receives a fixed price for the respective commodity hedged and pays a floating
market price, as defined for each transaction, to the counterparty at
settlement. The Company's 1997 NYMEX-related natural gas and crude oil commodity
price swaps closed with "other marketing revenue" reductions of $51 million
pretax and $5 million pretax, respectively. The Company has entered into natural
gas costless collar commodity price swap transactions which have a floor price
and a ceiling price. At December 31, 1997, there were outstanding natural gas
costless collars for 1998 covering approximately 37 TBtu of natural gas at a
weighted average floor price of $2.12 per MMBtu and ceiling price of $2.72 per
MMBtu. At December 31, 1997, there were open crude oil commodity price swaps for
1998 covering approximately 1.3 million barrels of crude oil at a weighted
average price of $18.90 per barrel.
Financing. The Company's long-term debt-to-total-capital ratio was 37% and
27% as of December 31, 1997 and 1996, respectively.
The Company has entered into agreements with Enron Corp. pursuant to which
the Company may borrow funds from or invest funds with Enron Corp. at
representative market rates of interest on a revolving basis. Advances from
Enron Corp. of $193 million were outstanding as of December 31, 1997. There were
no advances outstanding as of December 31, 1996. There were no investments with
Enron Corp. as of December 31, 1997 or 1996. These agreements are used primarily
to facilitate efficient cash management.
During 1997, total long-term debt increased $275 million to $741 million as
a result of borrowings related to increased exploration and development
expenditures and repurchase of the Company's common stock. (See Note 4 to the
Consolidated Financial Statements). The estimated fair value of the Company's
long-term debt at December 31, 1997 and 1996 was $744 million and $464 million,
respectively, based upon quoted market
27
<PAGE> 30
prices and, where such prices were not available, upon interest rates currently
available to the Company at year end. (See Note 13 to the Consolidated Financial
Statements).
Outlook. Uncertainty continues to exist as to the direction of future North
America natural gas price trends, and there remains a rather wide divergence in
the opinions held by some in the industry. This divergence in opinion is caused
by various factors including improvements in the technology used in drilling and
completing crude oil and natural gas wells that are tending to mitigate the
impacts of fewer crude oil and natural gas wells being drilled, the deregulation
of the natural gas market under Federal Energy Regulatory Commission Order 636
and subsequent related orders, improvements being realized in the availability
and utilization of natural gas storage capacity, colder weather experienced in
the latter part of 1995 and 1996 than in prior years and warmer than normal
weather experienced in late 1997 and early 1998. However, the continually
increasing recognition of natural gas as a more environmentally friendly source
of energy along with the availability of significant domestically sourced
supplies should result in further increases in demand and a
supporting/strengthening of the overall natural gas market over time. Being
primarily a natural gas producer, the Company is more significantly impacted by
changes in natural gas prices than by changes in crude oil and condensate
prices. (See "Business - Other Matters - Energy Prices"). At December 31, 1997,
based on the portion of the Company's anticipated natural gas volumes for 1998
for which prices have not, in effect, been hedged using NYMEX-related commodity
market transactions and long-term marketing contracts, the Company's net income
and cash flow sensitivity to changing natural gas prices is approximately $18
million for each $.10 per Mcf change in average wellhead natural gas prices.
While the Company is not impacted as significantly by changing crude oil prices
for those volumes not otherwise hedged, its net income and cash flow sensitivity
is approximately $5 million for $1.00 per barrel change in average wellhead
crude oil prices.
The Company plans to continue to focus a substantial portion of its
development and exploration expenditures in its major producing areas in North
America. However, based on the continuing uncertainty associated with North
America natural gas prices and as a result of the recent success realized in
Trinidad and India, the winning in 1996 of a concession in Venezuela, the award
of the modified U(a) block offshore Trinidad and the 1997 signing of a
production sharing contract in China, the Company anticipates expending a
substantial portion of its available funds in the further development of these
opportunities outside North America. In addition, the Company expects to conduct
limited exploratory activity in other areas outside of North America in its
expenditure plans and will continue to evaluate the potential for involvement in
other exploitation type opportunities. (See "Business - Exploration and
Production" for additional information detailing the specific geographic
locations of the related drilling programs). Early-in-year activity will be
managed within an annual expected expenditure level of approximately $700
million for 1998. This early-in-year planning will address the continuing
uncertainty with regard to the future of the North America natural gas price
environment and will be structured to maintain the flexibility necessary under
the Company's continuing strategy of funding exploration, exploitation,
development and acquisition activities primarily from available internally
generated cash flow.
The level of exploration and development expenditures may vary in 1998 and
will vary in future periods depending on energy market conditions and other
related economic factors. Based upon existing economic and market conditions,
the Company believes net operating cash flow and available financing
alternatives in 1998 will be sufficient to fund its net investing cash
requirements for the year. However, the Company has significant flexibility with
respect to its financing alternatives and adjustment of its exploration,
exploitation, development and acquisition expenditure plans if circumstances
warrant. While the Company has certain continuing commitments associated with
expenditure plans related to operations in India, Trinidad, Venezuela and China,
such commitments are not anticipated to be material when considered in relation
to the total financial capacity of the Company.
Other factors representing positive impacts that are more certain continue
to hold good potential for the Company in future periods. While the drilling
qualification period for the tight gas sand federal income tax credit expired as
of December 31, 1992, the Company continued in 1997, and should continue in the
future, to realize significant but declining benefits associated with production
from wells drilled during the qualifying period as it will be eligible for the
federal income tax credit through the year 2002. However, the annual
28
<PAGE> 31
benefit, which was approximately $12 million in 1997 and is estimated to be
approximately $10 million for 1998, is expected to continue to decline in future
periods as production from the qualified wells declines. The drilling
qualification period for a Texas severance tax exemption available on qualifying
high cost natural gas revenues continued through August 1996 in its original
form and in a modified and somewhat reduced form from that point through August
2002. Consequently, new qualifying production will be added prospectively to
that presently qualified. (See "Business - Other Matters - Tight Gas Sand Tax
Credit (Section 29) and Severance Tax Exemption"). Other natural gas marketing
activities are also expected to continue to contribute meaningfully to financial
results.
Other. The cost of environmental compliance has not been material to the
Company.
INFORMATION REGARDING FORWARD LOOKING STATEMENTS
This Annual Report on Form 10-K includes forward looking statements within
the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the
Securities Exchange Act of 1934. Although the Company believes that its
expectations are based on reasonable assumptions, it can give no assurance that
such expectations will be achieved. Important factors that could cause actual
results to differ materially from those in the forward looking statements herein
include, but are not limited to, the timing and extent of changes in commodity
prices for crude oil, natural gas and related products and interest rates, the
extent of the Company's success in discovering, developing and producing
reserves and in acquiring oil and gas properties, political developments around
the world and conditions of the capital and equity markets during the periods
covered by the forward looking statements.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information required hereunder is included in this report as set forth
in the "Index to Financial Statements" on page F-1.
ITEM 9. DISAGREEMENTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information required by this Item regarding directors is set forth in
the Proxy Statement under the caption entitled "Election of Directors", and is
incorporated herein by reference.
See list of "Current Executive Officers of the Registrant" in Part I
located elsewhere herein.
There are no family relationships among the officers listed, and there are
no arrangements or understandings pursuant to which any of them were elected as
officers. Officers are appointed or elected annually by the Board of Directors
at its first meeting following the Annual Meeting of Shareholders, each to hold
office until the corresponding meeting of the Board in the next year or until a
successor shall have been elected, appointed or shall have qualified.
ITEM 11. EXECUTIVE COMPENSATION
The information required by this Item is set forth in the Proxy Statement
under the caption "Compensation of Directors and Executive Officers", and is
incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information required by this Item is set forth in the Proxy Statement
under the captions "Election of Directors" and "Compensation of Directors and
Executive Officers", and is incorporated herein by reference.
29
<PAGE> 32
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this Item is set forth in the Proxy Statement
under the caption "Certain Transactions", and is incorporated herein by
reference.
PART IV
ITEM 14. FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULE, EXHIBITS AND
REPORTS ON FORM 8-K
(A)(1) AND (2) FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULE
See "Index to Financial Statements" set forth on page F-1.
(A)(3) EXHIBITS
See pages E-1 through E-5 for a listing of the exhibits.
(B) REPORTS ON FORM 8-K
The Company filed a Report on Form 8-K on October 27, 1997 reporting the
sale of $100 million principal amount of 6.5% Notes due September 15, 2004
pursuant to an underwritten public offering.
The Company filed a Report on Form 8-K on December 10, 1997 reporting the
sale of $100 million principal amount of 6.5% Notes due December 1, 2007
pursuant to an underwritten public offering.
30
<PAGE> 33
INDEX TO FINANCIAL STATEMENTS
ENRON OIL & GAS COMPANY
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Consolidated Financial Statements:
Management's Responsibility for Financial Reporting....... F-2
Report of Independent Public Accountants.................. F-3
Consolidated Statements of Income for Each of the Three
Years in the Period Ended December 31, 1997............ F-4
Consolidated Balance Sheets - December 31, 1997 and
1996................................................... F-5
Consolidated Statements of Shareholders' Equity for Each
of the Three Years in the Period Ended December 31,
1997................................................... F-6
Consolidated Statements of Cash Flows for Each of the
Three Years in the Period Ended December 31, 1997...... F-7
Notes to Consolidated Financial Statements................ F-8
Supplemental Information to Consolidated Financial
Statements................................................ F-25
Financial Statement Schedule:
Schedule II - Valuation and Qualifying Accounts and
Reserves............................................... S-1
Other financial statement schedules have been omitted
because they are inapplicable or the information required
therein is included elsewhere in the consolidated financial
statements or notes thereto.
</TABLE>
F-1
<PAGE> 34
MANAGEMENT'S RESPONSIBILITY FOR FINANCIAL REPORTING
The following consolidated financial statements of Enron Oil & Gas Company
and its subsidiaries were prepared by management which is responsible for their
integrity, objectivity and fair presentation. The statements have been prepared
in conformity with generally accepted accounting principles and, accordingly,
include some amounts that are based on the best estimates and judgments of
management.
Arthur Andersen LLP, independent public accountants, was engaged to audit
the consolidated financial statements of Enron Oil & Gas Company and its
subsidiaries and issue a report thereon. In the conduct of the audit, Arthur
Andersen LLP was given unrestricted access to all financial records and related
data including minutes of all meetings of shareholders, the Board of Directors
and committees of the Board. Management believes that all representations made
to Arthur Andersen LLP during the audit were valid and appropriate. Their audits
of the years presented included developing an overall understanding of the
Company's accounting systems, procedures and internal controls, and conducting
tests and other auditing procedures sufficient to support their opinion on the
financial statements.
The system of internal controls of Enron Oil & Gas Company and its
subsidiaries is designed to provide reasonable assurance as to the reliability
of financial statements and the protection of assets from unauthorized
acquisition, use or disposition. This system includes, but is not limited to,
written policies and guidelines including a published code for the conduct of
business affairs, conflicts of interest and compliance with laws regarding
antitrust, antiboycott and foreign corrupt practices policies, the careful
selection and training of qualified personnel, and a documented organizational
structure outlining the separation of responsibilities among management
representatives and staff groups.
The adequacy of financial controls of Enron Oil & Gas Company and its
subsidiaries and the accounting principles employed in financial reporting by
the Company are under the general oversight of the Audit Committee of the Board
of Directors. No member of this committee is an officer or employee of the
Company. The independent public accountants and internal auditors have direct
access to the Audit Committee and meet with the committee from time to time to
discuss accounting, auditing and financial reporting matters. It should be
recognized that there are inherent limitations to the effectiveness of any
system of internal control, including the possibility of human error and
circumvention or override. Accordingly, even an effective system can provide
only reasonable assurance with respect to the preparation of reliable financial
statements and safeguarding of assets. Furthermore, the effectiveness of an
internal control system can change with circumstances.
It is management's opinion that, considering the criteria for effective
internal control over financial reporting and safeguarding of assets which
consists of interrelated components including the control environment, risk
assessment process, control activities, information and communication systems,
and monitoring, the Company maintained an effective system of internal control
as to the reliability of financial statements and the protection of assets
against unauthorized acquisition, use or disposition for the year ended December
31, 1997.
<TABLE>
<S> <C> <C>
WALTER C. WILSON FORREST E. HOGLUND
Senior Vice Chairman of the
BEN B. BOYD President Board and
Vice President and Chief Financial Chief Executive
Controller Office Officer
</TABLE>
Houston, Texas
February 23, 1998
F-2
<PAGE> 35
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To Enron Oil & Gas Company:
We have audited the accompanying consolidated balance sheets of Enron Oil &
Gas Company (a Delaware corporation) and subsidiaries as of December 31, 1997
and 1996, and the related consolidated statements of income, shareholders'
equity and cash flows for each of the three years in the period ended December
31, 1997. These financial statements and the schedule referred to below are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements and the schedule based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Enron Oil & Gas Company and
subsidiaries as of December 31, 1997 and 1996, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1997, in conformity with generally accepted accounting principles.
Our audits were made for the purpose of forming an opinion on the basic
financial statements taken as a whole. The financial statement schedule listed
in the index to financial statements is presented for purposes of complying with
the Securities and Exchange Commission's rules and is not part of the basic
financial statements. This schedule has been subjected to the auditing
procedures applied in the audits of the basic financial statements and, in our
opinion, fairly states in all material respects the financial data required to
be set forth therein in relation to the basic financial statements taken as a
whole.
Houston, Texas ARTHUR ANDERSEN LLP
February 23, 1998
F-3
<PAGE> 36
ENRON OIL & GAS COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------------
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
NET OPERATING REVENUES
Natural Gas
Trade................................................. $544,181 $393,129 $222,118
Associated Companies.................................. 71,339 164,745 229,997
Crude Oil, Condensate and Natural Gas Liquids
Trade................................................. 121,838 108,365 66,145
Associated Companies.................................. 29,951 37,539 58,233
Gains on Sales of Reserves and Related Assets............ 9,287 20,358 62,821
Other.................................................... 6,905 6,512 9,388
-------- -------- --------
Total............................................ 783,501 730,648 648,702
OPERATING EXPENSES
Lease and Well........................................... 96,064 76,618 69,463
Exploration.............................................. 57,696 55,009 42,044
Dry Hole................................................. 17,303 13,193 12,911
Impairment of Unproved Oil and Gas Properties............ 27,213 21,226 23,715
Depreciation, Depletion and Amortization................. 278,179 251,278 216,047
General and Administrative............................... 54,415 56,405 56,626
Taxes Other Than Income.................................. 59,856 48,089 32,587
-------- -------- --------
Total............................................ 590,726 521,818 453,393
-------- -------- --------
OPERATING INCOME........................................... 192,775 208,830 195,309
OTHER INCOME (EXPENSE), NET................................ (1,588) (5,007) 669
-------- -------- --------
INCOME BEFORE INTEREST EXPENSE AND TAXES................... 191,187 203,823 195,978
INTEREST EXPENSE
Incurred
Trade................................................. 41,399 20,383 17,054
Affiliate............................................. 24 1,614 1,360
Capitalized.............................................. (13,706) (9,136) (6,490)
-------- -------- --------
Net Interest Expense............................. 27,717 12,861 11,924
-------- -------- --------
INCOME BEFORE INCOME TAXES................................. 163,470 190,962 184,054
INCOME TAX PROVISION....................................... 41,500 50,954 41,936
-------- -------- --------
NET INCOME................................................. $121,970 $140,008 $142,118
======== ======== ========
EARNINGS PER SHARE OF COMMON STOCK
Basic.................................................... $ .78 $ .88 $ .89
======== ======== ========
Diluted.................................................. $ .77 $ .87 $ .88
======== ======== ========
AVERAGE NUMBER OF COMMON SHARES
Basic.................................................... 157,376 159,853 159,917
======== ======== ========
Diluted.................................................. 158,160 161,525 161,132
======== ======== ========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-4
<PAGE> 37
ENRON OIL & GAS COMPANY
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
<TABLE>
<CAPTION>
AT DECEMBER 31,
-------------------------
1997 1996
----------- -----------
<S> <C> <C>
ASSETS
CURRENT ASSETS
Cash and Cash Equivalents................................. $ 9,330 $ 7,644
Accounts Receivable
Trade.................................................. 185,979 195,239
Associated Companies................................... 46,120 82,059
Inventories............................................... 32,040 20,746
Other..................................................... 8,566 20,222
----------- -----------
Total............................................. 282,035 325,910
OIL AND GAS PROPERTIES (Successful Efforts Method).......... 4,291,405 3,753,199
Less: Accumulated Depreciation, Depletion and
Amortization........................................... (1,904,198) (1,653,610)
----------- -----------
Net Oil and Gas Properties........................ 2,387,207 2,099,589
OTHER ASSETS................................................ 54,113 32,854
----------- -----------
TOTAL ASSETS................................................ $ 2,723,355 $ 2,458,353
=========== ===========
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts Payable
Trade.................................................. $ 198,109 $ 200,069
Associated Companies................................... 37,613 77,522
Accrued Taxes Payable..................................... 28,841 18,554
Dividends Payable......................................... 4,705 4,818
Other..................................................... 21,729 16,397
----------- -----------
Total............................................. 290,997 317,360
LONG-TERM DEBT
Trade..................................................... 548,775 466,089
Affiliate................................................. 192,500 -
OTHER LIABILITIES
Trade..................................................... 37,739 44,483
Associated Companies...................................... 44,699 -
DEFERRED INCOME TAXES....................................... 287,678 308,948
DEFERRED REVENUE............................................ 39,918 56,383
COMMITMENTS AND CONTINGENCIES
SHAREHOLDERS' EQUITY
Common Stock, $.01 Par, 320,000,000 Shares Authorized and
160,000,000 Shares Issued.............................. 201,600 201,600
Additional Paid In Capital................................ 402,877 388,212
Unearned Compensation..................................... (4,694) (5,727)
Cumulative Foreign Currency Translation Adjustment........ (19,771) (10,179)
Retained Earnings......................................... 800,709 697,564
Common Stock Held in Treasury, 4,935,744 shares at
December 31, 1997 and 242,882 shares at December 31,
1996................................................... (99,672) (6,380)
----------- -----------
Total Shareholders' Equity........................ 1,281,049 1,265,090
----------- -----------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY.................. $ 2,723,355 $ 2,458,353
=========== ===========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-5
<PAGE> 38
ENRON OIL & GAS COMPANY
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<TABLE>
<CAPTION>
CUMULATIVE
FOREIGN COMMON
ADDITIONAL CURRENCY STOCK TOTAL
COMMON PAID IN UNEARNED TRANSLATION RETAINED HELD IN SHAREHOLDERS'
STOCK CAPITAL COMPENSATION ADJUSTMENT EARNINGS TREASURY EQUITY
------------ ---------- ------------ ----------- -------- -------- -------------
<S> <C> <C> <C> <C> <C> <C> <C>
Balance at December 31,
1994....................... $201,600 $403,488 $ - $ (15,298) $453,810 $ (181) $1,043,419
Net Income................. - - - - 142,118 - 142,118
Dividends Paid/Declared,
$.12 Per Share........... - - - - (19,188) - (19,188)
Translation Adjustment..... - - - 4,551 - - 4,551
Treasury Stock Purchased... - - - - - (17,855) (17,855)
Treasury Stock Issued Under
Stock Option Plans....... - (4,109) - - - 14,438 10,329
Other...................... - - - - - 285 285
-------- -------- ------- --------- -------- -------- ----------
Balance at December 31,
1995....................... 201,600 399,379 - (10,747) 576,740 (3,313) 1,163,659
Net Income................. - - - - 140,008 - 140,008
Dividends Paid/Declared,
$.12 Per Share........... - - - - (19,184) - (19,184)
Translation Adjustment..... - - - 568 - - 568
Treasury Stock Purchased/
Tendered................. - - - - - (63,004) (63,004)
Treasury Stock Issued Under
Stock Option Plans....... - (11,167) (7,085) - - 59,937 41,685
Amortization of Unearned
Compensation............. - - 1,358 - - - 1,358
-------- -------- ------- --------- -------- -------- ----------
Balance at December 31,
1996....................... 201,600 388,212 (5,727) (10,179) 697,564 (6,380) 1,265,090
Net Income................. - - - - 121,970 - 121,970
Dividends Paid/Declared,
$.12 Per Share........... - - - - (18,825) - (18,825)
Translation Adjustment..... - - - (9,592) - - (9,592)
Treasury Stock Purchased... - - - - - (99,306) (99,306)
Treasury Stock Issued Under
Stock Option Plans....... - (872) - - - 6,014 5,142
Options Granted by Enron
Corp..................... - 15,081 - - - - 15,081
Amortization of Unearned
Compensation............. - - 1,033 - - - 1,033
Other...................... - 456 - - - - 456
-------- -------- ------- --------- -------- -------- ----------
Balance at December 31,
1997....................... $201,600 $402,877 $(4,694) $ (19,771) $800,709 $(99,672) $1,281,049
======== ======== ======= ========= ======== ======== ==========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-6
<PAGE> 39
ENRON OIL & GAS COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------
1997 1996 1995
--------- --------- ---------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Reconciliation of Net Income to Net Operating Cash
Inflows:
Net Income............................................ $ 121,970 $ 140,008 $ 142,118
Items Not Requiring (Providing) Cash
Depreciation, Depletion and Amortization........... 278,179 251,278 216,047
Impairment of Unproved Oil and Gas Properties...... 27,213 21,226 23,715
Deferred Income Taxes.............................. 16,665 2,276 45,173
Other, Net......................................... 359 7,830 2,910
Exploration Expenses.................................. 57,696 55,009 42,044
Dry Hole Expenses..................................... 17,303 13,193 12,911
Gains on Sales of Reserves and Related Assets......... (9,287) (20,358) (62,821)
Other, Net............................................ (2,590) 8,871 720
Changes in Components of Working Capital and Other
Liabilities
Accounts Receivable.............................. 48,893 (120,370) (17,525)
Inventories...................................... (11,294) (9,049) 4,034
Accounts Payable................................. (11,478) 87,495 2,514
Accrued Taxes Payable............................ 10,287 (1,041) 1,964
Other Liabilities................................ 2,521 3,752 1,544
Other, Net....................................... 9,760 270 (18,791)
Amortization of Deferred Revenue...................... (43,345) (43,463) (43,344)
Changes in Components of Working Capital Associated
with Investing and Financing Activities............ 18,077 (31,817) (17,858)
--------- --------- ---------
NET OPERATING CASH INFLOWS.............................. 530,929 365,110 335,355
INVESTING CASH FLOWS
Additions to Oil and Gas Properties................... (626,198) (539,330) (445,047)
Exploration Expenses.................................. (57,696) (55,009) (42,044)
Dry Hole Expenses..................................... (17,303) (13,193) (12,911)
Proceeds from Sales of Reserves and Related Assets
(Note 10).......................................... 37,521 63,951 102,006
Changes in Components of Working Capital Associated
with Investing Activities.......................... (22,454) 37,402 18,391
Other, Net............................................ (11,000) (5,381) (11,689)
--------- --------- ---------
NET INVESTING CASH OUTFLOWS............................. (697,130) (511,560) (391,294)
FINANCING CASH FLOWS
Long-Term Debt
Trade.............................................. 86,595 320,580 (16,100)
Affiliate.......................................... 192,500 (141,520) 116,520
Dividends Paid........................................ (18,938) (19,161) (19,193)
Treasury Stock Purchased.............................. (99,306) (43,507) (17,855)
Proceeds from Sales of Treasury Stock................. 5,141 22,188 10,329
Other, Net............................................ 1,895 (7,525) (533)
--------- --------- ---------
NET FINANCING CASH INFLOWS.............................. 167,887 131,055 73,168
--------- --------- ---------
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS........ 1,686 (15,395) 17,229
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR.......... 7,644 23,039 5,810
--------- --------- ---------
CASH AND CASH EQUIVALENTS AT END OF YEAR................ $ 9,330 $ 7,644 $ 23,039
========= ========= =========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-7
<PAGE> 40
ENRON OIL & GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(DOLLARS IN THOUSANDS UNLESS OTHERWISE INDICATED)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation. The consolidated financial statements of Enron
Oil & Gas Company (the "Company"), 55% of the outstanding common stock of which
was owned by Enron Corp. as of December 31, 1997, include the accounts of all
domestic and foreign subsidiaries. All material intercompany accounts and
transactions have been eliminated. Certain reclassifications have been made to
the consolidated financial statements for prior years to conform with the
current presentation.
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 revenue and expenses during the reporting
period. Actual results could differ from those estimates.
Cash Equivalents. The Company records as cash equivalents all highly liquid
short-term investments with maturities of three months or less.
Oil and Gas Operations. The Company accounts for its natural gas and crude
oil exploration and production activities under the successful efforts method of
accounting.
Oil and gas lease acquisition costs are capitalized when incurred. Unproved
properties with significant acquisition costs are assessed quarterly on a
property-by-property basis, and any impairment in value is recognized.
Amortization of any remaining costs of such leases begins at a point prior to
the end of the lease term depending upon the length of such term. Unproved
properties with acquisition costs that are not individually significant are
aggregated, and the portion of such costs estimated to be nonproductive, based
on historical experience, is amortized over the average holding period. If the
unproved properties are determined to be productive, the appropriate related
costs are transferred to proved oil and gas properties. Lease rentals are
expensed as incurred.
Oil and gas exploration costs, other than the costs of drilling exploratory
wells, are charged to expense as incurred. The costs of drilling exploratory
wells are capitalized pending determination of whether they have discovered
proved commercial reserves. If proved commercial reserves are not discovered,
such drilling costs are expensed. Costs to develop proved reserves, including
the costs of all development wells and related equipment used in the production
of natural gas and crude oil, are capitalized.
Depreciation, depletion and amortization of the cost of proved oil and gas
properties is calculated using the unit-of-production method. Estimated future
dismantlement, restoration and abandonment costs (classified as long-term
liabilities), net of salvage values, are taken into account. Certain other
assets are depreciated on a straight-line basis. In the first quarter of 1996,
the Company adopted Statement of Financial Accounting Standards ("SFAS") No.
121 - "Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to be Disposed Of", which resulted in a non-cash impairment charge that
was immaterial to and is included in depreciation, depletion and amortization.
Inventories, consisting primarily of tubular goods and well equipment held
for use in the exploration for, and development and production of natural gas
and crude oil reserves, are carried at cost with adjustments made from time to
time to recognize changes in condition value.
Natural gas revenues are recorded on the entitlement method based on the
Company's percentage ownership of current production. Each working interest
owner in a well generally has the right to a specific percentage of production,
although actual production sold may differ from an owner's ownership percentage.
Under entitlement accounting, a receivable is recorded when underproduction
occurs and a payable when overproduction occurs.
F-8
<PAGE> 41
Gains and losses associated with the sale in place of natural gas and crude
oil reserves and related assets are classified as net operating revenues in the
consolidated statements of income based on the Company's strategy of continuing
such sales in maximizing the economic value of its assets.
Accounting for Price Risk Management. The Company engages in price risk
management activities from time to time primarily for non-trading and to a
lesser extent for trading purposes. Derivative financial instruments (primarily
price swaps and costless collars) are utilized for non-trading purposes to hedge
the impact of market fluctuations on natural gas and crude oil market prices.
Hedge accounting is utilized in non-trading activities when there is a high
degree of correlation between price movements in the derivative and the item
designated as being hedged. Gains and losses on derivative financial instruments
used for hedging purposes are recognized as revenue in the same period as the
hedged item. Gains and losses on hedging instruments that are closed prior to
maturity are deferred in the consolidated balance sheets. In instances where the
anticipated correlation of price movements does not occur, hedge accounting is
terminated and future changes in the value of the derivative are recognized as
gains or losses using the mark-to-market method of accounting. Derivative and
other financial instruments utilized in connection with trading activities,
primarily price swaps and call options, are accounted for using the
mark-to-market method, under which changes in the market value of outstanding
financial instruments are recognized as gains or losses in the period of change.
The cash flow impact of derivative and other financial instruments used for
non-trading and trading purposes is reflected as cash flows from operating
activities in the consolidated statements of cash flows.
Capitalized Interest Costs. Certain interest costs have been capitalized as
a part of the historical cost of unproved oil and gas properties and in work in
progress for exploratory drilling and related facilities with significant cash
outlays. Interest costs capitalized during each of the three years in the period
ended December 31, 1997 are set out in the consolidated statements of income.
Income Taxes. The closing on December 13, 1995 of the sale by Enron Corp.
of approximately 31 million outstanding shares of the common stock of the
Company reduced Enron Corp.'s ownership interest in the Company below 80% with
the result that (i) the Company ceased, effective December 14, 1995, to be
included in the consolidated federal income tax return filed by Enron Corp. and
(ii) a tax allocation agreement (the "Base Agreement") previously in effect
between the Company and Enron Corp. was terminated. In addition, effective
December 14, 1995, the Company and Enron Corp. entered into a new tax allocation
agreement (the "1995 Agreement") pursuant to which, among other things, Enron
Corp. agreed (in exchange for the payment of $13 million by the Company) to be
liable for, and indemnify the Company against, all U.S. federal and state income
taxes and certain foreign taxes imposed on the Company for periods prior to the
date Enron Corp. reduced its ownership in the Company to less than 80%. In 1997,
the Company and Enron Corp. agreed to terminate the 1995 Agreement and enter
into a new tax allocation agreement. In the new agreement, Enron Corp. agreed to
refund the $13 million payment made by the Company pursuant to the 1995
Agreement, the Company agreed to release Enron Corp. from the liabilities
assumed related to the $13 million payment and the parties agreed to indemnify
each other in a manner consistent with the Base Agreement. Enron Corp. also
advanced the Company $50 million to fund certain federal income taxes related to
the 1995 taxable year. This advance is to be repaid in annual installments
through January 1, 2001. The Company does not believe that the cessation of
consolidated tax reporting with Enron Corp., the termination of the Base
Agreement concurrent with deconsolidation, the signing of the 1995 Agreement
and/or the newest tax allocation agreement with Enron Corp. have had or will
have in the future a material adverse effect on its financial condition or
results of operations.
Prior to December 14, 1995, the Company was included in the consolidated
federal income tax return filed by Enron Corp. as the common parent for itself
and its subsidiaries and the resulting taxes, including taxes for any state or
other taxing jurisdiction that required or permitted a consolidated, combined,
or unitary tax return to be filed and in which the Company and/or any of its
subsidiaries was included, were apportioned as between the Company and/or any of
its subsidiaries and Enron Corp. based on the terms of the Base Agreement.
The Company accounts for income taxes under the provisions of SFAS No.
109 - "Accounting for Income Taxes". SFAS No. 109 requires the asset and
liability approach for accounting for income taxes.
F-9
<PAGE> 42
Under this approach, deferred tax assets and liabilities are recognized based on
anticipated future tax consequences attributable to differences between
financial statement carrying amounts of assets and liabilities and their
respective tax bases (See Note 8 "Income Taxes").
Foreign Currency Translation. For subsidiaries whose functional currency is
deemed to be other than the U.S. dollar, asset and liability accounts are
translated at year-end exchange rates and revenue and expenses are translated at
average exchange rates prevailing during the year. Translation adjustments are
included as a separate component of shareholders' equity. Any gains or losses on
transactions or monetary assets or liabilities in currencies other than the
functional currency are included in net income in the current period.
Earnings Per Share. In accordance with the provisions of SFAS No.
128 - "Earnings per Share", basic earnings per share is computed on the basis of
the weighted-average number of common shares outstanding during the periods.
Diluted earnings per share is computed based upon the weighted-average number of
common shares plus the assumed issuance of common shares for all potentially
dilutive securities. The difference between the Average Number of Common Shares
outstanding for basic and diluted earnings per share is due to the assumed
issuance of common shares relating to employee stock options in each period
presented.
2. NATURAL GAS AND CRUDE OIL, CONDENSATE AND NATURAL GAS LIQUIDS NET OPERATING
REVENUES
Natural Gas Net Operating Revenues are comprised of the following:
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Wellhead Natural Gas Revenues
Trade........................................... $484,565 $323,642 $174,732
Associated Companies(1)(2)...................... 187,199 216,676 173,864
-------- -------- --------
Total................................... $671,764 $540,318 $348,596
======== ======== ========
Other Natural Gas Marketing Activities
Gross Revenues from:
Trade(3)..................................... $133,701 $142,149 $102,904
Associated Companies......................... 93,808 92,471 78,985
-------- -------- --------
Total................................... 227,509 234,620 181,889
Associated Costs from:
Trade........................................ 73,571 72,633 56,221
Associated Companies(1)(4)................... 162,543 143,871 90,121
-------- -------- --------
Total................................... 236,114 216,504 146,342
-------- -------- --------
Net..................................... (8,605) 18,116 35,547
Commodity Price Transaction Gain (Loss)
Trading...................................... 3,370(5) (13,222)(6) 2,688(7)
Non-Trading(8)............................... (51,009) 12,662 65,284
-------- -------- --------
Total................................... (47,639) (560) 67,972
-------- -------- --------
Total................................... $(56,244) $ 17,556 $103,519
======== ======== ========
</TABLE>
F-10
<PAGE> 43
Crude Oil, Condensate and Natural Gas Liquids Net Operating Revenues are
comprised of the following:
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Wellhead Crude Oil, Condensate and Natural Gas
Liquids Revenues
Trade........................................... $121,838 $108,365 $ 66,145
Associated Companies............................ 34,821 50,668 56,681
-------- -------- --------
Total................................... $156,659 $159,033 $122,826
======== ======== ========
Other Crude Oil and Condensate Marketing
Activities Commodity Price Hedging Gain
(Loss)(8)....................................... $ (4,870) $(13,129) $ 1,552
======== ======== ========
</TABLE>
- ---------------
(1) Wellhead Natural Gas Revenues in 1997, 1996 and 1995 include $114,859,
$119,009 and $80,369 respectively, associated with deliveries by Enron Oil
& Gas Company to Enron Oil & Gas Marketing, Inc., a wholly-owned
subsidiary, reflected as a cost in Other Natural Gas Marketing Activities -
Associated Costs.
(2) Includes $30,573, $20,656 and $14,022 in 1997, 1996 and 1995, respectively,
associated with the equivalent wellhead value of volumes delivered under
the terms of a volumetric production payment agreement effective October 1,
1992, as amended, net of transportation.
(3) Includes $43,344, $43,463 and $43,344 in 1997, 1996 and 1995, respectively,
associated with the amortization of deferred revenues under the terms of a
volumetric production payment agreement effective October 1, 1992, as
amended.
(4) Includes $44,137, $37,483 and $27,549 in 1997, 1996 and 1995, respectively,
for volumes delivered under a volumetric production payment agreement
effective October 1, 1992, as amended, including equivalent wellhead value,
any applicable transportation costs and exchange differentials.
(5) Includes a non-cash revenue increase related to the change in market value
of natural gas price swap options exercisable by a counterparty during 1997
and 1998, and of the partially offsetting "buy" price swap positions. This
revenue increase is partially offset by a revenue reduction related to the
settlement of 1997 transactions.
(6) Includes a non-cash charge of $12,000 related to the value of natural gas
price swap options exercisable by a counterparty during 1997, 1998, 1999
and 2000. The options for 1997 and 1998 remained open at December 31, 1996;
however, "buy" price swap positions in the same notional quantities and
maturities are in place. The option agreements for 1999 and 2000 were
terminated during the fourth quarter of 1996. See Note 13 for a discussion
of the options.
(7) Includes an $11,255 revenue increase associated with certain NYMEX-related
commodity market transactions designated for trading purposes partially
offset by a $2,567 revenue reduction related to call option transactions
and a $6,000 revenue reduction associated with certain NYMEX-related
natural gas commodity market transactions that were marked-to-market due to
loss of correlation between the NYMEX and the wellhead natural gas prices
that the positions were designated to hedge. (See Note 13 "Price and
Interest Rate Risk Management").
(8) Represents revenue increase (reduction) associated with commodity price
swap transactions primarily with Enron Corp. affiliated companies based on
NYMEX-related commodity prices in effect on dates of execution, less
customary transaction fees. These transactions serve as price hedges for a
portion of wellhead sales.
In March 1995, in a series of transactions with Enron Corp. and an
affiliate of Enron Corp., the Company exchanged all of its fuel supply and
purchase contracts and related price swap agreements associated with a Texas
City cogeneration plant (the "Cogen Contracts") for certain natural gas price
swap agreements of equivalent value issued by the affiliate that are designated
as hedges (the "Swap Agreements"). Such Swap Agreements were closed on March 31,
1995. As a result of the transactions, the Company was relieved of all
performance obligations associated with the Cogen Contracts. Such operating
revenues and associated costs through February 28, 1995 were classified as Other
Natural Gas Marketing Activities - Gross Revenues and
F-11
<PAGE> 44
Associated Costs from Associated Companies. The Company will realize net
operating revenues classified as Other Natural Gas Marketing
Activities - Commodity Price Transaction Gain (Loss), Non-Trading, and receive
corresponding cash payments of approximately $91 million during the period
extending through December 31, 1999, under the terms of the closed Swap
Agreements. The estimated fair value of the Swap Agreements was approximately
$81 million at the date the Swap Agreements were received in exchange for the
Cogen Contracts. The net effect of this series of transactions has resulted in
increases in net operating revenues and cash receipts for the Company during
1995 and 1996 of approximately $13 million and $7 million, respectively, with
offsetting decreases in 1998 and 1999 versus that anticipated under the Cogen
Contracts. The total cash payments receivable under the terms of the Swap
Agreements were approximately $13 million and $33 million at December 31, 1997
and 1996, respectively, and are presented in the accompanying balance sheet as
Accounts Receivable - Associated Companies for the $9 million and $20 million
current portion, respectively, and as Other Assets for the $4 million and $13
million noncurrent portion, respectively. The corresponding total future revenue
of approximately $13 million and $33 million, respectively, is classified as
Deferred Revenue. (See Note 13 "Price and Interest Rate Risk Management").
3. OTHER ASSETS
In December 1997, the Company and Enron Corp. entered into an Equity
Participation and Business Opportunity Agreement (the "Business Opportunity
Agreement"). (See Note 7 "Transactions with Enron Corp. and Related
Parties - Business Opportunity Agreement"). Among other things, the agreement
provides for Enron Corp. to grant the Company ten year options to purchase
3,200,000 shares of Enron Corp. common stock at a price of $39.1875 per share
which was the closing price of the stock on the date that the agreement was
approved by the Board of Directors of the Company. The option vesting schedule
provides that 25% vested immediately, 15% vest on the anniversary of the
Business Opportunity Agreement in 1998 and 10% vest each anniversary thereafter
until all of the options are vested. Vesting will be accelerated in the event of
a change of control of the Company. For such purposes, a "change of control"
means that (a) Enron Corp. no longer owns capital stock of the Company
representing at least 35% of the voting power for the election of directors and
(b) a majority of the members of the Board of Directors of the Company consists
of persons who are not officers or directors of Enron Corp. or any affiliate of
Enron Corp. other than the Company. Other Assets at December 31, 1997 includes
$23.3 million or $7.29 per share representing the estimated fair value of the
Enron Corp. stock options at the date of grant. Receipt of the options
represents a capital contribution from Enron Corp. and, accordingly, the fair
value received net of tax effects of $8.2 million has been credited to
Additional Paid In Capital.
4. LONG-TERM DEBT
Long-Term Debt at December 31 consisted of the following:
<TABLE>
<CAPTION>
1997 1996
-------- --------
<S> <C> <C>
Commercial Paper/Uncommitted Credit Facilities.............. $ 42,415 $ 65,700
9.10% Notes due 1998........................................ 20,000 40,000
6.50% Notes due 2004........................................ 100,000 -
6.70% Notes due 2006........................................ 150,000 150,000
6.50% Notes due 2007........................................ 100,000 -
Bank Debt due 1999.......................................... - 30,000
Subsidiary Debt due 1998-2001............................... 136,000 176,000
Other....................................................... 360 4,389
-------- --------
548,775 466,089
Affiliate................................................... 192,500 -
-------- --------
Total............................................. $741,275 $466,089
======== ========
</TABLE>
The Company has a revolving credit agreement with a group of banks that
provides for aggregate borrowings of up to $300 million and matures on June 27,
2002. Advances under the agreement bear interest,
F-12
<PAGE> 45
at the option of the Company, based on a base rate, an adjusted CD rate or a
Eurodollar rate. The Company also has a credit agreement with the same group of
banks that provides for aggregate borrowings of up to $100 million and matures
June 25, 1998. At December 31, 1997, there were no advances outstanding under
these agreements.
Commercial Paper outstanding at December 31, 1997 of $42.4 million was
issued under a commercial paper program the proceeds of which are used to fund
current transactions. At December 31, 1996, the Company had an uncommitted
credit facilities balance outstanding of $65.7 million. Advances under these
credit facilities bear interest based on market rates. Commercial paper and
uncommitted credit facilities balances are classified as long-term debt based on
the Company's intent and ability to replace such amounts with other long-term
debt.
The remaining repayment of the 9.10% Notes was made on February 13, 1998.
This amount was replaced with other long-term debt.
The 6.50% Notes due September 15, 2004 were issued through a public
offering in September 1997. These notes have an effective interest rate of
6.65%.
The 6.70% Notes due November 15, 2006 were issued through a public offering
in November 1996. These notes have an effective interest rate of 6.83%.
The 6.50% Notes due December 1, 2007 were issued through a public offering
in December 1997. These notes have an effective interest rate of 6.61%.
The Subsidiary Debt due 1998-2001 bears interest at variable rates based on
the London Interbank Bid or Offered Rates. Subsidiary debt of $31 million is due
in 1998 and is classified as long-term based on the Company's intent and ability
to replace such amount upon maturity with other long-term debt.
Certain of the borrowings described above contain covenants requiring the
maintenance of certain financial ratios and limitations on liens, debt issuance
and dispositions of assets. All subsidiary debt is guaranteed by the Company.
Shelf Registration. The Company may sell from time to time up to an
aggregate of $413 million in debt securities and/or common stock pursuant to an
effective "shelf" registration statement filed with the Securities and Exchange
Commission.
Financing Arrangements With Enron Corp. The Company engages in various
transactions with Enron Corp. that are characteristic of a consolidated group
under common control. Accordingly, the Company maintains agreements with Enron
Corp. that provide for the borrowing by the Company of up to $200 million
through December 31, 1998 and investing by the Company of surplus funds of up to
$200 million through December 31, 1998 at market rates from time to time.
Advances from Enron Corp. of $192.5 million were outstanding at December 31,
1997, and such balance was classified as long-term based on the Company's intent
and ability to replace such amount with other long-term debt. There were no
advances outstanding at December 31, 1996. There were no investments with Enron
Corp. at December 31, 1997 or 1996.
Fair Value Of Long-Term Debt. At December 31, 1997 and 1996, the Company
had $741 million and $466 million, respectively, of long-term debt which had
fair values of approximately $744 million and $464 million, respectively. The
fair value of long-term debt is the value the Company would have to pay to
retire the debt, including any premium or discount to the debtholder for the
differential between the stated interest rate and the year-end market rate. The
fair value of long-term debt is based upon quoted market prices and, where such
quotes were not available, upon interest rates available to the Company at
year-end.
5. VOLUMETRIC PRODUCTION PAYMENT
In September 1992, the Company sold a volumetric production payment for
$326.8 million to a limited partnership. Under the terms of the production
payment, as amended October 1, 1993, the Company conveyed a real property
interest of certain natural gas and other hydrocarbons to the purchaser. At
December 31, 1997 and 1996 there were approximately 23 trillion British thermal
units ("TBtu") and 41 TBtu, respectively,
F-13
<PAGE> 46
remaining to be delivered under the agreement. Such quantities are scheduled to
be delivered at the rate of 50 billion British thermal units per day through
March 31, 1999.
The Company accounted for the proceeds received in the transaction as
deferred revenue which is being amortized into revenue and income as natural gas
and other hydrocarbons are produced and delivered during the term of the
volumetric production payment agreement. Annual remaining amortization of
deferred revenue under the volumetric production payment agreement, as amended,
at December 31, 1997 was as follows:
<TABLE>
<S> <C>
1998............................................... $43,344
1999............................................... 10,688
-------
Total.................................... $54,032
=======
</TABLE>
6. SHAREHOLDERS' EQUITY
On May 7, 1996, the shareholders of the Company approved a resolution
submitted by the Board of Directors to amend the Restated Certificate of
Incorporation of the Company to increase the total number of authorized shares
of the common stock of the Company from 160 million to 320 million shares.
The Board of Directors of the Company approved in December 1992, and
amended in September 1994 and December 1996, the authorization for purchasing
and holding in treasury at any time of up to 1,000,000 shares of common stock of
the Company for the purpose of, but not limited to, meeting obligations
associated with the exercise of stock options granted to qualified employees
pursuant to the Company's stock option plans. In December 1996, the Board of
Directors of the Company approved the selling from time to time, subject to
certain conditions, of put options on the common stock of the Company. The
1,000,000 share limit mentioned above applies to shares held in treasury and
unexpired put options outstanding. In February 1997 as amended in February 1998,
the Board of Directors of the Company authorized the additional purchase of up
to an aggregate maximum of 10 million shares of common stock of the Company from
time to time in the open market to be held in treasury for the purpose of, but
not limited to, fulfilling any obligations arising under the Company's stock
option plans and any other approved transactions or activities for which such
common stock shall be required. At December 31, 1997 and 1996, 4,935,744 shares
and 242,882 shares, respectively, were held in treasury under these
authorizations. (See Note 9 "Commitments and Contingencies - Stock Option
Plans").
7. TRANSACTIONS WITH ENRON CORP. AND RELATED PARTIES
Business Opportunity Agreement. In December 1997, Enron Corp. and the
Company entered into the Business Opportunity Agreement which defines certain
obligations that Enron Corp. owes to the Company and relieves Enron Corp. from
certain obligations to the Company that it might otherwise have, including the
obligation to offer certain business opportunities to the Company. Enron Corp.
has advised the Company that, although it believes that it has conducted its
business in a manner that is consistent with its duties as a majority
shareholder of the Company, it was motivated to enter into the Business
Opportunity Agreement because of the difficulty of determining the applicability
of the law relating to duties that Enron Corp. may owe to the Company in
connection with Enron Corp.'s finance and trading business and because of Enron
Corp.'s desire to have more flexibility in pursuing business opportunities
identified by or developed solely by Enron Corp. personnel. The Business
Opportunity Agreement was approved by the Board of Directors of the Company
after it was approved unanimously by a special committee of the Board of
Directors consisting of the Company's independent directors.
The Business Opportunity Agreement provides generally that, so long as such
activities are conducted in compliance with the Business Opportunity Agreement
in all material respects, Enron Corp. may pursue business opportunities
independently of the Company. The Business Opportunity Agreement contains an
acknowledgment by the Company that Enron Corp.'s finance and trading business
may result in the acquisition by Enron Corp. of oil and gas properties or
companies and that in certain cases Enron Corp. or entities in which Enron Corp.
has an interest may acquire such assets pursuant to bidding or auction processes
in which the Company is also a bidder. In the Business Opportunity Agreement,
the Company acknowledges
F-14
<PAGE> 47
and agrees that such activities may have an impact on the Company or the price
it pays for properties or securities it purchases from others. The Business
Opportunity Agreement contains an acknowledgement and agreement by the Company
that, to the extent that a court might hold that the conduct of such activity is
a breach of a duty to the Company (and without admitting that the conduct of
such activity is such a breach of duty), the Company waives any and all claims
and courses of action that it may have to claim the conduct of such activity is
a breach of duty to the Company. The Business Opportunity Agreement contains
certain restrictions on the conduct of Enron's business. It also provides that,
except with respect to business opportunities pursued jointly by Enron Corp. and
the Company and except as otherwise agreed to between Enron Corp. and the
Company, Enron Corp.'s business will be conducted through the use of its own
personnel and assets and not with the use of any personnel or assets of the
Company.
The Business Opportunity Agreement states that its provisions relate
exclusively to the duties that Enron Corp. owes the Company and that nothing in
the Business Opportunity Agreement affects the fiduciary or other duties owed to
the Company by any individual director or officer of the Company in his or her
capacity as such. In this connection, Enron Corp. has agreed that its
representatives on the Board of Directors of the Company will not, for the
purpose of enabling Enron Corp. to pursue an opportunity in the oil and gas
business, vote in such a manner as to effectively prevent, prohibit or restrict
the Company from pursuing such opportunity.
In consideration for the Company's agreements in the Business Opportunity
Agreement, Enron Corp. provided valuable consideration to the Company, including
options to purchase common stock of Enron Corp. that will give the Company the
opportunity to participate in future appreciation in value of Enron, including
any appreciation in value resulting from activities that the Company has agreed
to permit Enron Corp. and its subsidiaries to pursue. (See Note 3 "Other
Assets"). The Business Opportunity Agreement also included (i) an agreement to
replace the existing services agreement, under which Enron Corp. provides
certain services to the Company, with a new services agreement under which the
Company's maximum payments to Enron Corp. for allocated indirect costs will be
reduced by $2.8 million per year, (ii) an agreement by Enron Corp. relieving the
Company of the obligation to bear the costs of any registration of sales by
Enron Corp. of shares of common stock of the Company, (iii) an agreement by
Enron Corp. to pay the costs of registration of the Company's sales of Enron
Corp. common stock acquired upon exercise of the options granted in the Business
Opportunity Agreement, (iv) an agreement that if Enron Corp. takes any action
that results in the loss by the Company of its status as an "independent
producer" under the Internal Revenue Code, Enron Corp. will pay the Company each
year through 2006 the lesser of (a) $1 million and (b) an amount which, after
payment of applicable taxes, will compensate the Company for the additional
income tax liability resulting from the loss of independent producer status, (v)
and an agreement that if Enron Corp. requests that the Company relocate its
offices, and if the Company agrees to do so, Enron will pay the Company's moving
expenses, including expenses of building out or refurbishing the space in its
new offices and expenses of removing and reinstalling the Company's
telecommunications and information systems facilities. In addition, pursuant to
the Business Opportunity Agreement, Enron Corp. agreed to cause its subsidiary,
Houston Pipe Line Company, to enter into various agreements with the Company
rearranging certain existing contractual arrangements between them and Enron
Corp., and the Company entered into a licensing agreement covering the Enron
Corp. name and mark and recognizing that the EOG and EOGI names and marks belong
to the Company. In the Business Opportunity Agreement, Enron Corp. and the
Company also entered into agreements in principle regarding the manner in which
they will share the burdens and benefits of the integrated projects under joint
development by Enron Corp. and the Company in Qatar, Mozambique and Uzbekistan.
The agreements in principle provide generally that the Company's interests in
these projects will be 20%, 20% and 80%, respectively, of the combined ownership
interest of the Company and Enron Corp.
The Business Opportunity Agreement also contains provisions that give Enron
Corp. the right to maintain its equity interest in the Company at certain
levels. It provides that if the Company issues additional shares of its capital
stock Enron Corp. will have the right to purchase additional shares of capital
stock of the Company as follows: (i) if Enron Corp. owns a majority interest,
Enron Corp. will have the right to purchase sufficient shares to permit it to
retain its majority interest; (ii) if Enron Corp. does not own a majority
interest but accounts for the assets and operations of the Company on a
consolidated basis for financial reporting purposes
F-15
<PAGE> 48
Enron Corp. will have the right to purchase sufficient shares to permit it to
continue to account for the Company on a consolidated basis; and (iii) if Enron
Corp. accounts for the assets and operations of the Company using the equity
method for financial reporting purposes Enron Corp. will have the right to
purchase sufficient shares to permit it to continue to account for the Company
using the equity method. Any such purchase by Enron Corp. will be for cash at
97% of the average closing price per share over a specified 20 day period
(reflecting a 3% private placement discount).
Natural Gas and Crude Oil, Condensate and Natural Gas Liquids Net Operating
Revenues. Wellhead Natural Gas and Crude Oil, Condensate and Natural Gas Liquids
Revenues and Other Natural Gas and Other Crude Oil and Condensate Marketing
Activities include revenues from and associated costs paid to various
subsidiaries and affiliates of Enron Corp. pursuant to contracts which, in the
opinion of management, are no less favorable than could be obtained from third
parties. Other Natural Gas and Other Crude Oil and Condensate Marketing
Activities also include certain commodity price swap and NYMEX-related commodity
transactions with Enron Corp. affiliated companies which, in the opinion of
management, are no less favorable than could be obtained from third parties.
(See Note 2 "Natural Gas and Crude Oil, Condensate and Natural Gas Liquids Net
Operating Revenues").
General and Administrative Expenses. The Company is charged by Enron Corp.
for all direct costs associated with its operations. Such direct charges,
excluding benefit plan charges (See Note 9 "Commitments and
Contingencies - Employee Benefit Plans"), totaled $16.1 million, $17.0 million
and $16.4 million for the years ended December 31, 1997, 1996 and 1995,
respectively. Management believes that these charges are reasonable.
Additionally, certain administrative costs not directly charged to any
Enron Corp. operations or business segments are allocated to the entities of the
consolidated group. Allocation percentages are generally determined utilizing
weighted average factors derived from property gross book value, net operating
revenues and payroll costs. Effective January 1, 1997, the Company entered into
an agreement with Enron Corp. with an initial term of ten years through December
2006, which agreement replaced a similar previous agreement, providing for
services substantially identical in nature and quality to those services
previously provided and for allocated indirect costs incurred in rendering such
services up to a maximum of approximately $5.3 million for 1997. Maximum
allocated indirect costs under the previous service agreement were $7.5 million
and $7.0 million for 1996 and 1995, respectively. The limit on cost for the
allocated indirect services provided by Enron Corp. to the Company will increase
in subsequent years for inflation and certain changes in the Company's
allocation bases. Management believes the indirect allocated charges for the
numerous types of support services provided by the corporate staff are
reasonable. Approximately $5.3 million was incurred by the Company for indirect
general and administrative expenses for 1997. Under the previous agreement,
approximately $7.5 million and $6.8 million were charged to the Company for
indirect general and administrative expenses for 1996 and 1995, respectively.
Financing. See Note 4 "Long-Term Debt - Financing Arrangements with Enron
Corp." for a discussion of financing arrangements with Enron Corp.
F-16
<PAGE> 49
8. INCOME TAXES
The principal components of the Company's net deferred income tax liability
at December 31, 1997 and 1996 were as follows:
<TABLE>
<CAPTION>
1997 1996
-------- --------
<S> <C> <C> <C>
Deferred Income Tax Assets
Cogen Contract Exchange.......................... $ 19,781 $ -
Net Operating Loss Carryforward, India........... 27,500 -
Non-Producing Leasehold Costs.................... 13,391 9,832
Seismic Costs Capitalized for Tax................ 7,144 7,037
Alternative Minimum Tax Credit Carryforward...... 12,681 7,516
Other............................................ 11,441 5,013
-------- --------
Total Deferred Income Tax Assets......... 91,938 29,398
Deferred Income Tax Liabilities
Oil and Gas Exploration and Development Costs
Deducted for Tax Over Book Depreciation,
Depletion and Amortization.................... 304,122 278,094
Capitalized Interest............................. 10,231 7,401
Volumetric Production Payment Book Revenue Over
Income for Tax................................ 58,850 51,499
Trading Activity................................. 3,470 1,448
Other............................................ 2,943 (96)
-------- --------
Total Deferred Income Tax Liabilities.... 379,616 338,346
-------- --------
Net Deferred Income Tax Liability........ $287,678 $308,948
======== ========
</TABLE>
The components of income before income taxes were as follows:
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
United States...................................... $103,831 $146,335 $157,174
Foreign............................................ 59,639 44,627 26,880
-------- -------- --------
Total.................................... $163,470 $190,962 $184,054
======== ======== ========
</TABLE>
Total income tax provision (benefit) was as follows:
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Current:
Federal.......................................... $ 50,494 $ 21,064 $ (6,983)
State............................................ 840 (916) 130
Foreign.......................................... 23,614 28,530 3,616
-------- -------- --------
Total.................................... 74,948 48,678 (3,237)
Deferred:
Federal.......................................... (32,711) 13,620 24,733
State............................................ 348 (1,826) 855
Foreign.......................................... (1,085) (9,518) 19,585
-------- -------- --------
Total.................................... (33,448) 2,276 45,173
-------- -------- --------
Income Tax Provision............................... $ 41,500 $ 50,954 $ 41,936
======== ======== ========
</TABLE>
F-17
<PAGE> 50
The differences between taxes computed at the U.S. federal statutory tax
rate and the Company's effective rate were as follows:
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ -------
<S> <C> <C> <C>
Statutory Federal Income Tax Rate......................... 35.00% 35.00% 35.00%
State Income Tax, Net of Federal Benefit.................. 0.47 (0.76) 0.35
Income Tax Related to Foreign Operations.................. 2.83 6.16 7.21
Tight Gas Sand Federal Income Tax Credits................. (7.51) (8.22) (12.19)
Revision of Prior Years' Tax Estimates.................... (4.34) (4.46) (6.52)
Amended Return Recoveries................................. - - (1.09)
Other..................................................... (1.06) (1.04) 0.02
------ ------ -------
Effective Income Tax Rate....................... 25.39% 26.68% 22.78%
====== ====== =======
</TABLE>
The Company's foreign subsidiaries' undistributed earnings of approximately
$166 million at December 31, 1997 are considered to be indefinitely invested
outside the U.S. and, accordingly, no U.S. federal or state income taxes have
been provided thereon. Upon distribution of those earnings in the form of
dividends, the Company may be subject to both foreign withholding taxes and U.S.
income taxes, net of allowable foreign tax credits. Determination of any
potential amount of unrecognized deferred income tax liabilities is not
practicable.
The Company has a $55 million India tax net operating loss carryforward at
December 31, 1997. The loss carryforward utilization is limited to future
taxable earnings of Enron Oil & Gas India Ltd. which earnings are expected to
exceed this carryforward amount before the carryforward period expires. The
India carryforward period is eight years, and unutilized net operating loss
carryforward will begin to expire with the fiscal year ending March 31, 2002.
The Company has an alternative minimum tax ("AMT") credit carryforward of
$13 million which can be used to offset regular income taxes payable in future
years. The AMT credit carryforward has an indefinite carryforward period.
9. COMMITMENTS AND CONTINGENCIES
Employee Benefit Plans. Employees of the Company are covered by various
retirement, stock purchase and other benefit plans of Enron Corp. During each of
the years ended December 31, 1997, 1996 and 1995, the Company was charged $5.0
million, $5.0 million and $6.6 million, respectively, for all such benefits,
including pension expense totaling $1.0 million, $1.0 million and $0.8 million,
respectively, by Enron Corp.
As of September 30, 1997, the most recent valuation date, the plan net
assets of the Enron Corp. defined benefit plan in which the employees of the
Company participate exceeded the actuarial present value of projected plan
benefit obligations by approximately $110 million. The assumed discount rate,
rate of return on plan assets and rate of increases in wages used in determining
the actuarial present value of projected plan benefits were 7.25%, 10.5% and
4.0%, respectively.
The Company also has in effect pension and savings plans related to its
Canadian, Trinidadian and Indian subsidiaries. Activity related to these plans
is not material relative to the Company's operations.
The Company provides certain medical, life insurance and dental benefits to
eligible employees and their eligible dependents. Benefits are provided under
the provisions of contributory defined dollar benefit plans of Enron Corp. The
Company accrues the cost of these post-retirement benefits over the service
lives of the employees expected to be eligible to receive such benefits. The
transition obligation is being amortized over an average period of 19 years.
Stock Option Plans. The Company has various stock option plans ("the
Plans") under which employees of the Company and its subsidiaries and
nonemployee members of the Board of Directors have been or may be granted rights
to purchase shares of common stock of the Company at a price not less than the
market price of the stock at the date of grant. Options granted under the Plans
vest over a period of time based on the nature
F-18
<PAGE> 51
of the grants and as defined in the individual grant agreements. Terms for
options granted under the Plans have not exceeded a maximum term of 10 years.
In January 1996, the Company granted 301,500 shares of common stock with a
market value of $23.50 per share to certain officers and key employees of the
Company under the Plans. Such shares are restricted and vest, subject to
continued employment and certain net income performance goals, on the
anniversary date of grant which could begin as early as 1998, but in any event
no later than January 2002. The fair value of the shares at date of grant has
been recorded in shareholders' equity as unearned compensation and is being
amortized as compensation expense. Related compensation expense for 1997 and
1996 was approximately $1 million per year.
The Company accounts for the Plans under the provisions and related
interpretations of Accounting Principles Board Opinion No. 25 ("APB No.
25") - "Accounting for Stock Issued to Employees". No compensation expense is
recognized for such options. In accordance with SFAS No. 123 - "Accounting for
Stock-Based Compensation" issued in 1995, the Company intends to continue to
apply APB No. 25 for purposes of determining net income and to present the pro
forma disclosures required by SFAS No. 123.
The following table sets forth the option transactions under the Plans for
the years ended December 31 (shares in thousands):
<TABLE>
<CAPTION>
1997 1996 1995
----------------- ----------------- ----------------
AVERAGE AVERAGE AVERAGE
GRANT GRANT GRANT
SHARES PRICE SHARES PRICE SHARES PRICE
------- ------- ------- ------- ------ -------
<S> <C> <C> <C> <C> <C> <C>
Outstanding at January 1..... 8,796 $20.70 8,019 $18.61 7,215 $18.15
Granted.................... 3,079 20.18 2,941 24.53 1,650 18.57
Exercised.................. (261) 17.16 (1,989) 17.95 (622) 13.01
Forfeited.................. (1,879) 24.06 (175) 20.28 (224) 19.27
------- ------- ------
Outstanding at December 31... 9,735 19.99 8,796 20.70 8,019 18.61
======= ======= ======
Shares Exercisable at
December 31................ 5,618 19.70 4,402 19.13 4,716 18.23
======= ======= ======
Shares Available for Future
Grant...................... 2,519 3,741 3,792
======= ======= ======
Average Fair Value of Shares
Granted During Year........ $ 6.96 $ 9.29 $ 6.39
======= ======= ======
</TABLE>
The fair value of each option grant is estimated using the Black-Scholes
option-pricing model with the following weighted-average assumptions used for
grants in 1997, 1996 and 1995, respectively: (1) dividend yield of 0.6%, 0.5%
and 0.5%, (2) expected volatility of 27%, 31% and 31%, (3) risk-free interest
rate of 6.3%, 5.8% and 7.2%, and (4) expected life of 5.2 years, 5.5 years and
4.1 years.
During 1997, in response to extremely competitive conditions for technical
personnel, the Company cancelled options issued in 1996 to purchase 1,282,000
shares of common stock at an exercise price of $25.38 per share, and reissued
the same number of options with an exercise price of $18.25 per share. The
reissue did not involve any executive officers of the Company.
F-19
<PAGE> 52
The following table summarizes certain information for the shares
outstanding at December 31, 1997 (shares in thousands):
<TABLE>
<CAPTION>
SHARES OUTSTANDING SHARES EXERCISABLE
------------------------------- ------------------
WEIGHTED WEIGHTED WEIGHTED
AVERAGE AVERAGE AVERAGE
RANGE OF REMAINING GRANT GRANT
GRANT PRICES SHARES LIFE PRICE SHARES PRICE
- ---------------- ------ --------- -------- ------ --------
<C> <S> <C> <C> <C> <C> <C>
$ 9.00 to $13.00 ...................... 477 3 years $ 9.82 477 $ 9.82
13.00 to 18.00 ...................... 1,082 5 17.83 779 17.81
18.00 to 23.00 ...................... 6,484 6 20.08 3,514 20.49
23.00 to 29.00 ...................... 1,692 7 23.86 848 23.72
----- -----
9.00 to 29.00 ...................... 9,735 6 19.99 5,618 19.70
===== =====
</TABLE>
The Company's pro forma net income and earnings per share of common stock
for 1997 and 1996, had compensation costs been recorded in accordance with SFAS
No. 123, are presented below (in millions except per share data):
<TABLE>
<CAPTION>
1997 1996 1995
-------------------- -------------------- --------------------
AS AS AS
REPORTED PRO FORMA REPORTED PRO FORMA REPORTED PRO FORMA
-------- --------- -------- --------- -------- ---------
<S> <C> <C> <C> <C> <C> <C>
Net Income................ $122.0 $116.7 $140.0 $135.5 $142.1 $139.0
Earnings per Share of
Common Stock
Basic................... $ .78 $ .74 $ .88 $ .85 $ .89 $ .87
====== ====== ====== ====== ====== ======
Diluted................. $ .77 $ .74 $ .87 $ .84 $ .88 $ .86
====== ====== ====== ====== ====== ======
</TABLE>
The effects of applying SFAS No. 123 in this pro forma disclosure should
not be interpreted as being indicative of future effects. SFAS No. 123 does not
apply to awards prior to 1995, and the extent and timing of additional future
awards cannot be predicted.
The Black-Scholes model used by the Company to calculate option values, as
well as other currently accepted option valuation models, were developed to
estimate the fair value of freely tradable, fully transferable options without
vesting and/or trading restrictions, which significantly differ from the
Company's stock option awards. These models also require highly subjective
assumptions, including future stock price volatility and expected time until
exercise, which significantly affect the calculated values. Accordingly,
management does not believe that this model provides a reliable single measure
of the fair value of the Company's stock option awards.
During 1997, 1996 and 1995, the Company purchased or was tendered
4,954,344, 2,383,727 and 762,799 of its common shares, respectively, and
delivered such shares upon the exercise of stock options and awards of
restricted stock, except for shares held in treasury at December 31, 1997, 1996
and 1995. The difference between the cost of the treasury shares and the
exercise price of the options, net of federal income tax benefit of $.5 million,
$6.1 million and $2.2 million for the years 1997, 1996 and 1995, respectively,
is reflected as an adjustment to Additional Paid In Capital. In December 1992,
as amended in September 1994 and December 1996, the Company commenced a stock
repurchase program of up to 1,000,000 shares authorized by the Board of
Directors to facilitate the availability of treasury shares of common stock for,
but not limited to, the settlement of employee stock option exercises pursuant
to the Plans. In February 1997 as amended in February 1998, the Board of
Directors authorized the additional purchase of up to 10 million shares for
similar purposes. At December 31, 1997 and 1996, 4,935,744 and 242,882 shares,
respectively, were held in treasury under these authorizations. (See Note 6
"Shareholders' Equity").
Letters Of Credit. At December 31, 1997 and 1996, the Company had letters
of credit outstanding totaling approximately $169 million and $213 million,
respectively.
F-20
<PAGE> 53
Contingencies. Enron Oil & Gas India Ltd. ("EOGIL"), a wholly-owned
subsidiary of the Company, is a respondent in two public interest lawsuits filed
in the Delhi High Court, India. The first (the "Wadehra Action") was brought by
B. L. Wadehra, an Indian public interest lawyer, against the Union of India,
EOGIL, EOGIL co-participants in the Panna and Mukta fields, Reliance Industries
Limited ("Reliance") and Oil & Natural Gas Corporation Limited ("ONGC"), and
certain other respondents. ONGC is the Indian national oil company and is
wholly-owned by the Union of India. The second suit (the "CPIL Action") was
brought by the Centre for Public Interest Litigation and the National Alliance
of People's Movement against the Union of India, the Central Bureau of
Investigation, ONGC, Reliance and EOGIL. Petitioners in both the Wadehra Action
and the CPIL Action allege various improprieties in the award of the Panna and
Mukta fields to EOGIL, Reliance and ONGC, and seek the cancellation of the
Production Sharing Contract for the Panna and Mukta fields. The Union of India
is vigorously disputing these allegations. The Company believes that the public
competitive bidding process for the fields was fair and that the award of these
fields to EOGIL, Reliance and ONGC was proper. Although no assurances can be
given, based on currently available information the Company believes that the
claims made by the petitioners in both actions are without merit, and that the
ultimate resolution of these matters will not have a material adverse effect on
its financial condition or results of operations. There are various other suits
and claims against the Company that have arisen in the ordinary course of
business. However, management does not believe these suits and claims will
individually or in the aggregate have a material adverse effect on the Company's
financial condition or results of operations. The Company has been named as a
potentially responsible party in certain Comprehensive Environmental Response
Compensation and Liability Act proceedings. However, management does not believe
that any potential assessments resulting from such proceedings will individually
or in the aggregate have a materially adverse effect on the financial condition
or results of operations of the Company.
10. CASH FLOW INFORMATION
Gains on sales of certain oil and gas reserves and related assets in the
amount of $9.3 million, $20.4 million and $62.8 million for the years ended
December 31, 1997, 1996 and 1995, respectively, are required by current
accounting guidelines to be removed from net income in connection with
determining net operating cash inflows while the related proceeds are required
to be classified as investing cash flows. The Company believes the proceeds from
the sales of reserves and related assets should be considered in analyzing the
elements of operating cash flows. The current federal income tax impact of these
sales transactions was calculated by the Company to be a benefit of $3.2 million
for 1997 and an expense of $8.5 million and $24.4 million for 1996 and 1995,
respectively, which entered into the overall calculation of current federal
income tax. The Company believes that this federal income tax impact should also
be considered in analyzing the elements of the cash flow statement.
Non-cash investing and financing activities for 1995 include the issuance
by a subsidiary of the Company of redeemable preferred stock with a
liquidation/redemption value of $19 million in exchange for certain oil and gas
properties. An approximate $7 million step-up in property basis was made
relating to deferred tax liabilities associated with the difference between the
tax and book bases of acquired properties as required by SFAS No. 109 for a
nontaxable business combination. The preferred stock was redeemed in November
1995.
Cash paid for interest and income taxes was as follows for the years ended
December 31:
<TABLE>
<CAPTION>
1997 1996 1995
------- ------- -------
<S> <C> <C> <C>
Interest (net of amount capitalized)................... $27,759 $14,237 $11,307
Income taxes........................................... 28,708 42,014 10,140
</TABLE>
Included in 1995 income taxes paid is $13 million paid to Enron Corp. for
the indemnification of any future liability associated with all federal and
state income taxes and certain foreign taxes imposed on the Company for periods
prior to the date Enron Corp. reduced its ownership in the Company to below 80%.
Pursuant to a new tax allocation agreement (See Note 1 "Summary of Significant
Accounting Policies - Income Taxes") such $13 million payment plus interest has
been returned to the Company, and the Company has assumed all obligations with
respect to the liabilities previously indemnified by Enron Corp.
F-21
<PAGE> 54
11. BUSINESS SEGMENT INFORMATION
The Company's operations are all natural gas and crude oil exploration and
production related. Accordingly, such operations are classified as one business
segment. Financial information by geographic area is presented below for the
years ended December 31, or at December 31:
<TABLE>
<CAPTION>
1997 1996 1995
---------- ---------- ----------
<S> <C> <C> <C>
Gross Operating Revenues
United States................................. $ 725,100 $ 660,804 $ 582,993
Canada........................................ 73,466 63,114 44,585
Other International........................... 106,190 104,226 87,097
---------- ---------- ----------
Total(1).............................. $ 904,756 $ 828,144 $ 714,675
========== ========== ==========
Operating Income
United States................................. $ 138,213 $ 160,109 $ 162,652
Canada........................................ 19,983 12,720 3,442
Other International........................... 34,579 36,001 29,215
---------- ---------- ----------
Total................................. $ 192,775 $ 208,830 $ 195,309
========== ========== ==========
Identifiable Assets
United States................................. $2,036,933 $1,882,900 $1,693,293
Canada........................................ 276,998 236,925 230,498
Other International........................... 409,424 338,528 223,467
---------- ---------- ----------
Total................................. $2,723,355 $2,458,353 $2,147,258
========== ========== ==========
</TABLE>
- ---------------
(1) Not deducted are natural gas associated costs of $121,255, $97,496 and
$65,973 in 1997, 1996 and 1995, respectively.
12. OTHER INCOME (EXPENSE), NET
Other income (expense), net consisted of the following for the years ended
December 31:
<TABLE>
<CAPTION>
1997 1996 1995
---------- ---------- ----------
<S> <C> <C> <C>
Interest Income(1).............................. $ 4,122 $ 2,264 $ 556
Financial Reserve Accruals...................... - (6,897) 379
Litigation Provision............................ (5,800) - -
Other, Net...................................... 90 (374) (266)
---------- ---------- ----------
Total................................. $ (1,588) $ (5,007) $ 669
========== ========== ==========
</TABLE>
- ---------------
(1) Includes $2,549, $403 and $59 from related parties.
13. PRICE AND INTEREST RATE RISK MANAGEMENT
Periodically, the Company enters into certain trading and non-trading
activities including NYMEX-related commodity market transactions and other
contracts. The non-trading portions of these activities have been designated to
hedge the impact of market price fluctuations on anticipated commodity delivery
volumes or other contractual commitments.
Trading Activities. Trading activities in 1997 included a revenue increase
of $3.4 million related to change in market value of natural gas price swap
options exercisable by a counterparty in 1997 and 1998 and partially offsetting
"buy" price swap positions.
During 1995, the Company entered into a NYMEX-related natural gas price
swap covering 73 TBtu for the year ended December 31, 1996. This swap contained
an option to extend the price swap covering 73 TBtu
F-22
<PAGE> 55
for each of the years 1997 and 1998 which was exercisable at one time prior to
December 31, 1996. The 1996 price swap was closed in the first quarter of 1996.
During 1996, this option was restructured into four options each exercisable, in
total, at one time by the counterparty before December 31, 1996, 1997, 1998 and
1999 to purchase 37 TBtu of notional natural gas for each of the years 1997,
1998, 1999 and 2000 at an average fixed price of $1.98, $1.98, $1.93 and $1.93
per million British thermal units ("MMBtu"), respectively. The 1997 and 1998
options were subsequently restructured to be exercisable monthly at a price of
$2.16 and $2.07 per MMBtu, respectively. These options cover notional volumes
averaging 3 TBtu per month during 1997 and 1998. During the fourth quarter of
1996, the 1999 and 2000 options were terminated. In 1996, the Company entered
into "buy" NYMEX-related natural gas price swap positions in the same notional
quantities and maturities as are covered by the 1997 and 1998 options. The
Company recognized a $3.4 million revenue increase and a $12 million revenue
reduction in 1997 and 1996, respectively, related to these trading activities.
In 1995, the Company sold a call option with a notional volume of 50
billion British thermal units ("BBtu") per day at a strike price of $2.10 per
MMBtu for each month in the period January 1996 through December 1996. At
December 31, 1995, the approximate market value of the outstanding call option
was $1.8 million. The Company recognized a $2.6 million revenue reduction in
1995 related to this call option. In the first quarter of 1996, the Company
purchased a call option with a notional volume of 50 BBtu per day at a strike
price of $2.10 per MMBtu for the period February 1996 through December 1996 for
$3.0 million to offset the call option discussed above. The purchase resulted in
a $1.2 million revenue reduction recognized in the first quarter of 1996.
The Company realized an $11.3 million revenue increase in 1995 related to
certain NYMEX-related natural gas commodity price swap transactions with an
Enron Corp. affiliated company that were designated for trading purposes in
December 1994 and closed in the first quarter of 1995.
The following table summarizes the estimated fair value of financial
instruments held for trading purposes at yearend and the average during the
year:
<TABLE>
<CAPTION>
1997(1) 1996(1) 1995(1)
------------------- ------------------- ------------------
FAIR AVERAGE FAIR AVERAGE FAIR AVERAGE
VALUE FAIR VALUE VALUE FAIR VALUE VALUE FAIR VALUE
------ ---------- ------ ---------- ----- ----------
(IN MILLIONS) (IN MILLIONS) (IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C>
Options Written.............. $(10.5) $(13.7) $(12.8) $(8.3) $(1.8) $(.3)
NYMEX-related Natural Gas
Price Swaps................ 4.2 7.1 .8 3.4 - .4
</TABLE>
- ---------------
(1) Estimated fair values have been determined by using available market data
and valuation methodologies. Judgment is necessarily required in
interpreting market data and the use of different market assumptions or
estimation methodologies may affect the estimated fair value amounts.
Interest Rate Swap Agreements and Foreign Currency Contracts. At December
31, 1997 and 1996, a subsidiary of the Company and the Company are parties to
offsetting foreign currency and interest rate swap agreements with an aggregate
notional principal amount of $210 million. Such swap agreements are scheduled to
terminate in 2001. At December 31, 1997 and 1996, the composite fair value of
the agreements was not significant based upon termination values obtained from
third parties.
Hedging Transactions. With the objective of enhancing the certainty of
future revenues, the Company enters into NYMEX-related commodity price swaps and
costless collars from time to time. Using NYMEX-related commodity price swaps,
the Company receives a fixed price for the respective commodity hedged and pays
a floating market price, as defined for each transaction, to the counterparty at
settlement.
The NYMEX-related natural gas commodity price swaps are priced based on a
Henry Hub, Louisiana delivery point. The Henry Hub price has historically had a
high degree of correlation with a significant portion of the wellhead price
received by the Company which has made such transactions effective natural gas
price hedges. During December 1995, there was a loss of correlation between the
prices paid under the natural gas commodity price swaps and the wellhead natural
gas prices ultimately received for a portion of the Company's
F-23
<PAGE> 56
hedged natural gas production. This loss of correlation resulted in the
recognition of a $6 million revenue reduction in 1995.
At December 31, 1997, the Company had outstanding positions covering
notional volumes of approximately 37 TBtu of natural gas for 1998 and
approximately 4 TBtu of natural gas for each of the years 1999 and 2000 and
approximately 1.3 million barrels ("MMBbl") and .7 MMBbl of crude oil and
condensate for the years 1998 and 1999, respectively. The fair value of the
positions was a net revenue increase of $1 million at December 31, 1997. During
the fourth quarter of 1997, the Company closed positions covering notional
volumes of approximately 37 TBtu of natural gas for each of the years 1999 and
2000. At December 31, 1997 the aggregate deferred revenue reduction for the
1998, 1999 and 2000 closed positions was approximately $9 million, $10 million
and $10 million, respectively.
At December 31, 1996, the Company had outstanding positions covering
notional volumes of approximately 10 TBtu of natural gas for 1997 and
approximately 37 TBtu of natural gas for each of the years 1999 and 2000 and
approximately 2.1 MMBbl, 1.7 MMBbl and 1.2 MMBbl of crude oil and condensate for
the years 1997, 1998 and the period 1999 through 2000, respectively. The fair
value of the positions was a negative $27 million at December 31, 1996. The
Company closed substantially all of the NYMEX-related natural gas commodity
price swaps for 1997 by entering into offsetting positions in the fourth quarter
of 1996. At December 31, 1996, the aggregate total of deferred revenue reduction
for 1997 and 1998 closed positions was approximately $74 million.
The following table summarizes the estimated fair value of financial
instruments and related transactions for nontrading activities at December 31,
1997 and 1996:
<TABLE>
<CAPTION>
1997 1996 1998
------------------------ ------------------------ ------------------------
CARRYING ESTIMATED CARRYING ESTIMATED CARRYING ESTIMATED
AMOUNT FAIR VALUE(1) AMOUNT FAIR VALUE(1) AMOUNT FAIR VALUE(1)
-------- ------------- -------- ------------- -------- -------------
(IN MILLIONS) (IN MILLIONS) (IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C>
Long-Term Debt(2).... $741.3 $744.4 $466.1 $464.5 $289.1 $294.0
Swap Agreements...... 13.3 12.7 32.8 31.0 62.8 58.8
NYMEX-Related
Commodity Market
Positions.......... (27.4) (31.6) (73.8) (105.5) (5.1) 10.9
</TABLE>
- ---------------
(1) Estimated fair values have been determined by using available market data
and valuation methodologies. Judgment is necessarily required in
interpreting market data and the use of different market assumptions or
estimation methodologies may affect the estimated fair value amounts.
(2) See Note 4 "Long-Term Debt."
Credit Risk. While notional contract amounts are used to express the
magnitude of price and interest rate swap agreements, the amounts potentially
subject to credit risk, in the event of nonperformance by the other parties, are
substantially smaller. The Company does not anticipate nonperformance by the
other parties.
14. CONCENTRATION OF CREDIT RISK
Substantially all of the Company's accounts receivable at December 31, 1997
and 1996 result from crude oil and natural gas sales and/or joint interest
billings to affiliate and third party companies in the oil and gas industry.
This concentration of customers and joint interest owners may impact the
Company's overall credit risk, either positively or negatively, in that these
entities may be similarly affected by changes in economic or other conditions.
In determining whether or not to require collateral from a customer or joint
interest owner, the Company analyzes the entity's net worth, cash flows,
earnings, and credit ratings. Receivables are generally not collateralized.
Historical credit losses incurred on receivables by the Company have been
immaterial.
F-24
<PAGE> 57
ENRON OIL & GAS COMPANY
SUPPLEMENTAL INFORMATION TO CONSOLIDATED FINANCIAL STATEMENTS
(IN THOUSANDS EXCEPT PER SHARE AMOUNTS UNLESS OTHERWISE INDICATED)
(UNAUDITED EXCEPT FOR RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING
ACTIVITIES)
OIL AND GAS PRODUCING ACTIVITIES
The following disclosures are made in accordance with SFAS No.
69 - "Disclosures about Oil and Gas Producing Activities":
Oil and Gas Reserves. Users of this information should be aware that the
process of estimating quantities of "proved" and "proved developed" crude oil
and natural gas reserves is very complex, requiring significant subjective
decisions in the evaluation of all available geological, engineering and
economic data for each reservoir. The data for a given reservoir may also change
substantially over time as a result of numerous factors including, but not
limited to, additional development activity, evolving production history, and
continual reassessment of the viability of production under varying economic
conditions. Consequently, material revisions to existing reserve estimates occur
from time to time. Although every reasonable effort is made to ensure that
reserve estimates reported represent the most accurate assessments possible, the
significance of the subjective decisions required and variances in available
data for various reservoirs make these estimates generally less precise than
other estimates presented in connection with financial statement disclosures.
Proved reserves represent estimated quantities of natural gas, crude oil,
condensate, and natural gas liquids that geological and engineering data
demonstrate, with reasonable certainty, to be recoverable in future years from
known reservoirs under economic and operating conditions existing at the time
the estimates were made.
Proved developed reserves are proved reserves expected to be recovered,
through wells and equipment in place and under operating methods being utilized
at the time the estimates were made.
Canadian provincial royalties are determined based on a graduated
percentage scale which varies with prices and production volumes. Canadian
reserves, as presented on a net basis, assume prices and royalty rates in
existence at the time the estimates were made, and the Company's estimate of
future production volumes. Future fluctuations in prices, production rates, or
changes in political or regulatory environments could cause the Company's share
of future production from Canadian reserves to be materially different from that
presented.
Estimates of proved and proved developed reserves at December 31, 1997,
1996 and 1995 were based on studies performed by the engineering staff of the
Company for reserves in the United States, Canada, Trinidad and India. Opinions
by DeGolyer and MacNaughton, independent petroleum consultants, for the years
ended December 31, 1997, 1996 and 1995 covering producing areas containing 54%,
64% and 60%, respectively, of proved reserves, excluding deep Paleozoic methane
reserves, of the Company on a net-equivalent-cubic-feet-of-gas basis, indicate
that the estimates of proved reserves prepared by the Company's engineering
staff for the properties reviewed by DeGolyer and MacNaughton, when compared in
total on a net-equivalent-cubic-feet-of-gas basis, do not differ materially from
the estimates prepared by DeGolyer and MacNaughton. The deep Paleozoic methane
reserves were covered by the opinion of DeGolyer and MacNaughton for the year
ended December 31, 1995. Such estimates by DeGolyer and MacNaughton in the
aggregate varied by not more than 5% from those prepared by the engineering
staff of the Company. All reports by DeGolyer and MacNaughton were developed
utilizing geological and engineering data provided by the Company.
The presentation of estimated proved reserves excludes, for each of the
years presented, those quantities attributable to future deliveries required
under a volumetric production payment. In order to calculate such amounts, the
Company has assumed that deliveries under the volumetric production payment are
made as scheduled at expected British thermal unit factors, and that delivery
commitments are satisfied through delivery, as scheduled, of the related
volumes.
The Company has also presented, as additional information, proved reserves
including quantities attributable to future deliveries required under the
volumetric production payment. The Company believes
F-25
<PAGE> 58
that this information is informative to readers of its financial statements as
the related oil and gas properties costs and deferred revenue are included in
the Company's balance sheets for each of the years presented. This additional
information is not required to be presented in accordance with SFAS No. 69;
however, the Company believes this additional information is useful in assessing
its reserve and financial position on a comprehensive basis.
No major discovery or other favorable or adverse event subsequent to
December 31, 1997 is believed to have caused a material change in the estimates
of proved or proved developed reserves as of that date.
The following table sets forth the Company's net proved and proved
developed reserves at December 31 for each of the four years in the period ended
December 31, 1997, and the changes in the net proved reserves for each of the
three years in the period then ended as estimated by the engineering staff of
the Company.
NET PROVED AND PROVED DEVELOPED RESERVE SUMMARY
<TABLE>
<CAPTION>
UNITED STATES CANADA TRINIDAD INDIA OTHER TOTAL
------------- ------ -------- ------ ----- -------
<S> <C> <C> <C> <C> <C> <C>
Natural Gas (Bcf)(1)
Net proved reserves at December 31,
1994.............................. 1,307.4 296.6 206.2 29.3 - 1,839.5
Revisions of previous estimates... 10.1 (8.1) 17.5 (29.3) - (9.8)
Purchases in place................ 174.8 - - - - 174.8
Extensions, discoveries and other
additions....................... 1,391.6(2) 54.8 60.8 75.0 - 1,582.2
Sales in place.................... (38.1) (1.7) - - - (39.8)
Production........................ (191.7) (27.7) (39.0) - - (258.4)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1995.............................. 2,654.1(2) 313.9 245.5 75.0 - 3,288.5
Additional disclosures:
Volumes attributable to volumetric
production payment.............. 54.2 - - - - 54.2
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1995, including volumes
attributable to volumetric
production payment................ 2,708.3(2) 313.9 245.5 75.0 - 3,342.7
======= ====== ====== ====== === =======
Net proved reserves at December 31,
1995.............................. 2,654.1(2) 313.9 245.5 75.0 - 3,288.5
Revisions of previous estimates... 3.6 (2.9) 79.6 - - 80.3
Purchases in place................ 100.6 0.9 - - - 101.5
Extensions, discoveries and other
additions....................... 256.8 49.2 90.7 124.6 - 521.3
Sales in place.................... (58.4) (4.3) - - - (62.7)
Production........................ (210.2) (35.9) (45.6) - - (291.7)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1996.............................. 2,746.5(2) 320.9 370.2 199.6 - 3,637.2
Additional disclosures:
Volumes attributable to volumetric
production payment.............. 37.5 - - - - 37.5
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1996, including volumes
attributable to volumetric
production payment................ 2,784.0(2) 320.9 370.2 199.6 - 3,674.7
======= ====== ====== ====== === =======
</TABLE>
(Table
continued on following page)
F-26
<PAGE> 59
<TABLE>
<CAPTION>
UNITED STATES CANADA TRINIDAD INDIA OTHER TOTAL
------------- ------ -------- ------ ----- -------
<S> <C> <C> <C> <C> <C> <C>
Net proved reserves at December 31,
1996.............................. 2,746.5(2) 320.9 370.2 199.6 - 3,637.2
Revisions of previous estimates... (50.8) (1.5) (0.4) 25.1 - (27.6)
Purchases in place................ 60.0 67.6 - - - 127.6
Extensions, discoveries and other
additions....................... 275.9 37.8 - 253.5 7.7 574.9
Sales in place.................... (17.7) (0.4) - - - (18.1)
Production........................ (229.1) (37.0) (41.0) (6.6) - (313.7)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1997.............................. 2,784.8(2) 387.4 328.8 471.6 7.7 3,980.3
Additional disclosures:
Volumes attributable to volumetric
production payment.............. 20.8 - - - - 20.8
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1997, including volumes
attributable to volumetric
production payment................ 2,805.6(2) 387.4 328.8 471.6 7.7 4,001.1
======= ====== ====== ====== === =======
Liquids (MBbl)(3)(4)
Net proved reserves at December 31,
1994.............................. 17,787 7,237 4,429 7,585 - 37,038
Revisions of previous estimates... (413) (351) 396 4,874 - 4,506
Purchases in place................ 4,264 - - - - 4,264
Extensions, discoveries and other
additions....................... 8,703 729 3,896 - - 13,328
Sales in place.................... (1,241) (9) - - - (1,250)
Production........................ (3,701) (1,021) (1,851) (917) - (7,490)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1995.............................. 25,399 6,585 6,870 11,542 - 50,396
Revisions of previous estimates... 339 191 1,835 - - 2,365
Purchases in place................ 312 2 - - - 314
Extensions, discoveries and other
additions....................... 7,103 2,116 1,388 275 - 10,882
Sales in place.................... (447) (121) - - - (568)
Production........................ (3,830) (1,321) (1,925) (1,026) - (8,102)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1996.............................. 28,876 7,452 8,168 10,791 - 55,287
Revisions of previous estimates... 3,515 225 (31) 19 - 3,728
Purchases in place................ 127 1,123 - - - 1,250
Extensions, discoveries and other
additions....................... 6,037 1,590 - 20,123 - 27,750
Sales in place.................... (1,683) - - - - (1,683)
Production........................ (5,223) (1,384) (1,236) (838) - (8,681)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1997.............................. 31,649 9,006 6,901 30,095 - 77,651
======= ====== ====== ====== === =======
Bcf Equivalent (Bcfe)
Net proved reserves at December 31,
1994.............................. 1,414.2(5) 339.9 232.8 74.8 - 2,061.7
Revisions of previous estimates... 7.6 (10.2) 19.8 - - 17.2
Purchases in place................ 200.4 - - - - 200.4
Extensions, discoveries and other
additions....................... 1,443.8(2) 59.2 84.2 75.0 - 1,662.2
Sales in place.................... (45.5) (1.8) - - - (47.3)
Production........................ (213.9) (33.8) (50.1) (5.5) - (303.3)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1995.............................. 2,806.6 (2)(5 353.3 286.7 144.3 - 3,590.9
Revisions of previous estimates... 5.7 (1.8) 90.6 - - 94.5
Purchases in place................ 102.5 0.9 - - - 103.4
Extensions, discoveries and other
additions....................... 299.4 61.9 99.0 126.2 - 586.5
Sales in place.................... (61.0) (5.1) - - - (66.1)
Production........................ (233.1) (43.9) (57.1) (6.2) - (340.3)
------- ------ ------ ------ --- -------
</TABLE>
(Table continued on following page)
F-27
<PAGE> 60
<TABLE>
<CAPTION>
UNITED STATES CANADA TRINIDAD INDIA OTHER TOTAL
------------- ------ -------- ------ ----- -------
<S> <C> <C> <C> <C> <C> <C>
Net proved reserves at December 31,
1996.............................. 2,920.1 (2)(5 365.3 419.2 264.3 - 3,968.9
Revisions of previous estimates... (29.8) (0.1) (0.5) 25.2 - (5.2)
Purchases in place................ 60.7 74.4 - - - 135.1
Extensions, discoveries and other
additions....................... 312.1 47.4 - 374.2 7.7 741.4
Sales in place.................... (27.7) (0.4) - - - (28.1)
Production........................ (260.4) (45.3) (48.5) (11.7) - (365.9)
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1997.............................. 2,975.0 (2)(5 441.3 370.2 652.0 7.7 4,446.2
Additional disclosures:
Volumes attributable to volumetric
production payment.............. 20.8 - - - - 20.8
------- ------ ------ ------ --- -------
Net proved reserves at December 31,
1997, including volumes
attributable to volumetric
production payment................ 2,995.8(2) 441.3 370.2 652.0 7.7 4,467.0
======= ====== ====== ====== === =======
Net proved developed reserves at
Natural Gas (Bcf)
December 31, 1994............... 1,128.2 288.3 206.2 - - 1,622.7
December 31, 1995............... 1,218.1 310.1 233.9 - - 1,762.1
December 31, 1996............... 1,325.7 319.5 370.2 124.6 - 2,140.0
December 31, 1997............... 1,349.0 370.9 328.8 286.6 - 2,335.3
Liquids (MBbl)(4)
December 31, 1994............... 16,770 7,073 4,429 7,585 - 35,857
December 31, 1995............... 19,977 6,505 5,607 11,542 - 43,631
December 31, 1996............... 24,868 7,452 8,168 10,791 - 51,279
December 31, 1997............... 27,707 8,885 6,901 23,322 - 66,815
Bcf Equivalents
December 31, 1994............... 1,228.8 330.7 232.8 45.5 - 1,837.8
December 31, 1995............... 1,338.0 349 .1 267.5 69.3 - 2,023.9
December 31, 1996............... 1,474.9 364 .2 419.2 189.3 - 2,447.6
December 31, 1997............... 1,515.3 424 .2 370.2 426.5 - 2,736.2
Net proved developed reserves,
including amounts attributable to
volumetric production payment at
Natural Gas (Bcf)
December 31, 1994............... 1,199.1 288.3 206.2 - - 1,693.6
December 31, 1995............... 1,272.3 310.1 233.9 - - 1,816.3
December 31, 1996............... 1,363.2 319.5 370.2 124.6 - 2,177.5
December 31, 1997............... 1,369.8 370.9 328.8 286.6 - 2,356.1
</TABLE>
- ---------------
(1) Billion cubic feet.
(2) Includes 1,180 Bcf of proved undeveloped methane reserves contained, along
with high concentrations of carbon dioxide and other gases in deep
Paleozoic formations in the Big Piney area of Wyoming. The Company is
actively pursuing the consummation of a market or markets from several
different potential sources to facilitate realizing the value of these
reserves.
(3) Thousand barrels.
(4) Includes crude oil, condensate and natural gas liquids.
(5) Excludes approximately 71 Bcfe, 54 Bcfe, 38 Bcfe and 21 Bcfe at December
31, 1994, 1995, 1996 and 1997, respectively, related to a volumetric
production payment.
F-28
<PAGE> 61
Capitalized Costs Relating to Oil and Gas Producing Activities. The
following table sets forth the capitalized costs relating to the Company's
natural gas and crude oil producing activities at December 31, 1997 and 1996:
<TABLE>
<CAPTION>
1997 1996
----------- -----------
<S> <C> <C>
Proved Properties.......................................... $ 4,069,914 $ 3,593,230
Unproved Properties........................................ 221,491 159,969
----------- -----------
Total............................................ 4,291,405 3,753,199
Accumulated depreciation, depletion and amortization....... (1,904,198) (1,653,610)
----------- -----------
Net capitalized costs...................................... $ 2,387,207 $ 2,099,589
=========== ===========
</TABLE>
Costs Incurred in Oil and Gas Property Acquisition, Exploration and
Development Activities. The acquisition, exploration and development costs
disclosed in the following tables are in accordance with definitions in SFAS No.
19 - "Financial Accounting and Reporting by Oil and Gas Producing Companies".
Acquisition costs include costs incurred to purchase, lease, or otherwise
acquire property.
Exploration costs include exploration expenses, additions to exploration
wells including those in progress, and depreciation of support equipment used in
exploration activities.
Development costs include additions to production facilities and equipment,
additions to development wells including those in progress, and depreciation of
support equipment and related facilities used in development activities.
The following tables set forth costs incurred related to the Company's oil
and gas activities for the years ended December 31:
<TABLE>
<CAPTION>
UNITED STATES CANADA TRINIDAD INDIA OTHER TOTAL
------------- ------- -------- ------- ------- --------
<S> <C> <C> <C> <C> <C> <C>
1997
Acquisition Costs of Properties
Unproved........................ $ 69,258 $ 7,700 $ - $ - $ 235 $ 77,193
Proved.......................... 42,386 38,949 - - 28 81,363
-------- ------- ------- ------- ------- --------
Total................... 111,644 46,649 - - 263 158,556
Exploration Costs................. 74,360 8,279 1,344 965 15,935 100,883
Development Costs................. 333,093 30,856 163 67,777 9,869 441,758
-------- ------- ------- ------- ------- --------
Total................... $519,097 $85,784 $ 1,507 $68,742 $26,067 $701,197
======== ======= ======= ======= ======= ========
1996
Acquisition Costs of Properties
Unproved........................ $ 38,832 $ 3,565 $ 2,000 $ - $ 77 $ 44,474
Proved.......................... 68,706 672 - - - 69,378
-------- ------- ------- ------- ------- --------
Total................... 107,538 4,237 2,000 - 77 113,852
Exploration Costs................. 60,880 8,069 2,082 748 16,490 88,269
Development Costs................. 283,985 25,705 6,654 82,098 6,969 405,411
-------- ------- ------- ------- ------- --------
Total................... $452,403 $38,011 $10,736 $82,846 $23,536 $607,532
======== ======= ======= ======= ======= ========
1995
Acquisition Costs of Properties
Unproved........................ $ 16,196 $ 4,645 $ - $ - $ 1,482 $ 22,323
Proved.......................... 122,369 116 - 5,000 - 127,485
-------- ------- ------- ------- ------- --------
Total................... 138,565 4,761 - 5,000 1,482 149,808
Exploration Costs................. 47,463 7,197 374 (98) 17,948 72,884
Development Costs................. 217,674 28,611 32,692 16,756 577 296,310
-------- ------- ------- ------- ------- --------
Total................... $403,702 $40,569 $33,066 $21,658 $20,007 $519,002
======== ======= ======= ======= ======= ========
</TABLE>
F-29
<PAGE> 62
Results of Operations for Oil and Gas Producing Activities(1). The
following tables set forth results of operations for oil and gas producing
activities for the years ended December 31:
<TABLE>
<CAPTION>
UNITED STATES CANADA TRINIDAD INDIA OTHER TOTAL
------------- ------- -------- ------- -------- --------
<S> <C> <C> <C> <C> <C> <C>
1997
Operating Revenues
Associated Companies........................... $206,738 $15,280 $ - $ - $ 2 $222,020
Trade.......................................... 448,824 58,712 66,000 35,332 21 608,889
Gains on Sales of Reserves and Related
Assets....................................... 4,464 (13) - - 4,836 9,287
-------- ------- ------- ------- -------- --------
Total.................................... 660,026 73,979 66,000 35,332 4,859 840,196
Exploration Expenses, including Dry Hole......... 50,930 5,995 1,344 965 15,765 74,999
Production Costs................................. 106,395 20,073 12,256 10,505 75 149,304
Impairment of Unproved Oil and Gas Properties.... 24,229 2,643 - - 341 27,213
Depreciation, Depletion and Amortization......... 238,765 23,116 11,032 3,716 901 277,530
-------- ------- ------- ------- -------- --------
Income (Loss) before Income Taxes................ 239,707 22,152 41,368 20,146 (12,223) 311,150
Income Tax Provision (Benefit)................... 69,252 8,130 22,752 9,670 (252) 109,552
-------- ------- ------- ------- -------- --------
Results of Operations............................ $170,455 $14,022 $18,616 $10,476 $(11,971) $201,598
======== ======= ======= ======= ======== ========
1996
Operating Revenues
Associated Companies........................... $253,629 $13,715 $ - $ - $ - $267,344
Trade.......................................... 281,522 48,717 83,536 20,691 - 434,466
Gains on Sales of Reserves and Related
Assets....................................... 19,127 670 - - - 19,797
-------- ------- ------- ------- -------- --------
Total.................................... 554,278 63,102 83,536 20,691 - 721,607
Exploration Expenses, including Dry Hole......... 45,291 5,003 2,082 748 15,078 68,202
Production Costs................................. 77,352 16,633 14,577 9,890 - 118,452
Impairment of Unproved Oil and Gas Properties.... 18,571 2,284 - - 371 21,226
Depreciation, Depletion and Amortization......... 208,872 24,935 15,447 611 648 250,513
-------- ------- ------- ------- -------- --------
Income (Loss) before Income Taxes................ 204,192 14,247 51,430 9,442 (16,097) 263,214
Income Tax Provision (Benefit)................... 54,412 5,674 28,287 4,721 (50) 93,044
-------- ------- ------- ------- -------- --------
Results of Operations............................ $149,780 $ 8,573 $23,143 $ 4,721 $(16,047) $170,170
======== ======= ======= ======= ======== ========
1995
Operating Revenues
Associated Companies........................... $223,652 $ 6,893 $ - $ - $ - $230,545
Trade.......................................... 122,567 36,815 71,686 15,411 - 246,479
Gains on Sales of Reserves and Related
Assets....................................... 62,737 84 - - - 62,821
-------- ------- ------- ------- -------- --------
Total.................................... 408,956 43,792 71,686 15,411 - 539,845
Exploration Expenses, including Dry Hole......... 35,298 3,839 374 (98) 15,542 54,955
Production Costs................................. 63,734 13,825 8,176 10,553 - 96,288
Impairment of Unproved Oil and Gas Properties.... 21,981 1,734 - - - 23,715
Depreciation, Depletion and Amortization......... 180,788 19,533 14,633 335 368 215,657
-------- ------- ------- ------- -------- --------
Income (Loss) before Income Taxes................ 107,155 4,861 48,503 4,621 (15,910) 149,230
Income Tax Provision (Benefit)................... 1,226 1,133 26,677 2,311 (1,335) 30,012
-------- ------- ------- ------- -------- --------
Results of Operations............................ $105,929 $ 3,728 $21,826 $ 2,310 $(14,575) $119,218
======== ======= ======= ======= ======== ========
</TABLE>
- ---------------
(1) Excludes net revenues associated with other marketing activities, interest
charges, general corporate expenses and certain gathering and handling fees
for each of the three years in the period ended December 31, 1997. The
gathering and handling fees and other marketing net revenues are directly
associated with oil and gas operations with regard to segment reporting as
defined in SFAS No. 14 - "Financial Reporting for Segments of a Business
Enterprise", but are not part of Disclosures about Oil and Gas Producing
Activities as defined in SFAS No. 69.
F-30
<PAGE> 63
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved
Oil and Gas Reserves. The following information has been developed utilizing
procedures prescribed by SFAS No. 69 and based on crude oil and natural gas
reserve and production volumes estimated by the engineering staff of the
Company. It may be useful for certain comparison purposes, but should not be
solely relied upon in evaluating the Company or its performance. Further,
information contained in the following table should not be considered as
representative of realistic assessments of future cash flows, nor should the
Standardized Measure of Discounted Future Net Cash Flows be viewed as
representative of the current value of the Company.
The future cash flows presented below are based on sales prices, cost
rates, and statutory income tax rates in existence as of the date of the
projections. It is expected that material revisions to some estimates of crude
oil and natural gas reserves may occur in the future, development and production
of the reserves may occur in periods other than those assumed, and actual prices
realized and costs incurred may vary significantly from those used.
Management does not rely upon the following information in making
investment and operating decisions. Such decisions are based upon a wide range
of factors, including estimates of probable as well as proved reserves, and
varying price and cost assumptions considered more representative of a range of
possible economic conditions that may be anticipated.
The presentation of the standardized measure of discounted future net cash
flows and changes therein excludes, for each of the years presented, amounts
attributable to future deliveries required under a volumetric production payment
at the equivalent wellhead value. In order to calculate such amounts, the
Company has assumed that deliveries under the volumetric production payment are
made as scheduled and that production costs corresponding to the volumes
delivered are incurred by the Company at average rates for the properties
subject to the production payment.
The Company has also presented, as additional information, the standardized
measure of discounted future net cash flows and changes therein including
amounts attributable to future deliveries required under the volumetric
production payment. The Company believes that this information is informative to
readers of its financial statements because the related oil and gas properties
costs and deferred revenue are shown in the Company's balance sheets for each of
the years presented. This additional information is not required to be presented
in accordance with SFAS No. 69; however, the Company believes this additional
information is useful in assessing its reserve and financial position on a
comprehensive basis.
F-31
<PAGE> 64
The following table sets forth the standardized measure of discounted
future net cash flows from projected production of the Company's crude oil and
natural gas reserves at December 31, for the years ended December 31:
<TABLE>
<CAPTION>
UNITED
STATES CANADA TRINIDAD INDIA OTHER TOTAL
------ ------ -------- ----- ----- -----
<S> <C> <C> <C> <C> <C> <C>
1997
Future cash inflows(1)....................... $ 5,186,755 $ 814,195 $ 532,318 $1,633,199 $13,862 $ 8,180,329
Future production costs...................... (1,138,401) (302,965) (106,999) (422,474) (3,587) (1,974,426)
Future development costs..................... (313,463) (19,610) (400) (102,014) (1,814) (437,301)
----------- --------- --------- ---------- ------- -----------
Future net cash flows before income taxes.... 3,734,891 491,620 424,919 1,108,711 8,461 5,768,602
Future income taxes.......................... (887,521) (92,927) (215,344) (501,109) (779) (1,697,680)
----------- --------- --------- ---------- ------- -----------
Future net cash flows........................ 2,847,370 398,693 209,575 607,602 7,682 4,070,922
Discount to present value at 10% annual
rate....................................... (1,297,651) (121,381) (61,656) (287,874) (1,906) (1,770,468)
----------- --------- --------- ---------- ------- -----------
Standardized measure of discounted future net
cash flows relating to proved oil and gas
reserves................................... 1,549,719 277,312 147,919 319,728 5,776 2,300,454
Additional disclosures:
Amounts attributable to volumetric
production payment....................... 18,102 - - - - 18,102
----------- --------- --------- ---------- ------- -----------
Total discounted future net revenues,
including amounts attributable to
volumetric production payment............ $ 1,567,821 $ 277,312 $ 147,919 $ 319,728 $ 5,776 $ 2,318,556
=========== ========= ========= ========== ======= ===========
1996
Future cash inflows(1)....................... $ 9,390,661 $ 715,143 $ 709,082 $ 864,386 $ - $11,679,272
Future production costs...................... (1,639,531) (281,244) (236,643) (338,202) - (2,495,620)
Future development costs..................... (306,028) (9,014) (1,588) (150) - (316,780)
----------- --------- --------- ---------- ------- -----------
Future net cash flows before income taxes.... 7,445,102 424,885 470,851 526,034 - 8,866,872
Future income taxes.......................... (2,260,500) (98,606) (245,577) (227,177) - (2,831,860)
----------- --------- --------- ---------- ------- -----------
Future net cash flows........................ 5,184,602 326,279 225,274 298,857 - 6,035,012
Discount to present value at 10% annual
rate....................................... (2,692,833) (100,521) (68,436) (104,672) - (2,966,462)
----------- --------- --------- ---------- ------- -----------
Standardized measure of discounted future net
cash flows relating to proved oil and gas
reserves................................... 2,491,769 225,758 156,838 194,185 - 3,068,550
Additional disclosures:
Amounts attributable to volumetric
production payment....................... 75,081 - - - - 75,081
----------- --------- --------- ---------- ------- -----------
Total discounted future net revenues,
including amounts attributable to
volumetric production payment............ $ 2,566,850 $ 225,758 $ 156,838 $ 194,185 $ - $ 3,143,631
=========== ========= ========= ========== ======= ===========
1995
Future cash inflows(1)....................... $ 3,996,029 $ 502,803 $ 395,328 $ 396,130 $ - $ 5,290,290
Future production costs...................... (747,064) (203,906) (152,287) (202,410) - (1,305,667)
Future development costs..................... (297,859) (7,153) (3,610) (13,500) - (322,122)
----------- --------- --------- ---------- ------- -----------
Future net cash flows before income taxes.... 2,951,106 291,744 239,431 180,220 - 3,662,501
Future income taxes.......................... (695,843) (46,310) (105,188) (81,349) - (928,690)
----------- --------- --------- ---------- ------- -----------
Future net cash flows........................ 2,255,263 245,434 134,243 98,871 - 2,733,811
Discount to present value at 10% annual
rate....................................... (1,015,123) (68,861) (19,217) (45,470) - (1,148,671)
----------- --------- --------- ---------- ------- -----------
Standardized measure of discounted future net
cash flows relating to proved oil and gas
reserves................................... 1,240,140 176,573 115,026 53,401 - 1,585,140
Additional disclosures:
Amounts attributable to volumetric
production payment....................... 35,957 - - - - 35,957
----------- --------- --------- ---------- ------- -----------
Total discounted future net revenues,
including amounts attributable to
volumetric production payment............ $ 1,276,097 $ 176,573 $ 115,026 $ 53,401 $ - $ 1,621,097
=========== ========= ========= ========== ======= ===========
</TABLE>
- ---------------
(1) Based on year end market prices determined at the point of delivery from the
producing unit.
F-32
<PAGE> 65
Changes in Standardized Measure of Discounted Future Net Cash Flows. The
following table sets forth the changes in the standardized measure of discounted
future net cash flows at December 31, for each of the three years in the period
ended December 31, 1997.
<TABLE>
<CAPTION>
UNITED
STATES CANADA TRINIDAD INDIA OTHER TOTAL
------ ------ -------- ----- ----- -----
<S> <C> <C> <C> <C> <C> <C>
December 31, 1994........................ $ 962,805(1) $156,941 $103,430 $ 20,818 $ - $1,243,994
Sales and transfers of oil and gas
produced, net of production costs.... (268,463) (29,883) (63,510) (4,858) - (366,714)
Net changes in prices and production
costs................................ 12,079 (5,698) (37,035) 7,857 - (22,797)
Extensions, discoveries, additions and
improved recovery net of related
costs................................ 376,474(2) 38,028 53,674 46,180 - 514,356
Development costs incurred............. 29,100 2,600 1,800 - - 33,500
Revisions of estimated development
costs................................ 920 139 28,771 4,500 - 34,330
Revisions of previous quantity
estimates............................ 5,694 (5,217) 10,142 (29) - 10,590
Accretion of discount.................. 97,248 17,483 17,412 2,857 - 135,000
Net change in income taxes............. (132,614) 10,592 (8,048) (28,127) - (158,197)
Purchases of reserves in place......... 193,711 - - - - 193,711
Sales of reserves in place............. (54,441) (569) - - - (55,010)
Changes in timing and other............ 17,627 (7,843) 8,390 4,203 - 22,377
---------- -------- -------- -------- ------ ----------
December 31, 1995........................ 1,240,140(1)(2) 176,573 115,026 53,401 - 1,585,140
Sales and transfers of oil and gas
produced, net of production costs.... (437,143) (45,799) (68,959) (10,801) - (562,702)
Net changes in prices and production
costs................................ 1,817,466 57,587 60,387 53,676 - 1,989,116
Extensions, discoveries, additions and
improved recovery net of related
costs................................ 580,417 62,506 62,165 150,475 - 855,563
Development costs incurred............. 57,800 2,200 2,200 - - 62,200
Revisions of estimated development
costs................................ (14,490) (2,696) 1,010 13,500 - (2,676)
Revisions of previous quantity
estimates............................ 7,002 (1,227) 79,933 - - 85,708
Accretion of discount.................. 137,441 18,387 19,376 8,928 - 184,132
Net change in income taxes............. (655,801) (29,814) (73,985) (86,627) - (846,227)
Purchases of reserves in place......... 161,454 456 - - - 161,910
Sales of reserves in place............. (102,671) (3,561) - - - (106,232)
Changes in timing and other............ (299,846) (8,854) (40,315) 11,633 - (337,382)
---------- -------- -------- -------- ------ ----------
December 31, 1996........................ 2,491,769(1)(2) 225,758 156,838 194,185 - 3,068,550
Sales and transfers of oil and gas
produced, net of production costs.... (518,594) (53,919) (53,744) (24,827) - (651,084)
Net changes in prices and production
costs................................ (1,664,174) (19,784) 4,730 (34,611) - (1,713,839)
Extensions, discoveries, additions and
improved recovery net of related
costs................................ 374,283 37,533 - 257,256 5,616 674,688
Development costs incurred............. 52,300 1,900 - - - 54,200
Revisions of estimated development
costs................................ 3,681 4,345 1,188 (33,210) - (23,996)
Revisions of previous quantity
estimates............................ (17,257) (101) (442) 26,696 - 8,896
Accretion of discount.................. 327,724 26,287 30,956 31,669 - 416,636
Net change in income taxes............. 605,769 11,097 12,734 (90,729) 160 539,031
Purchases of reserves in place......... 43,882 52,911 - - - 96,793
Sales of reserves in place............. (28,589) (379) - - - (28,968)
Changes in timing and other............ (121,075) (8,336) (4,341) (6,701) - (140,453)
---------- -------- -------- -------- ------ ----------
December 31, 1997........................ 1,549,719(1)(2) 277,312 147,919 319,728 5,776 2,300,454
Additional disclosures:
Amounts attributable to volumetric
production payment................... 18,102 - - - - 18,102
---------- -------- -------- -------- ------ ----------
Total discounted future net revenues
relating to proved oil and gas
reserves, including amounts
attributable to volumetric production
payment, at December 31, 1997........ $1,567,821 $277,312 $147,919 $319,728 $5,776 $2,318,556
========== ======== ======== ======== ====== ==========
</TABLE>
- ---------------
(1) Excludes $60,269, $35,957, $75,081 and $18,102 at December 31, 1994, 1995,
1996 and 1997 respectively, related to a volumetric production payment.
(2) Includes approximately $77,500, $344,300 and $85,700 discounted before
income taxes, in 1995, 1996 and 1997 respectively, related to the reserves
in the Big Piney deep Paleozoic formations.
F-33
<PAGE> 66
UNAUDITED QUARTERLY FINANCIAL INFORMATION
<TABLE>
<CAPTION>
QUARTER ENDED
-----------------------------------------
MARCH 31 JUNE 30 SEPT. 30 DEC. 31
-------- -------- -------- --------
<S> <C> <C> <C> <C>
1997
Net Operating Revenues..................... $180,651 $171,753 $193,120 $237,977
======== ======== ======== ========
Operating Income........................... $ 41,170 $ 28,619 $ 48,757 $ 74,229
======== ======== ======== ========
Income before Income Taxes................. $ 37,311 $ 24,111 $ 40,975 $ 61,073
Income Tax Provision (Benefit)............. 14,246 (460) 9,802 17,912
-------- -------- -------- --------
Net Income................................. $ 23,065 $ 24,571 $ 31,173 $ 43,161
======== ======== ======== ========
Earnings per Share of Common Stock
Basic.................................... $ .15 $ .16 $ .20 $ .28
======== ======== ======== ========
Diluted.................................. $ .14 $ .16 $ .20 $ .28
======== ======== ======== ========
Average Number of Common Shares
Basic.................................... 158,866 157,489 157,072 156,076
======== ======== ======== ========
Diluted.................................. 159,790 157,950 158,049 156,808
======== ======== ======== ========
1996
Net Operating Revenues..................... $159,026 $197,113 $170,182 $204,327
======== ======== ======== ========
Operating Income........................... $ 31,997 $ 73,643 $ 46,179 $ 57,011
======== ======== ======== ========
Income before Income Taxes................. $ 27,338 $ 70,332 $ 43,361 $ 49,931
Income Tax Provision....................... 1,415 22,750 11,994 14,795
-------- -------- -------- --------
Net Income................................. $ 25,923 $ 47,582 $ 31,367 $ 35,136
======== ======== ======== ========
Earnings per Share of Common Stock
Basic.................................... $ .16 $ .30 $ .20 $ .22
======== ======== ======== ========
Diluted.................................. $ .16 $ .29 $ .19 $ .22
======== ======== ======== ========
Average Number of Common Shares
Basic.................................... 159,934 159,910 159,850 159,719
======== ======== ======== ========
Diluted.................................. 161,411 161,656 161,677 161,352
======== ======== ======== ========
1995
Net Operating Revenues..................... $155,362 $183,974 $153,006 $156,360
======== ======== ======== ========
Operating Income........................... $ 42,829 $ 73,374 $ 37,925 $ 41,181
======== ======== ======== ========
Income before Income Taxes................. $ 39,500 $ 71,331 $ 33,344 $ 39,879
Income Tax Provision....................... 9,875 23,193 376 8,492
-------- -------- -------- --------
Net Income................................. $ 29,625 $ 48,138 $ 32,968 $ 31,387
======== ======== ======== ========
Earnings per Share of Common Stock
Basic.................................... $ .19 $ .30 $ .21 $ .20
======== ======== ======== ========
Diluted.................................. $ .18 $ .30 $ .20 $ .19
======== ======== ======== ========
Average Number of Common Shares
Basic.................................... 159,972 159,965 159,916 159,817
======== ======== ======== ========
Diluted.................................. 160,677 161,494 161,260 161,028
======== ======== ======== ========
</TABLE>
F-34
<PAGE> 67
SCHEDULE II
ENRON OIL & GAS COMPANY
SCHEDULE II -- VALUATION AND QUALIFYING ACCOUNTS AND RESERVES
FOR THE YEARS ENDED DECEMBER 31, 1997, 1996 AND 1995
(IN THOUSANDS)
<TABLE>
<CAPTION>
========================================================================================================
COLUMN A COLUMN B COLUMN C COLUMN D COLUMN E
- --------------------------------------------------------------------------------------------------------
ADDITIONS DEDUCTIONS FOR
BALANCE AT CHARGED TO PURPOSE FOR BALANCE AT
BEGINNING OF COSTS AND WHICH RESERVES END OF
DESCRIPTION YEAR EXPENSES WERE CREATED YEAR
- --------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
1997
Reserves deducted from assets to
which they apply -
Revaluation of Accounts Receivable........ $7,030 $ - $ 5 $7,025
====== ====== ====== ======
1996
Reserves deducted from assets to
which they apply -
Revaluation of Accounts Receivable........ $2,571 $6,897 $2,438 $7,030
====== ====== ====== ======
1995
Reserves deducted from assets to
which they apply -
Revaluation of Accounts Receivable........ $1,022 $1,549 $ - $2,571
====== ====== ====== ======
Litigation Reserve(a)....................... $2,000 $ (379)(b) $1,621 $ -
====== ====== ====== ======
</TABLE>
- ------------------
(a) Included in Other Liabilities in the consolidated balance sheets.
(b) Includes reversal of prior year provision in excess of requirement.
S-1
<PAGE> 68
EXHIBITS
Exhibits not incorporated herein by reference to a prior filing are
designated by an asterisk (*) and are filed herewith; all exhibits not so
designated are incorporated herein by reference to the Company's Form S-1
Registration Statement, Registration No. 33-30678, filed on August 24, 1989
("Form S-1"), or as otherwise indicated.
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
3.1(a) - Restated Certificate of Incorporation of Enron Oil & Gas
Company (Exhibit 3.1 to Form S-1).
3.1(b) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company (Exhibit 4.1(b) to
Form S-8 Registration Statement No. 33-52201, filed
February 8, 1994).
3.1(c) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company (Exhibit 4.1(c) to
Form S-8 Registration Statement No. 33-58103, filed March
15, 1995).
3.1(d) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company, dated June 11,
1996 (Exhibit 3(d) to Form S-3 Registration Statement No.
333-09919, filed August 9, 1996).
3.1(e) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company, dated May 7, 1997
(Exhibit 3(e) to Form S-3 Registration Statement No.
333-44785, filed January 23, 1998).
3.2 - By-laws of Enron Oil & Gas Company dated August 23, 1989,
as amended December 12, 1990, February 8, 1994, January 19,
1996 and February 13, 1997 (Exhibit 3.2 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1996).
3.3 - Specimen of Certificate evidencing the Common Stock
(Exhibit 3.3 to Form S-1).
4.3(a) - Amended and Restated Enron Oil & Gas Company 1994 Stock
Plan (Exhibit 4.3 to Form S-8 Registration Statement No.
33-58103, filed March 15, 1995).
4.3(b) - Amendment to Amended and Restated Enron Oil & Gas Company
1994 Stock Plan, dated effective as of December 12, 1995
(Exhibit 4.3(a) to the Company's Annual Report on Form 10-K
for the year ended December 31, 1995).
4.3(c) - Amendment to Amended and Restated Enron Oil & Gas Company
1994 Stock Plan, dated effective as of December 10, 1996
(Exhibit 4.3(a) to Form S-8 Registration Statement No.
333-20841, filed January 31, 1997).
*4.3(d) - Third Amendment to Amended and Restated Enron Oil & Gas
Company 1994 Stock Plan, dated effective as of December 9,
1997.
10.2(a) - Stock Restriction and Registration Agreement dated as of
August 23, 1989 (Exhibit 10.2 to Form S-1).
*10.2(b) - Amendment to Stock Restriction and Registration Agreement,
dated December 9, 1997, between Enron Oil & Gas Company and
Enron Corp.
10.3 - 1995 Tax Allocation Agreement, entered into effective as
of December 14, 1995, between Enron Corp., Enron Oil & Gas
Company, and the subsidiaries of Enron Oil & Gas Company
listed therein as additional parties (Exhibit 10.3 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1995).
</TABLE>
E-1
<PAGE> 69
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.9(a) - Employment Agreement between Enron Oil & Gas Company and
Forrest Hoglund, dated as of September 1, 1987, as amended
(Exhibit 10.19 to Form S-1), and Second and Third
Amendments to Employment Agreement dated June 30, 1989 and
February 14, 1992, respectively (Exhibit 10.10 to Form S-1
Registration Statement No. 33-50462, filed August 5, 1992).
10.9(b) - 4th Amendment to Employment Agreement dated December 14,
1994, among Enron Corp., Enron Oil & Gas Company and
Forrest Hoglund (Exhibit 10.9(b) to the Company's Annual
Report on Form 10-K for the year ended December 31, 1994).
10.14(a) - Enron Oil & Gas Company 1993 Nonemployee Directors' Stock
Option Plan (Exhibit 10.14 to the Company's Annual Report
on Form 10-K for the year ended December 31, 1992).
10.14(b) - First Amendment to Enron Oil & Gas Company 1993
Nonemployee Directors' Stock Option Plan (Exhibit 10.14(b)
to the Company's Annual Report on Form 10-K for the year
ended December 31, 1996).
10.16 - Interest Rate and Currency Exchange Agreement, dated as of
June 1, 1991, between Enron Risk Management Services Corp.
and Enron Oil & Gas Marketing, Inc. (Exhibit 10.17 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1991), Confirmation dated June 14, 1992
(Exhibit 10.17 to Form S-1 Registration Statement, No.
33-50462, filed August 5, 1992) and Confirmations dated
March 25, 1991, April 25, 1991, and September 23, 1992
(assigned to Enron Risk Management Services Corp. by Enron
Finance Corp. pursuant to an Assignment and Assumption
Agreement, dated as of November 1, 1993, by and between
Enron Finance Corp., Enron Risk Management Services Corp.
and Enron Oil & Gas Marketing, Inc.). (Exhibit 10.16 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1993).
10.17 - Assignment and Assumption Agreement, dated as of November
1, 1993, by and between Enron Oil & Gas Marketing, Inc.,
Enron Oil & Gas Company and Enron Risk Management Services
Corp. (Exhibit 10.17 to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.18 - ISDA Master Agreement, dated as of November 1, 1993,
between Enron Oil & Gas Company and Enron Risk Management
Services Corp., and Confirmation Nos. 1268.0, 1286.0,
1291.0, 1292.0, 1304.0, 1305.0, 1321.0, 1335.0, 1338.0,
1370.0, 1471.0, 1485.0, 1486.0, 1494.0, 1495.0, 1509.0,
1514.0, 1533.01, 1569.0, 1986.0, 2217.0, 2227.0, 2278.0,
2299.0, 2372.0, 2647.0 (Exhibit 10.18 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1993).
10.19 - Letter Agreement between Colorado Interstate Gas Company
and Enron Oil & Gas Marketing, Inc. dated November 1, 1990
(Exhibit 10.18 to the Company's Annual Report on Form 10-K
for the year ended December 31, 1990).
10.23 - Gas Purchase Agreement between Enron Oil & Gas Company and
Enron Oil & Gas Marketing, Inc. dated August 22, 1989
(Exhibit 10.41 to Form S-1).
10.24 - Gas Purchase Agreement between Enron Oil & Gas Company and
Enron Oil & Gas Marketing, Inc. dated August 22, 1989
(Exhibit 10.42 to Form S-1).
10.25 - Enron Corp. 1991 Stock Plan (Exhibit 10.08 to Enron Corp.
Annual Report on Form 10-K for the year ended December 31,
1991).
10.26 - Enron Corp. 1988 Deferral Plan (Exhibit 10.49 to Form
S-1).
10.28 - Enron Executive Supplemental Survivor Benefits Plan
Effective January 1, 1987 (Exhibit 10.51 to Form S-1).
</TABLE>
E-2
<PAGE> 70
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.30 - Credit Agreement between Enron Corp. and Enron Oil & Gas
Company dated September 29, 1995 (Exhibit 10.30 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1995).
10.31 - Credit Agreement between Enron Oil & Gas Company and Enron
Corp. dated September 29, 1995 (Exhibit 10.31 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1995).
10.34(a) - Enron Oil & Gas Company 1992 Stock Plan (As Amended and
Restated effective December 14, 1994) (incorporated by
reference to Exhibit A to the Company's Proxy Statement,
dated March 27, 1995, with respect to the Company's 1995
Annual Meeting of Shareholders).
*10.34(b) - Amendment to Enron Oil & Gas Company 1992 Stock Plan (As
Amended and Restated Effective December 14, 1994).
*10.34(c) - Second Amendment to Enron Oil & Gas Company 1992 Stock
Plan (As Amended and Restated Effective December 14, 1994).
10.35 - Enron Corp. 1992 Deferral Plan (Exhibit 10.41 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1991).
10.36(a) - Conveyance of Production Payment, dated September 25,
1992, between Enron Oil & Gas Company and Cactus
Hydrocarbon 1992-A Limited Partnership (Exhibit 10.34 to
the Company's Annual Report on Form 10-K for the year ended
December 31, 1992).
10.36(b) - First Amendment to Conveyance of Production Payment, dated
effective April 1, 1993 between Enron Oil & Gas Company and
Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit
10.36(b) to the Company's Annual Report on Form 10-K for
the year ended December 31, 1993).
10.36(c) - Second Amendment to Conveyance of Production Payment,
dated effective July 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.36(c) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.36(d) - Third Amendment to Conveyance of Production Payment, dated
effective October 1, 1993 between Enron Oil & Gas Company
and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit
10.36(d) to the Company's Annual Report on Form 10-K for
the year ended December 31, 1993).
10.37(a) - Hydrocarbon Exchange Agreement dated September 25, 1992,
between Enron Oil & Gas Company and Cactus Hydrocarbon
1992-A Limited Partnership (Exhibit 10.35 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1992).
10.37(b) - Amendment to Hydrocarbon Exchange Agreement dated
effective as of January 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(b) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
10.37(c) - First Amendment to Hydrocarbon Exchange Agreement dated
effective as of April 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(c) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
10.37(d) - Second Amendment to Hydrocarbon Exchange Agreement dated
effective as of July 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(d) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
</TABLE>
E-3
<PAGE> 71
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.37(e) - Amendment to Hydrocarbon Exchange Agreement dated
effective as of August 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(e) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
10.37(f) - Fourth Amendment to Hydrocarbon Exchange Agreement, dated
effective October 1, 1993, between Enron Oil & Gas Company
and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit
10.37 to the Company's Annual Report on Form 10-K for the
year ended December 31, 1993).
10.38 - Purchase and Sale Agreement, dated September 25, 1992,
between Enron Oil & Gas Company and Cactus Hydrocarbon
1992-A Limited Partnership (Exhibit 10.36 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1992).
10.39(a) - Production and Delivery Agreement, dated September 25,
1992, between Enron Oil & Gas Company and Cactus
Hydrocarbon 1992-A Limited Partnership (Exhibit 10.37 to
the Company's Annual Report on Form 10-K for the year ended
December 31, 1992).
10.39(b) - First Amendment to Production and Delivery Agreement,
dated effective April 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.39(b) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.39(c) - Second Amendment to Production and Delivery Agreement,
dated effective July 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.39(c) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.39(d) - Third Amendment to Production and Delivery Agreement,
dated effective October 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.39(d) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.57(a) - Letter Agreement relating to Natural Gas Swap
Transactions, dated March 31, 1995, among Enron Oil & Gas
Company, Enron Corp. and Enron Capital & Trade Resources
Corp (Exhibit 10.57(a) to the Company's Annual Report on
Form 10-K for the year ended December 31, 1995).
10.57(b) - Amendment to Natural Gas Swap Transactions Letter
Agreement, dated March 31, 1995, among Enron Oil & Gas
Company, Enron Corp. and Enron Capital & Trade Resources
Corp (Exhibit 10.57(b) to the Company's Annual Report on
Form 10-K for the year ended December 31, 1995).
10.58 - Confirmation Letter (revised due to adjustments to the
attached Payment Schedule), dated March 31, 1995, between
Enron Oil & Gas Company and Enron Capital & Trade Resources
Corp. (ECT Transaction Reference No. 15198.00) (Exhibit
10.58 to the Company's Annual Report on Form 10-K for the
year ended December 31, 1995).
10.59 - Confirmation Letter (revised due to Price Change for 1998
and adjustment to the attached Payment Schedule), dated
March 31, 1995, between Enron Oil & Gas Company and Enron
Capital & Trade Resources Corp. (ECT Transaction Reference
No. 15198.01) (Exhibit 10.59 to the Company's Annual Report
on Form 10-K for the year ended December 31, 1995).
*10.60 - Services Agreement, dated January 1, 1997, between Enron
Corp. and Enron Oil & Gas Company.
</TABLE>
E-4
<PAGE> 72
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.61 - Equity Participation and Business Opportunity Agreement,
dated December 9, 1997, between Enron Oil & Gas Company and
Enron Corp. (Exhibit 10 to Form S-3 Registration Statement
No. 333-44785, filed January 23, 1998).
*10.62 - Stock Restriction and Registration Rights Agreement, dated
December 9, 1997, between Enron Corp. and Enron Oil & Gas
Company.
*10.63(a) - Enron Oil & Gas Company 1996 Deferral Plan.
*10.63(b) - First Amendment to Enron Oil & Gas Company 1996 Deferral
Plan, dated effective as of December 9, 1997.
*10.64 - Executive Employment Agreement between Enron Oil & Gas
Company and Mark G. Papa, effective as of November 1, 1997.
*21 - List of subsidiaries.
*23.1 - Consent of DeGolyer and MacNaughton.
*23.2 - Opinion of DeGolyer and MacNaughton dated January 13,
1998.
*23.3 - Consent of Arthur Andersen LLP.
*24 - Powers of Attorney.
*27 - Financial Data Schedule.
</TABLE>
E-5
<PAGE> 73
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized, on the 13th day of
March, 1998.
ENRON OIL & GAS COMPANY
(Registrant)
By /s/ WALTER C. WILSON
-----------------------------------
(Walter C. Wilson)
Senior Vice President and Chief
Financial Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed by the following persons on behalf of registrant and in
the capacities with Enron Oil & Gas Company indicated and on the 13th day of
March, 1998.
<TABLE>
<CAPTION>
SIGNATURE TITLE
--------- -----
<C> <S>
/s/ FORREST E. HOGLUND Chairman of the Board and Chief Executive
- ----------------------------------------------------- Officer and Director (Principal Executive
(Forrest E. Hoglund) Officer)
/s/ WALTER C. WILSON Senior Vice President and Chief Financial
- ----------------------------------------------------- Officer (Principal Financial Officer)
(Walter C. Wilson)
/s/ BEN B. BOYD Vice President and Controller (Principal
- ----------------------------------------------------- Accounting Officer)
(Ben B. Boyd)
FRED C. ACKMAN * Director
- -----------------------------------------------------
(Fred C. Ackman)
JAMES V. DERRICK, JR. * Director
- -----------------------------------------------------
(James V. Derrick, Jr.)
KEN L. HARRISON * Director
- -----------------------------------------------------
(Ken L. Harrison)
KENNETH L. LAY * Director
- -----------------------------------------------------
(Kenneth L. Lay)
EDWARD RANDALL, III * Director
- -----------------------------------------------------
(Edward Randall, III)
JEFFREY K. SKILLING * Director
- -----------------------------------------------------
(Jeffrey K. Skilling)
FRANK G. WISNER * Director
- -----------------------------------------------------
(Frank G. Wisner)
*By /s/ ANGUS H. DAVIS
-------------------------------------------------
(Angus H. Davis)
(Attorney-in-fact for persons indicated)
</TABLE>
<PAGE> 74
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
3.1(a) - Restated Certificate of Incorporation of Enron Oil & Gas
Company (Exhibit 3.1 to Form S-1).
3.1(b) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company (Exhibit 4.1(b) to
Form S-8 Registration Statement No. 33-52201, filed
February 8, 1994).
3.1(c) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company (Exhibit 4.1(c) to
Form S-8 Registration Statement No. 33-58103, filed March
15, 1995).
3.1(d) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company, dated June 11,
1996 (Exhibit 3(d) to Form S-3 Registration Statement No.
333-09919, filed August 9, 1996).
3.1(e) - Certificate of Amendment of Restated Certificate of
Incorporation of Enron Oil & Gas Company, dated May 7, 1997
(Exhibit 3(e) to Form S-3 Registration Statement No.
333-44785, filed January 23, 1998).
3.2 - By-laws of Enron Oil & Gas Company dated August 23, 1989,
as amended December 12, 1990, February 8, 1994, January 19,
1996 and February 13, 1997 (Exhibit 3.2 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1996).
3.3 - Specimen of Certificate evidencing the Common Stock
(Exhibit 3.3 to Form S-1).
4.3(a) - Amended and Restated Enron Oil & Gas Company 1994 Stock
Plan (Exhibit 4.3 to Form S-8 Registration Statement No.
33-58103, filed March 15, 1995).
4.3(b) - Amendment to Amended and Restated Enron Oil & Gas Company
1994 Stock Plan, dated effective as of December 12, 1995
(Exhibit 4.3(a) to the Company's Annual Report on Form 10-K
for the year ended December 31, 1995).
4.3(c) - Amendment to Amended and Restated Enron Oil & Gas Company
1994 Stock Plan, dated effective as of December 10, 1996
(Exhibit 4.3(a) to Form S-8 Registration Statement No.
333-20841, filed January 31, 1997).
*4.3(d) - Third Amendment to Amended and Restated Enron Oil & Gas
Company 1994 Stock Plan, dated effective as of December 9,
1997.
10.2(a) - Stock Restriction and Registration Agreement dated as of
August 23, 1989 (Exhibit 10.2 to Form S-1).
*10.2(b) - Amendment to Stock Restriction and Registration Agreement,
dated December 9, 1997, between Enron Oil & Gas Company and
Enron Corp.
10.3 - 1995 Tax Allocation Agreement, entered into effective as
of December 14, 1995, between Enron Corp., Enron Oil & Gas
Company, and the subsidiaries of Enron Oil & Gas Company
listed therein as additional parties (Exhibit 10.3 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1995).
10.9(a) - Employment Agreement between Enron Oil & Gas Company and
Forrest Hoglund, dated as of September 1, 1987, as amended
(Exhibit 10.19 to Form S-1), and Second and Third
Amendments to Employment Agreement dated June 30, 1989 and
February 14, 1992, respectively (Exhibit 10.10 to Form S-1
Registration Statement No. 33-50462, filed August 5, 1992).
10.9(b) - 4th Amendment to Employment Agreement dated December 14,
1994, among Enron Corp., Enron Oil & Gas Company and
Forrest Hoglund (Exhibit 10.9(b) to the Company's Annual
Report on Form 10-K for the year ended December 31, 1994).
</TABLE>
<PAGE> 75
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.14(a) - Enron Oil & Gas Company 1993 Nonemployee Directors' Stock
Option Plan (Exhibit 10.14 to the Company's Annual Report
on Form 10-K for the year ended December 31, 1992).
10.14(b) - First Amendment to Enron Oil & Gas Company 1993
Nonemployee Directors' Stock Option Plan (Exhibit 10.14(b)
to the Company's Annual Report on Form 10-K for the year
ended December 31, 1996).
10.16 - Interest Rate and Currency Exchange Agreement, dated as of
June 1, 1991, between Enron Risk Management Services Corp.
and Enron Oil & Gas Marketing, Inc. (Exhibit 10.17 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1991), Confirmation dated June 14, 1992
(Exhibit 10.17 to Form S-1 Registration Statement, No.
33-50462, filed August 5, 1992) and Confirmations dated
March 25, 1991, April 25, 1991, and September 23, 1992
(assigned to Enron Risk Management Services Corp. by Enron
Finance Corp. pursuant to an Assignment and Assumption
Agreement, dated as of November 1, 1993, by and between
Enron Finance Corp., Enron Risk Management Services Corp.
and Enron Oil & Gas Marketing, Inc.). (Exhibit 10.16 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1993).
10.17 - Assignment and Assumption Agreement, dated as of November
1, 1993, by and between Enron Oil & Gas Marketing, Inc.,
Enron Oil & Gas Company and Enron Risk Management Services
Corp. (Exhibit 10.17 to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.18 - ISDA Master Agreement, dated as of November 1, 1993,
between Enron Oil & Gas Company and Enron Risk Management
Services Corp., and Confirmation Nos. 1268.0, 1286.0,
1291.0, 1292.0, 1304.0, 1305.0, 1321.0, 1335.0, 1338.0,
1370.0, 1471.0, 1485.0, 1486.0, 1494.0, 1495.0, 1509.0,
1514.0, 1533.01, 1569.0, 1986.0, 2217.0, 2227.0, 2278.0,
2299.0, 2372.0, 2647.0 (Exhibit 10.18 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1993).
10.19 - Letter Agreement between Colorado Interstate Gas Company
and Enron Oil & Gas Marketing, Inc. dated November 1, 1990
(Exhibit 10.18 to the Company's Annual Report on Form 10-K
for the year ended December 31, 1990).
10.23 - Gas Purchase Agreement between Enron Oil & Gas Company and
Enron Oil & Gas Marketing, Inc. dated August 22, 1989
(Exhibit 10.41 to Form S-1).
10.24 - Gas Purchase Agreement between Enron Oil & Gas Company and
Enron Oil & Gas Marketing, Inc. dated August 22, 1989
(Exhibit 10.42 to Form S-1).
10.25 - Enron Corp. 1991 Stock Plan (Exhibit 10.08 to Enron Corp.
Annual Report on Form 10-K for the year ended December 31,
1991).
10.26 - Enron Corp. 1988 Deferral Plan (Exhibit 10.49 to Form
S-1).
10.28 - Enron Executive Supplemental Survivor Benefits Plan
Effective January 1, 1987 (Exhibit 10.51 to Form S-1).
10.30 - Credit Agreement between Enron Corp. and Enron Oil & Gas
Company dated September 29, 1995 (Exhibit 10.30 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1995).
10.31 - Credit Agreement between Enron Oil & Gas Company and Enron
Corp. dated September 29, 1995 (Exhibit 10.31 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1995).
</TABLE>
<PAGE> 76
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.34(a) - Enron Oil & Gas Company 1992 Stock Plan (As Amended and
Restated effective December 14, 1994) (incorporated by
reference to Exhibit A to the Company's Proxy Statement,
dated March 27, 1995, with respect to the Company's 1995
Annual Meeting of Shareholders).
*10.34(b) - Amendment to Enron Oil & Gas Company 1992 Stock Plan (As
Amended and Restated Effective December 14, 1994).
*10.34(c) - Second Amendment to Enron Oil & Gas Company 1992 Stock
Plan (As Amended and Restated Effective December 14, 1994).
10.35 - Enron Corp. 1992 Deferral Plan (Exhibit 10.41 to the
Company's Annual Report on Form 10-K for the year ended
December 31, 1991).
10.36(a) - Conveyance of Production Payment, dated September 25,
1992, between Enron Oil & Gas Company and Cactus
Hydrocarbon 1992-A Limited Partnership (Exhibit 10.34 to
the Company's Annual Report on Form 10-K for the year ended
December 31, 1992).
10.36(b) - First Amendment to Conveyance of Production Payment, dated
effective April 1, 1993 between Enron Oil & Gas Company and
Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit
10.36(b) to the Company's Annual Report on Form 10-K for
the year ended December 31, 1993).
10.36(c) - Second Amendment to Conveyance of Production Payment,
dated effective July 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.36(c) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.36(d) - Third Amendment to Conveyance of Production Payment, dated
effective October 1, 1993 between Enron Oil & Gas Company
and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit
10.36(d) to the Company's Annual Report on Form 10-K for
the year ended December 31, 1993).
10.37(a) - Hydrocarbon Exchange Agreement dated September 25, 1992,
between Enron Oil & Gas Company and Cactus Hydrocarbon
1992-A Limited Partnership (Exhibit 10.35 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1992).
10.37(b) - Amendment to Hydrocarbon Exchange Agreement dated
effective as of January 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(b) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
10.37(c) - First Amendment to Hydrocarbon Exchange Agreement dated
effective as of April 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(c) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
10.37(d) - Second Amendment to Hydrocarbon Exchange Agreement dated
effective as of July 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(d) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
10.37(e) - Amendment to Hydrocarbon Exchange Agreement dated
effective as of August 1, 1993, between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.37(e) to the Company's Annual Report on Form
10-K for the year ended December 31, 1994).
</TABLE>
<PAGE> 77
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
10.37(f) - Fourth Amendment to Hydrocarbon Exchange Agreement, dated
effective October 1, 1993, between Enron Oil & Gas Company
and Cactus Hydrocarbon 1992-A Limited Partnership (Exhibit
10.37 to the Company's Annual Report on Form 10-K for the
year ended December 31, 1993).
10.38 - Purchase and Sale Agreement, dated September 25, 1992,
between Enron Oil & Gas Company and Cactus Hydrocarbon
1992-A Limited Partnership (Exhibit 10.36 to the Company's
Annual Report on Form 10-K for the year ended December 31,
1992).
10.39(a) - Production and Delivery Agreement, dated September 25,
1992, between Enron Oil & Gas Company and Cactus
Hydrocarbon 1992-A Limited Partnership (Exhibit 10.37 to
the Company's Annual Report on Form 10-K for the year ended
December 31, 1992).
10.39(b) - First Amendment to Production and Delivery Agreement,
dated effective April 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.39(b) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.39(c) - Second Amendment to Production and Delivery Agreement,
dated effective July 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.39(c) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.39(d) - Third Amendment to Production and Delivery Agreement,
dated effective October 1, 1993 between Enron Oil & Gas
Company and Cactus Hydrocarbon 1992-A Limited Partnership
(Exhibit 10.39(d) to the Company's Annual Report on Form
10-K for the year ended December 31, 1993).
10.57(a) - Letter Agreement relating to Natural Gas Swap
Transactions, dated March 31, 1995, among Enron Oil & Gas
Company, Enron Corp. and Enron Capital & Trade Resources
Corp (Exhibit 10.57(a) to the Company's Annual Report on
Form 10-K for the year ended December 31, 1995).
10.57(b) - Amendment to Natural Gas Swap Transactions Letter
Agreement, dated March 31, 1995, among Enron Oil & Gas
Company, Enron Corp. and Enron Capital & Trade Resources
Corp (Exhibit 10.57(b) to the Company's Annual Report on
Form 10-K for the year ended December 31, 1995).
10.58 - Confirmation Letter (revised due to adjustments to the
attached Payment Schedule), dated March 31, 1995, between
Enron Oil & Gas Company and Enron Capital & Trade Resources
Corp. (ECT Transaction Reference No. 15198.00) (Exhibit
10.58 to the Company's Annual Report on Form 10-K for the
year ended December 31, 1995).
10.59 - Confirmation Letter (revised due to Price Change for 1998
and adjustment to the attached Payment Schedule), dated
March 31, 1995, between Enron Oil & Gas Company and Enron
Capital & Trade Resources Corp. (ECT Transaction Reference
No. 15198.01) (Exhibit 10.59 to the Company's Annual Report
on Form 10-K for the year ended December 31, 1995).
*10.60 - Services Agreement, dated January 1, 1997, between Enron
Corp. and Enron Oil & Gas Company.
10.61 - Equity Participation and Business Opportunity Agreement,
dated December 9, 1997, between Enron Oil & Gas Company and
Enron Corp. (Exhibit 10 to Form S-3 Registration Statement
No. 333-44785, filed January 23, 1998).
</TABLE>
<PAGE> 78
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<C> <S>
*10.62 - Stock Restriction and Registration Rights Agreement, dated
December 9, 1997, between Enron Corp. and Enron Oil & Gas
Company.
*10.63(a) - Enron Oil & Gas Company 1996 Deferral Plan.
*10.63(b) - First Amendment to Enron Oil & Gas Company 1996 Deferral
Plan, dated effective as of December 9, 1997.
*10.64 - Executive Employment Agreement between Enron Oil & Gas
Company and Mark G. Papa, effective as of November 1, 1997.
*21 - List of subsidiaries.
*23.1 - Consent of DeGolyer and MacNaughton.
*23.2 - Opinion of DeGolyer and MacNaughton dated January 13,
1998.
*23.3 - Consent of Arthur Andersen LLP.
*24 - Powers of Attorney.
*27 - Financial Data Schedule.
</TABLE>
<PAGE> 1
EXHIBIT 4.3(d)
THIRD AMENDMENT TO
AMENDED AND RESTATED ENRON OIL & GAS COMPANY
1994 STOCK PLAN
WHEREAS, ENRON OIL & GAS COMPANY (the "Company") has heretofore
adopted and maintains the Amended and Restated Enron Oil & Gas Company 1994
Stock Plan, as amended by Amendment dated effective as of December 12, 1995 and
by Amendment dated effective December 10, 1996 (the "Plan"); and
WHEREAS, the Company desires to amend the Plan;
NOW, THEREFORE, the Plan is amended as follows:
1. The following new paragraph (vi) is added to the end of
Section 5.3 of the Plan:
"(vi) Phantom Stock Units. The Committee is authorized to grant
Awards of Phantom Stock Units to eligible persons other than Directors
of the Company. Awards of Phantom Stock Units shall be evidenced by
Award Agreements. Paragraphs (ii), (iii) (iv) and (v) of this Section
5.3 shall apply to Awards of Phantom Stock Units in similar manner as
they apply to Shares of Restricted Stock, as interpreted by the
Committee, provided, however, the limitation in paragraph (ii) above
on the number of Shares of Restricted Stock which may be granted shall
apply to the total aggregate number of Awards of Shares of Restricted
Stock and Phantom Stock Units. A Phantom Stock Unit is a contractual
obligation of the Company equal in value to one Share of the Company,
which until paid is an unfunded bookkeeping credit on the records of
the Company. Such credit shall be increased by the dividends per
Share of the Company after the date of the Award. The portion of such
credit attributable to Phantom Stock Units shall be paid under
paragraph (iii) above in Shares of the Company."
2. Section 5.4 (iii) is hereby deleted in its entirety and the
following is substituted therefor:
"(iii) Limits on Transfer of Awards. Except pursuant to a "domestic
relations order" as defined in Section 414 of the Code or Section 206
of the Employee Retirement Income Security Act of 1974, as amended, no
Award (other than Released Securities) and no right under any such
Award, shall be assignable, alienable, saleable or transferable by a
Participant otherwise than by will or by the laws of descent and
distribution or, in the case of an Award of Restricted Stock, by
assignment to the Company; provided however, if so determined by the
Committee, a Participant may, in the manner established by the
Committee, designate a beneficiary of beneficiaries to exercise the
rights of the Participant and to receive any property distributable
with respect to any Award upon the death of the Participant. Each
Award and each right under any Award shall be exercisable during the
Participant's lifetime only by the Participant or, if permissible
under applicable law, by the Participant's guardian or legal
representative. No Award
-1-
<PAGE> 2
(other than Released Securities) and no right under any such Award may
be pledged, alienated, attached or otherwise encumbered, and any
purported pledge, alienation, attachment or encumbrance thereof shall
be void and unenforceable against the Company or any subsidiary."
3. Section 7.2 is hereby deleted in its entirety and the following
is substituted therefor:
"7.2 Withholding. The Company or any subsidiary of the Company is
authorized and directed (i) to withhold from any Award granted or any
payment due or any transfer made under any Award or under the Plan the
amount (in cash, Shares, other securities, other Awards, or other
property) of withholding taxes due in respect of an Award, its
exercise, or any payment or transfer under such Award or under the
Plan, and (ii) to take such other action, including but not limited
to, acceptance of already owned Shares (including Shares acquired from
the exercise of an Option or vesting of Shares of Restricted Stock),
as may be necessary to satisfy all obligations for the payment of such
taxes."
AS AMENDED HEREBY, the Plan is specifically ratified and reaffirmed.
Dated effective as of December 9, 1997.
ATTEST: ENRON OIL & GAS COMPANY
By: /s/ Angus H. Davis By: /s/ Patricia L. Edwards
------------------------------- -------------------------------
Angus H. Davis Patricia L. Edwards
Vice President, Communications Vice President, Human Resources
and Corporate Secretary & Administration
-2-
<PAGE> 1
EXHIBIT 10.2(b)
AMENDMENT TO STOCK RESTRICTION AND REGISTRATION AGREEMENT
This amendment (this "Amendment") to the Stock Restriction and
Registration Agreement dated as of August 23, 1989 (the "Agreement") is dated
as of December 9, 1997, and is entered into by Enron Oil & Gas Company, a
Delaware corporation (the "Company"), and Enron Corp., an Oregon corporation
(the "Holder").
WHEREAS, Section 7 of the Agreement provides that the Company will be
obligated to pay Registration Expenses, defined in the Agreement to include
generally all expenses incident to the performance by the Company of its
obligations under the Agreement; and
WHEREAS, the Company and the Holder desire to provide that the Holder will
be obligated to pay the expenses incident to the performance by the Company of
its obligations under the Agreement, with certain specified exceptions;
NOW, THEREFORE, in consideration of the agreements herein and other
valuable consideration, the receipt and sufficiency of which are hereby
acknowledged, the undersigned agree that the Agreement is hereby amended as
follows:
1. AMENDMENT TO SECTION 7. Section 7 of the Agreement is hereby amended to
read as follows:
7. Registration Expenses. All Registration Expenses (as defined
herein) will be borne by the selling Holders in proportion to the
number of shares registered.
As used herein, the term Registration Expenses means (a)
underwriting discounts and commissions applicable to the sale of
Restricted Stock, fees and expenses of any legal counsel, accountants
or other agents retained by any selling Holder and all other
out-of-pocket expenses incurred by any selling Holder in connection
with any registration under this Agreement and (b) all out-of-pocket
expenses incident to the Company's performance of or compliance with
this Agreement (whether or not the registration in connection with
which such expenses are incurred ultimately becomes effective),
including without limitation all registration and filing fees, fees
and expenses of compliance with securities or blue sky laws (including
reasonable fees and disbursements of counsel in connection with blue
sky qualifications of the Restricted Stock), rating agency fees,
printing expenses, messenger and delivery expenses incurred by the
Company, the fees and expenses incurred in connection with the listing
of the securities to be registered on each securities exchange on
which similar securities issued by the Company are then listed, and
fees and disbursements of counsel for the Company and its independent
certified public accountants (including the expenses of any special
audit or comfort letters required by or incident to such performance),
securities acts liability insurance (if the Company elects to obtain
such insurance), the reasonable fees and expenses of any special
experts retained by the Company in connection with such registration
and the fees and expenses of other persons retained by the Company.
The term Registration Expenses shall not include any portion of
expenses that would have been incurred by the Company in the absence
of registration, such as depreciation or rent or other charges for use
of Company property, and such term shall not include any portion of
the Company's internal expenses, such as salaries
<PAGE> 2
and expenses of its officers and employees performing drafting, due
diligence, legal or accounting duties.
2. CERTAIN DEFINED TERMS. Capitalized terms used but not defined herein
are used as defined in the Agreement.
3. GOVERNING LAW. This Amendment will be governed by and construed in
accordance with the laws of the State of Delaware.
IN WITNESS WHEREOF, this Amendment has been executed as of the date first
written above.
ENRON OIL & GAS COMPANY
By: /s/ FORREST E. HOGLUND
------------------------
Name: Forrest E. Hoglund
Title: Chairman of the Board and
Chief Executive Officer
ENRON CORP.
By: /s/ J. CLIFFORD BAXTER
------------------------
Name: J. Clifford Baxter
Title: Senior Vice President,
Corporate Development
2
<PAGE> 1
EXHIBIT 10.34(b)
AMENDMENT TO
ENRON OIL & GAS COMPANY 1992 STOCK PLAN
(As Amended and Restated Effective December 14, 1994)
WHEREAS, ENRON OIL & GAS COMPANY (the "Company") has heretofore
adopted and maintains the Enron Oil & Gas Company 1992 Stock Plan (As Amended
and Restated Effective December 14, 1994) (the "Plan"); and
WHEREAS, the Company desires to amend the Plan to revise the
definition of "retirement";
NOW, THEREFORE the plan is amended as follows:
Paragraph (r) of Section 10 is rescinded and the following new
paragraph (r) is inserted in its place:
"(r) "Retirement" shall mean with respect to an Employee of the
Company or one of its subsidiaries, after attainment of age 55 with at least 5
years of service, the Employee's termination of employment and eligibility to
receive benefits under the Enron Corp. Retirement Plan."
AS AMENDED HEREBY, the Plan is specifically ratified and reaffirmed.
Date: December 12, 1995.
ATTEST: ENRON OIL & GAS COMPANY
/s/ Angus H. Davis By: /s/ J. Chris Bryan
- --------------------------------- -----------------------------------
Corporate Secretary Title:
<PAGE> 1
EXHIBIT 10.34 (c)
SECOND AMENDMENT TO
ENRON OIL & GAS COMPANY 1992 STOCK PLAN
(As Amended and Restated Effective December 14, 1994)
WHEREAS, ENRON OIL & GAS COMPANY (the "Company") has heretofore
adopted and maintains the Enron Oil & Gas Company 1992 Stock Plan (As Amended
and Restated Effective December 14, 1994) (the "Plan"); and
WHEREAS, the Company desires to amend the Plan;
NOW, THEREFORE, the Plan is amended as follows:
1. The following new paragraph (vii) is added to the end of
Section 5.3 of the Plan:
"(vii) Phantom Stock Units. The Committee is authorized to grant
Awards of Phantom Stock Units to eligible persons other than Directors
of the Company. Awards of Phantom Stock Units shall be evidenced by
Award Agreements. Paragraphs (ii), (iii) (iv) and (v) of this Section
5.3 shall apply to Awards of Phantom Stock Units in similar manner as
they apply to Shares of Restricted Stock, as interpreted by the
Committee, provided, however, the limitation in paragraph (ii) above
on the number of Shares of Restricted Stock which may be granted shall
apply to the total aggregate number of Awards of Shares of Restricted
Stock and Phantom Stock Units. A Phantom Stock Unit is a contractual
obligation of the Company equal in value to one Share of the Company,
which until paid is an unfunded bookkeeping credit on the records of
the Company. Such credit shall be increased by the dividends per
Share of the Company after the date of the Award. The portion of such
credit attributable to Phantom Stock Units shall be paid under
paragraph (iii) above in Shares of the Company."
2. Section 5.4 (iii) is hereby deleted in its entirety and the
following is substituted therefor:
"(iii) Limits on Transfer of Awards. No Award (other than Released
Securities) and no right under any such Award shall be assignable,
alienable, saleable or transferable by a Participant other than:
(a) by will or by the laws of descent and distribution;
(b) pursuant to a "domestic relations order" as defined
in Section 414 of the Code or Section 206 of the
Employee Retirement Income Security Act of 1974, as
amended;
(c) by transfer by an eligible Participant, subject to
such rules as the Committee may adopt to preserve the
purposes of the Plan (including limiting such
transfer to Participants who are directors or senior
executives), to:
-1-
<PAGE> 2
(I) a member of his or her Immediate Family,
(II) a trust solely for the benefit of the
Participant and his or her Immediate Family,
or
(III) a partnership or limited liability company
whose only partners or shareholders are the
Participant and his or her Immediate Family
members,
(d) by designation, in a manner established by the
Committee, of a beneficiary or beneficiaries to
exercise the rights of the Participant and to receive
any property distributable with respect to any Award
upon the death of the Participant.
Each transferee described in (b) and (c) above is hereafter referred
to an a "Permitted Transferee", provided that the Committee is
notified in writing of the terms and conditions of any transfer
intended to be described in (b) or (c) and the Committee determines
that the transfer complies with the requirements of the Plan and the
applicable Award Agreement. Any purported assignment, alienation,
pledge, attachment, sale, transfer or encumbrance that does not
qualify under (a), (b), (c) or (d) shall be void and unenforceable
against the Company. "Immediate Family" means, with respect to a
particular Participant, the Participant's spouse, children or
grandchildren (including adopted and stepchildren and grandchildren).
The terms and provisions of an Award Agreement shall be binding upon
the beneficiaries, executors and administrators of the Participant and
on the Permitted Transferees of the Participant (including the
beneficiaries, executors and administrators of the Permitted
Transferees), except that Permitted Transferees shall not reassign any
Award other than by will or by the laws of descent and distribution.
An Award shall be exercised only by the Participant (or his or her
attorney in fact or guardian) (including, in the case of a
transferred Award, by a Permitted Transferee), or, in the case of the
Participant's death, by the Participant's executor or administrator
(including, in the case of a transferred Award, by the executor or
administrator of the Permitted Transferee), and all exercises of an
Award shall be accompanied by sufficient payment, as determined by the
Company, to meet its withholding tax obligation on such exercise or by
other arrangements satisfactory to the Committee to provide for such
payment."
3. Section 7.2 is hereby deleted in its entirety and the following is
substituted therefor:
"7.2 Withholding. The Company or any subsidiary of the Company is
authorized and directed (i) to withhold from any Award granted or any
payment due or any transfer made under any Award or under the Plan the
amount (in cash, Shares, other securities, other Awards, or other
property) of withholding taxes due in respect of an Award, its
exercise, or any payment or transfer under such Award or under the
Plan, and (ii) to take such other action, including but not limited
to, acceptance of already owned Shares (including Shares acquired from
the exercise of an Option or vesting of Shares of Restricted Stock),
as may be necessary to satisfy all obligations for the payment of such
taxes."
-2-
<PAGE> 3
AS AMENDED HEREBY, the Plan is specifically ratified and reaffirmed.
Dated effective as of December 9, 1997.
ATTEST: ENRON OIL & GAS COMPANY
By: /s/ Angus H. Davis By: /s/ Patricia L. Edwards
----------------------------- -----------------------------
Angus H. Davis Patricia L. Edwards
Vice President, Communications Vice President, Human Resources
and Corporate Secretary & Administration
-3-
<PAGE> 1
EXHIBIT 10.60
SERVICES AGREEMENT
This Agreement is made and entered into as of the 1st day of January,
1997, between Enron Corp., an OREGON corporation ("Enron"), and Enron Oil & Gas
Company, a Delaware corporation ("EOG").
For and in consideration of the mutual promises and conditions
contained herein, the parties hereto agree as follows:
1. In order to assist the continued and orderly conduct of
certain corporate functions currently performed by Enron for the benefit of
EOG, Enron agrees to provide and EOG agrees to purchase, subject to the terms
and conditions set forth herein, certain corporate staff and support services
(collectively, the "Services").
2. This Agreement shall become effective and Enron shall make the
Services available to EOG pursuant to the terms of this Agreement commencing on
January 1, 1997, and shall continue thereafter for a period of 10 years (unless
otherwise specified herein) and from year to year thereafter unless terminated
upon written notice by either party 60 days prior to the anniversary date of
this Agreement. IF ENRON'S STOCK OWNERSHIP IN EOG FALLS BELOW 35% OF THE
ISSUED AND OUTSTANDING COMMON STOCK OF EOG HAVING THE RIGHT TO VOTE FOR
DIRECTORS OF EOG, THEN EITHER PARTY SHALL HAVE THE RIGHT TO TERMINATE THIS
AGREEMENT BY GIVING WRITTEN NOTICE TO THE OTHER PARTY, SUCH TERMINATION TO BE
EFFECTIVE AS OF THE DATE SET FORTH IN SUCH NOTICE; PROVIDED,
<PAGE> 2
HOWEVER, THAT EOG SHALL HAVE THE RIGHT TO DELAY THE EFFECTIVE DATE OF ANY SUCH
TERMINATION BY ENRON FOR A PERIOD OF UP TO ONE YEAR IN ORDER FOR EOG TO MAKE
NECESSARY ARRANGEMENTS FOR THE SERVICES TO BE PROVIDED BY THIRD PARTIES BY SO
NOTIFYING ENRON WITHIN 15 DAYS AFTER RECEIPT OF ENRON'S NOTICE OF TERMINATION.
3. The parties understand and agree that the Services shall be
substantially identical in nature and quality to the Services provided to EOG
by Enron during the 12-month period prior to the effective date of this
Agreement.
4. EOG, as compensation for the performance of the Services,
agrees to reimburse Enron for: (i) all expenses actually incurred by Enron and
readily identifiable to EOG relating to corporate staff and support services
provided by Enron hereunder ("Direct Charges"), as identified in Exhibit A
attached hereto, which calculation shall be based on the cost incurred by Enron
in providing such Services and charged to EOG, IN EACH INSTANCE, USING THE
METHODOLOGY THAT MOST REASONABLY REFLECTS THE USE OF THE SPECIFIC SERVICE BY
EOG AND ITS SUBSIDIARIES, ON THE ONE HAND, AND BY ENRON AND ITS OTHER
SUBSIDIARIES OR AFFILIATED COMPANIES, ON THE OTHER HAND (excepting the
calculation of charges for "Rent and LHI" as indicated in Exhibit A for any
square footage occupied during the term hereof) , (ii) the actual cost of any
goods or services purchased for EOG by Enron from third parties unaffiliated
with Enron ("Operating Charges"), (iii) the actual cost or charge for
<PAGE> 3
outsourced services provided by any third party unaffiliated with Enron for EOG
under an Enron or Enron affiliate agreement with such third party ("Outsourced
Charges") and (iv) AN ALLOCATED PORTION OF ADMINISTRATIVE AND GENERAL EXPENSES
INCURRED BY ENRON FOR CORPORATE STAFF AND SUPPORT SERVICES, COMPOSED OF THOSE
SERVICES AS IDENTIFIED IN EXHIBIT B ATTACHED HERETO (EXCLUDING THOSE SERVICES
ON EXHIBIT B FOR WHICH THE AMOUNT SHOWN UNDER THE HEADING "EOG" IS $0), AND FOR
WHICH EOG DOES NOT RECEIVE DIRECT CHARGES ("ALLOCATED CHARGE"). THE ALLOCATED
CHARGE PAYABLE BY EOG UNDER CLAUSE (IV) OF THE IMMEDIATELY PRECEDING SENTENCE
WILL BE (I) THE PORTION OF THE EXPENSES REFERRED TO IN CLAUSE (IV) ALLOCATED TO
EOG USING THE MODIFIED MASSACHUSETTS FORMULA, MINUS (II) $2,800,000 PER YEAR
BEGINNING JANUARY 1, 1997; PROVIDED, HOWEVER, THAT THE ALLOCATED CHARGE DURING
ANY YEAR SHALL NOT EXCEED THE ALLOCATED CHARGE CEILING (AS DEFINED BELOW). The
$2,800,000 will be adjusted annually, in the same manner that the Allocated
Charge Ceiling is adjusted below, based upon any change in the SEASONALLY
ADJUSTED Consumer Price Index for all Urban Consumers as determined by the U.S.
Department of Labor, Bureau of Labor Statistics (the "CPI-U").
THE ALLOCATED CHARGE CEILING FOR THE YEAR 1997 SHALL BE $5,300,000. THE
ALLOCATED CHARGE CEILING FOR EACH YEAR THEREAFTER SHALL BE ADJUSTED ANNUALLY,
AS HEREINAFTER PROVIDED, FOR CHANGES IN THE CPI-U, AND ROUNDED TO THE NEAREST
$100,000.
<PAGE> 4
FOR THE PURPOSE OF COMPUTING THE EFFECTS OF THE CPI-U CHANGE ON THE
ALLOCATED CHARGE CEILING, THE PARTIES HERETO AGREE THAT THE BASE PERIOD FOR THE
CPI-U IS "1982/84 EQUALS 100", AND THE CPI-U INDEX NUMBER FOR DECEMBER 31, 1996
IS 159.2. CPI-U ADJUSTMENTS TO THE ALLOCATED CHARGE CEILING SHALL BE MADE
ANNUALLY, BASED UPON THE CPI-U INDEX NUMBER FOR THE MONTH OF DECEMBER FOR THE
IMMEDIATELY PRECEDING YEAR (SUCH ADJUSTMENTS ARE TO BE EFFECTED UPON
PUBLICATION OF THE CPI-U INDEX NUMBER FOR SUCH MONTH). IN THE EVENT THE BUREAU
OF LABOR STATISTICS SHIFTS THE CPI-U REFERRED TO HEREIN FROM THE "1982/84
EQUALS 100" BASE PERIOD TO A DIFFERENT BASE PERIOD, EOG AND ENRON AGREE TO USE
THE REBASING FACTORS PUBLISHED BY THE BUREAU OF LABOR STATISTICS FOR CONVERTING
THE "1982/84 EQUALS 100" BASE PERIOD TO THE NEW APPLICABLE BASE. IN THE EVENT
(I) WITH RESPECT TO THE CPI-U, REBASING FACTORS ARE NOT PUBLISHED OR (II) THE
CPI-U IS DISCONTINUED, A PROPER INDEX OR CLASSIFICATION WITH APPROPRIATE
ADJUSTMENT FACTORS SHALL BE SUBSTITUTED BY WRITTEN AGREEMENT BETWEEN ENRON AND
EOG.
IF THE COMPENSATION FOR ANY SERVICE DOES NOT INCLUDE SALES, USE, EXCISE
VALUE ADDED OR SIMILAR TAXES, AND IF ANY SUCH TAXES ARE IMPOSED ON THE SERVICES
AFTER THE EFFECTIVE DATE OF THIS AGREEMENT, THEN SUCH TAXES SHALL BE PAID BY
EOG.
THE METHODOLOGIES USED FOR DETERMINING DIRECT CHARGES,
<PAGE> 5
OPERATING CHARGES, OUTSOURCED CHARGES AND ALLOCATED CHARGES TO EOG WILL BE
EVALUATED PERIODICALLY TO DETERMINE WHETHER MORE ACCURATE METHODOLOGIES MAY BE
AVAILABLE FOR DETERMINING SUCH CHARGES THAN THOSE BEING USED ON THE EFFECTIVE
DATE OF THIS AGREEMENT. CHANGES IN METHODOLOGIES WILL BE IMPLEMENTED ONLY
AFTER BEING AGREED TO BY BOTH ENRON AND EOG.
5. Enron shall invoice EOG by the 15th working day of each month
for all Direct Charges, Operating Charges, Outsourced Charges and Allocated
Charges, all with respect to the preceding month. All invoices shall reflect
in reasonable detail a description of the Services performed during the
preceding month, and shall be due and payable on the last day of the month of
the invoice. In the event of default in payment by EOG, and if such payment is
not made within thirty days after written notice is sent to EOG by certified
mail to the address specified below, Enron may terminate this Agreement as to
those Services which relate to the unpaid portion of the invoice by giving
written notice of such election to EOG. In the event of a dispute as to the
propriety of invoiced amounts, EOG shall pay all undisputed amounts on each
invoice, but shall be entitled to withhold payment of any amount in dispute and
shall promptly notify Enron of its dispute. Enron shall provide EOG with
records relating to the disputed amount so as to enable the parties to resolve
the dispute. So long as the parties are attempting in good faith to resolve
the dispute, Enron shall not be entitled to terminate the Services related to
and by reason of the disputed charge.
<PAGE> 6
6. Any input necessary for Enron or any third party to perform
any Services shall be submitted by EOG in a manner consistent with the
practices utilized during the period prior to the effective date of this
Agreement, which manner shall not be altered except by mutual written agreement
of the parties. Should EOG's failure to supply such input render Enron's or
any third party's performance of any Services unreasonably difficult, Enron or
any third party, upon reasonable notice, may refuse to perform such Services
until such input is supplied.
7. EOG acknowledges that the Services shall be provided only with
respect to the business of EOG. EOG will not request performance of any
Services for the benefit of any entity other than EOG and its subsidiaries or
affiliates. EOG represents and agrees that it will use the Services only in
accordance with all applicable federal, state and local laws and regulations
and communications and common carrier tariffs, and in accordance with the
reasonable conditions, rules, regulations and specifications which may be set
forth in any manuals, materials, documents or instructions in existence on the
effective date of this Agreement and furnished by Enron to EOG. Enron or any
third party reserves the right to take all actions, including termination of
any particular Services, that Enron or any third party reasonably believes to
be necessary to assure compliance with applicable laws, regulations and
tariffs.
8. Enron will assign to EOG all user codes, passwords or numbers,
or other control or identifying cards or numbers, necessary for Enron to
perform the Services. EOG assumes full
<PAGE> 7
responsibility for selection and use of any such codes, passwords, cards or
numbers that may be permitted or required in connection with the Services
involved.
9. The Services will be of the same nature and quality as those
provided to EOG during the 12-month period prior to the effective date of this
Agreement.
ALL PRODUCTS OBTAINED FOR EOG ARE AS IS, WHERE IS, WITH ALL FAULTS.
NEITHER ENRON, ANY ENRON AFFILIATE NOR ANY THIRD PARTY PERFORMING ANY SERVICES
HEREUNDER MAKE ANY WARRANTIES OR REPRESENTATIONS WHATSOEVER, EXPRESS OR
IMPLIED, INCLUDING THE WARRANTY OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR
PURPOSE WITH RESPECT TO THE SERVICES RENDERED OR PRODUCTS OBTAINED FOR EOG.
IN NO EVENT SHALL ENRON BE LIABLE TO EOG OR ANY OTHER PERSON FOR ANY
INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES RESULTING FROM ANY ERROR IN THE
PERFORMANCE OF SERVICES OR FROM THE BREACH OF THIS AGREEMENT, REGARDLESS OF
ENRON OR ANY THIRD PARTY FAULT. TO THE EXTENT ANY THIRD PARTY HAS LIMITED ITS
LIABILITY TO ENRON FOR SERVICES UNDER AN OUTSOURCING OR OTHER AGREEMENT, EOG
AGREES TO BE BOUND BY SUCH LIMITATION OF LIABILITY FOR ANY PRODUCT OR SERVICE
PROVIDED TO EOG BY SUCH THIRD PARTY UNDER ENRON'S AGREEMENT.
Enron shall have no obligation to perform the Services if its failure
to do so is caused by or results from any act of God, governmental action,
natural disaster, strike, failure of essential equipment or any other cause or
circumstance beyond the control of Enron. Enron agrees that upon restoring
service
<PAGE> 8
following any failure of any equipment necessary for Enron to provide any
Services, Enron will allow EOG to have equal priority, in accordance with prior
practice, with respect to access to the restored service. At its election,
Enron may cause one or more of its subsidiaries (other than EOG) , affiliates
or third party contractors to provide the services called for by this
Agreement; however, such action shall not release Enron from its obligations
under this Agreement.
10. In the event any portion of this Agreement shall be found by a
court of competent jurisdiction to be unenforceable, that portion of the
Agreement will be null and void and the remainder of the Agreement will be
binding on the parties as if the unenforceable provisions had never been
contained herein.
11. This Agreement shall not be assignable by either of the
parties hereto except by operation of law.
12. This Agreement constitutes the entire agreement of the parties
relating to the performance of the Services and all prior or contemporaneous
written or oral agreements are merged herein. This Agreement may not be
changed except by a writing signed by both parties. This Agreement shall be
governed by the laws of the State of Texas.
13. Any notice, request, instruction, correspondence or other
document to be given hereunder by either party to the other (herein
collectively called "Notice") shall be in writing and delivered personally or
mailed, postage prepaid, or by facsimile or telegram, as follows:
<PAGE> 9
IF TO ENRON:
Enron Corp.
1400 Smith Street
P. 0. Box 1188
Houston, Texas 77251-1188
Attention: Senior Vice President,
Chief Accounting and Information
Officer
Facsimile No.: 713-853-3920
IF TO EOG:
Enron Oil & Gas Company
1400 Smith Street
P. 0. Box 4362
Houston, Texas 77210-4362
Attention: Senior Vice President and
Chief Financial Officer
Facsimile No.: 713-646-2113
Notice given by personal delivery or mail shall be effective upon actual
receipt by the party to whom addressed. Notice given by facsimile or telegram
shall be effective upon actual receipt if received during the recipient's
normal business hours, or at the beginning of the recipient's next business day
after receipt if not received during the recipient's normal business hours.
Any party may change any address to which Notice is to be given to it by giving
Notice as provided above of such change of address.
<PAGE> 10
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be signed
on the date(s) noted below on their behalf by their duly authorized officers
effective as of January 1, 1997.
ENRON CORP.
By: /s/ J. CLIFFORD BAXTER
------------------------------------
J. Clifford Baxter,
Senior Vice President,
Corporate Development
Date: December 9, 1997
ENRON OIL & GAS COMPANY
By: /s/ FORREST E HOGLUND
------------------------------------
Forrest E. Hoglund
Chairman of the Board
and Chief Executive Officer
Date: December 9, 1997
<PAGE> 11
EXHIBIT A
<TABLE>
<CAPTION>
Major Sub
Cat. Cat. RC# Title Charge Basis
- ----------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
PENSION, THRIFT & MEDICAL
2320 Savings Plan Head Count
* 2321 Retirement Plan Demographics (see note below)
2323 EE Life, AD&D Dep Head Count
2324 Long Term Disability Head Count
* 2325 Supp. Exec. Retirement Plan Demographics (see note below)
2326 ESOP Admin. Fees Head Count
2338(2333) Business Travel Insurance Head Count
* 2335 FAS 106 Demographics (see note below)
2356 Adm. Fees For Met Life Head Count
2330 HMO Premiums Head Count
2331 Drug Plan - Admin. Chgs. Head Count
2337 Active Medical/Dental Head Count
</TABLE>
*NOTE: The effective date for change in methodology for these items
will be the later of January 1, 1996 or the beginning of the 22nd month
prior to the date of the Equity Participation and Business Opportunity
Agreement between EOG and Enron Corp.
<TABLE>
<S> <C> <C> <C> <C>
COMPENSATION PLANS
2314 Restricted Stock Actual Participation
0028 Long-term Incentive Plan Actual Participation
1148 Perf. Based Rest. Stock Actual Participation
AVIATION
0781 Aviation Reservation Fee Usage
0782 Aviation Usage Usage
BUILDING FACILITIES & SERVICES
Building Rent & Related
0566 Construction Services Usage
0580 Facility Planning Usage
0581 Facility Maintenance EB Space
0629 Corporate Security EB Space
0666 Recycling Usage
0692 EPCO-Churn Relocation Usage
0898 Office Relocation/Furniture EB Space
1829 International Security Usage
2234 Facilities Operatons EB Space
2441 Building Utilities EB Space
2455 Building Rent and LHI EB Space @ 13.50/sq. ft. up to
170K sq. ft. Amounts over 170K
will be negotiated separately.
Parking Garage Svcs. and Transp. Subs.
0060 Service Garage Employee Election
2478 Parking Employee Election
2334 Transportation Subsidy Employee Election
Copy, Graphics & Audio Visual Services
0224 Forms Management Usage
0228 Copier Center Usage
0339 Artistic Services Usage
0703 Audio Visual Services Usage
2255 Convenience Copiers Usage
</TABLE>
<PAGE> 12
EXHIBIT A
<TABLE>
<CAPTION>
Major Sub
Cat. Cat. RC# Title Charge Basis
- --------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
BUILDING FACILITIES & SERVICES(continued)
Mail, Shipping & Receiving
0103 Shipping & Receiving Usage
0492 Mail Center Usage
Records Related Costs
0215 Record Center Houston Usage
0489 Record & Info Management Usage
Real Estate Management
0075 EPCO Administration Usage
0508 Real Estate Management Usage
0752 EPCO Legal Services Usage
Health & Employee Services
0647 Health & Employee Services Headcount
0776 Manager - Wellness Headcount
2453 Cafeteria Headcount
2454 Body Shop Headcount
2460 Employee Recreation Headcount
2475 Coffee Headcount
2477 Corporate Special Events Mgt. Comm. Member Head Count
Telecommunications
0117 Enron Information Services % of Total EIS Services
2357 Telecomm. Houston Operations Usage
2358 Computer Services Usage
2359 Ardmore Center Usage
OUTSIDE PROFESSIONAL SERVICES
2349 Outside Auditing Fees Per AA&Co.
0408 Contract Audit Services Per AA&Co.
INSURANCE
2411 Insurance Premiums/Cost Methodology representing
basis for premiums
DATA PROCESSING COSTS
EIS Charges Usage
EDS Charges Usage
Amortization of EDS Pre-paids Historical Usage
HR & BENEFITS RELATED
0071 Alcohol/Drug Testing Usage
0208 Compensation & Benefits Replaced by 2012
0319 Corporate Human Resources Head Count
0246 Payroll Head Count
0649 Benefits Accounting Replaced by 2012
2012 EMI Management Fee Head Count
2242 Fair Employment Head Count
</TABLE>
<PAGE> 13
EXHIBIT A
<TABLE>
<CAPTION>
Major Sub
Cat. Cat. RC# Title Charge Basis
- --------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
RECRUITING, TRAINING & FAIR EMPLOYMENT PRACTICES
0658 Corp. Org. Development & Trng. Head Count
1150 Corp HR Services Usage-moved from HR
1121 VP - Recruit, Trng. & FEP Head Count
TREASURY, FINANCE & RISK MANAGEMENT
Bank Fees Usage
0410 Risk Management Primarily % of Premiums
0451 Treasury Usage
0041 Corporate Finance Usage
TAX
0441 State Tax Group Usage
0564 Ad Valorem Tax Dept. Usage
LEGAL
0610 Corporate Secretary Usage
0611 Misc. MLP Expenses Usage
0854 Legal Litigation Usage
0860 Corporate Legal Usage
0861 Environmental Legal Usage
2416 Legal Library Attny. Head Count
INVESTOR RELATIONS
0405 Investor Relations Usage
EMPLOYEE MATCHING
2381 Corp. Contributions - Houston Employee Elections
CORPORATE EVENTS
1274 Management Conference Attendees
1137 Enron Earth Day Headcount
1140 Volunteer Events Headcount
1284 Employee Picnic Headcount
2397 Employee Communications Headcount
</TABLE>
<PAGE> 14
EXHIBIT B
<TABLE>
<CAPTION>
Total Enron
RC Net Oil &
Description* Number Expenses Gas
- -------------------------------- ------- ----------- ----------
<S> <C> <C> <C>
MMF % 22.10%
Direct Cost In - Shared Services $14,166,000 $3,130,686
Direct Cost In - Other 2,783,457 615,144
Executive Consultants 89 2,000,000 442,000
Corporate Financial Planning 137 1,008,000 222,768
Corporate Accounting & Reporting 138 1,811,000 400,231
Competitive Analysis 150 440,000 0
Sr. Vice President - Corporate Mkt. & Resources 302 1,117,000 246,857
Sr. Vice President - CIAAO 303 602,000 133,042
President and COO 304 1,800,000 397,800
Chief of Staff 305 693,000 153,153
Corporate Affairs 307 619,000 136,799
Executive Reception 308 544,000 120,224
Political Action Committee 309 34,000 7,514
Workforce Diversity 315 383,000 84,643
Investor Relations 405 1,663,000 0
Vice President - Tax 445 2,816,000 0
Corporate Development 460 706,000 156,026
Vice President & Treasurer 588 473,000 104,533
Corporate Secretary 610 1,616,000 0
MLP Services 611 60,000 0
Organizational Development & Testing 658 0 0
Government Affairs & Public Policy 808 0 0
Public Policy Analysis 848 192,000 0
Corporate Legal 860 1,259,000 0
Federal Government Affairs 866 1,283,000 283,543
State Government Affairs 870 913,000 201,773
Chairman and CEO 890 2,100,000 464,100
Corporate Advertising 1109 0 0
Corporate Aircraft Usage 2001 4,365,300 964,731
NQ Stock Plan 2315 0 0
Exec Perqs 2317 0 0
Employee Performance Awards 2318 150,000 33,150
Corporate Contributions - Houston 2381 0 0
Corporate Memberships 2396 490,000 108,290
Employee Communications 2397 359,800 79,516
Corporate Communications 2398 684,600 151,297
Media Relations 2399 1,942,000 429,182
Executive Board Meeting Expenses 2418 1,034,400 228,602
1997 EOG Service Agreement Reduction (2,800,000)
1997 EOG Service Agreement Cap Adjustment 0 (1,186,000)
----------- ----------
TOTAL $50,107,557 $5,309,604 **
=========== ==========
</TABLE>
* May vary as new costs centers are created.
** The calculated 1997 amount based on the 1/94 Enron/EOG Service agreement is
$8.1mm.
<PAGE> 1
EXHIBIT 10.62
STOCK RESTRICTION AND REGISTRATION RIGHTS AGREEMENT
THIS STOCK RESTRICTION AND REGISTRATION RIGHTS AGREEMENT (the
"Agreement") dated as of December 9, 1997, is between ENRON CORP., an Oregon
corporation (the "Company"), and ENRON OIL & GAS COMPANY, a Delaware
corporation (the "Holder").
W I T N E S S E T H:
WHEREAS, the Holder owns a substantial number of options to purchase
shares of common stock, without par value (the "Common Stock"), of the Company
(the "Options");
WHEREAS, the Options are, and the Common Stock to be issued upon
exercise of such Options will be, "restricted securities" under the Securities
Act of 1933 (the "Securities Act"); and
WHEREAS, under the provisions of the Securities Act and the General
Rules and Regulations promulgated by the Securities and Exchange Commission
(the "SEC") thereunder, the Holder may be limited in the manner of selling the
shares of Common Stock owned by the Holder, absent registration under the
Securities Act of the sale of such Common Stock or the availability of another
exemption from the registration requirements of the Securities Act; and
WHEREAS, the Company and the Holder desire to set forth certain
registration rights as to such shares;
NOW, THEREFORE, in consideration of the premises and the mutual
covenants and agreements contained herein, the parties hereby agree as follows:
1. Agreement Not to Sell or Transfer Restricted Stock For a
Period of Time. The Holder agrees that it will not offer, sell, contract to
sell or otherwise dispose of any Options or shares of Common Stock except
pursuant to a registration statement under the Securities Act or an applicable
exemption therefrom.
2. Demand Registration.
a. Request for Registration. As used in this Agreement,
"Restricted Stock" shall mean all shares of Common Stock issued upon exercise
of the Options, together with any securities issued or issuable with respect to
any such Common Stock by way of stock dividend or stock split or in connection
with a combination of shares, recapitalization, merger, consolidation or other
reorganization or otherwise. As to any particular Restricted Stock, once issued
such securities shall cease to be Restricted Stock when (a) a registration
statement with respect to the sale of such securities shall have become
effective under the Securities Act and such securities shall have been
<PAGE> 2
disposed of in accordance with such registration statement, (b) such securities
shall have been sold pursuant to Rule 144 (or any successor provision) under
the Securities Act, or (c) such securities shall have been otherwise
transferred, new certificates representing such securities not bearing a legend
restricting further transfer shall have been delivered by the Company and
subsequent disposition of such securities shall not require registration or
qualification of such securities under the Securities Act or any similar state
law then in force. The Holder and any permitted assignee of the Holder's rights
and duties hereunder are referred to herein as the "Holders." Unless the
context otherwise requires, any reference herein to a Holder or Holders of
Restricted Stock shall be deemed to include reference to a holder of Options,
and any reference herein to a number of shares of Restricted Stock, to a
majority in number of shares of Restricted Stock or to all or a portion of
shares of Restricted Stock of any Holder or Holders shall be deemed to include
reference to a number of shares of Restricted Stock issuable upon exercise
thereof or to a combination of shares of Restricted Stock issuable and issued
upon exercise of Options (provided that the Company shall not be required to
file any registration statement covering resales of Options). Subject to the
conditions and limitations set forth in Section 5 of this Agreement, the Holder
or Holders of Restricted Stock holding in the aggregate at least 500,000 shares
of Restricted Stock may make a written request for registration under the
Securities Act of all or part of its or their Restricted Stock pursuant to this
Section 2 ("Demand Registration"), provided that the number of shares of
Restricted Stock proposed to be sold shall be at least 500,000 shares (subject
to appropriate adjustment for any stock dividend, stock split, combination,
recapitalization, merger, consolidation, reorganization or other occurrence
affecting the number of shares of Restricted Stock). Such request will specify
the aggregate number of shares of Restricted Stock proposed to be sold and will
also specify the intended method of disposition thereof. Within ten days after
receipt of such request, the Company will give written notice of such
registration request to all other Holders of Restricted Stock and include in
such registration all Restricted Stock with respect to which the Company has
received written requests for inclusion therein within fifteen business days
after the receipt by the applicable Holder of the Company's notice. Each such
request will also specify the aggregate number of shares of Restricted Stock to
be registered and the intended method of disposition thereof. No other party,
including the Company (but excluding another Holder of Restricted Stock), shall
be permitted to offer securities under any such Demand Registration unless the
Holder or Holders requesting the Demand Registration shall consent in writing.
b. Priority on Demand Registrations. If the Holders of a
majority in number of shares of the Restricted Stock to be registered in a
Demand Registration so elect, the offering of such Restricted Stock pursuant to
such Demand Registration shall be in the form of an underwritten offering. In
such event, if the managing underwriter or underwriters of such offering advise
the Company and the Holders in writing that in their opinion the aggregate
amount of Restricted Stock requested to be included in such offering is so
large that it will materially and adversely affect the success of such
offering, the Company will include in such registration the aggregate number of
shares of Restricted Stock which in the opinion of such managing underwriter or
underwriters can be sold without any such material adverse effect, and such
number of shares shall be allocated pro rata among the Holders of Restricted
Stock on the basis of the number of shares of Restricted Stock requested to be
included in such registration by their Holders. To the extent Restricted Stock
so
2
<PAGE> 3
requested to be registered are excluded from the offering, then the Holders of
such Restricted Stock shall have the right to one additional Demand
Registration under this Section with respect to such Restricted Stock, provided
that the failure of such Restricted Stock to be registered is through no fault
of such Holder.
c. Selection of Underwriters and Counsel. If any Demand
Registration is in the form of an underwritten offering, the Holders of a
majority in number of shares of Restricted Stock to be registered will select
and obtain the services of the investment banker or investment bankers and
manager or managers that will administer the offering and the counsel to such
investment bankers and managers; provided that such investment bankers,
managers and counsel must be approved by the Company, which approval shall not
be unreasonably withheld.
3. Piggyback Registration. If the Company proposes to file a
registration statement under the Securities Act with respect to an offering for
its own account of any class of its equity securities (other than a
registration statement on Form S-8 (or any successor form) or any other
registration statement relating solely to employee benefit plans or filed in
connection with an exchange offer, a transaction to which Rule 145 under the
Securities Act applies or an offering of securities solely to the Company's
existing stockholders), then the Company shall in each case give written notice
of such proposed filing to the Holders of Restricted Stock as soon as
practicable (but no later than five business days) before the anticipated
filing date, and such notice shall offer such Holders the opportunity to
register such number of shares of Restricted Stock as each such Holder may
request. Each Holder of Restricted Stock desiring to have such Holder's
Restricted Stock included in such registration statement shall so advise the
Company in writing within five business days after the date of Company's
notice, setting forth the amount of such Holder's Restricted Stock for which
registration is requested. If the Company's offering is to be an underwritten
offering, the Company shall, subject to the further provisions of this
Agreement, use its reasonable efforts to cause the managing underwriter or
underwriters of a proposed underwritten offering to permit the Holders of the
Restricted Stock, requested to be included in the registration for such
offering, to include such securities in such offering on the same terms and
conditions as any similar securities of the Company included therein. Moreover,
if the registration of which the Company gives notice does involve an
underwriting, the right of each Holder to registration pursuant to this Section
3 shall, unless the Company otherwise assents, be conditioned upon such
Holder's participation as a seller in such underwriting and its execution of an
underwriting agreement with the managing underwriter or underwriters selected
by the Company. Notwithstanding the foregoing, if the managing underwriter or
underwriters of such offering deliver a written opinion to the Holders of
Restricted Stock that either because of (A) the kind of securities which the
Holders, the Company and any other person or entities intend to include in such
offering or (B) the size of the offering which the Holders, the Company and
other persons intend to make, the success of the offering would be materially
and adversely affected by inclusion of the Restricted Stock requested to be
included, then (i) in the event that the size of the offering is the basis of
such managing underwriter's opinion, the number of shares to be offered for the
accounts of Holders of Restricted Stock shall be reduced pro rata or to the
extent necessary to reduce the total amount of securities to be included in
such offering to the amount recommended by such managing underwriter or
underwriters; provided that if securities are being
3
<PAGE> 4
offered for the account of other persons or entities as well as the Company,
such reduction shall not represent a greater fraction of the number or kind of
securities intended to be offered by Holders of Restricted Stock than the
fraction of similar reductions imposed on such other persons or entities over
the amount of securities of such kind they intended to offer; and (ii) in the
event that the combination of securities to be offered is the basis of such
managing underwriter's opinion, (x) the Restricted Stock to be included in such
offering shall be reduced as described in clause (i) above (subject to the
proviso in clause (i)) or, (y) if the actions described in clause (x) would, in
the judgment of the managing underwriter, be insufficient to substantially
eliminate the adverse effect that inclusion of the Restricted Stock requested
to be included would have on such offering, such Restricted Stock will be
excluded from such offering. Any Restricted Stock excluded from an underwriting
shall be withdrawn from registration and shall not, without the consent of the
Company and the manager of the underwriting, be transferred in a public
distribution prior to the earlier of 90 days (or such other shorter period of
time as the manager of the underwriting may require) after the effective date
of the registration statement or 150 days after the date the Holders of such
Restricted Stock are notified of such exclusion.
4. Registration Procedures. Whenever, pursuant to Section 2 or 3,
the Holders of Restricted Stock have requested that any Restricted Stock be
registered, the Company will, subject to the provisions of Section 5, use all
reasonable efforts to effect the registration and the sale of such Restricted
Stock in accordance with the intended method of disposition thereof as promptly
as practicable, and in connection with any such request, the Company will:
a. in connection with a request pursuant to Section 2,
prepare and file with the SEC, not later than 60 days after receipt of a
request to file a registration statement with respect to Restricted Stock, a
registration statement on any form for which the Company then qualifies and
which counsel for the Company shall deem appropriate and which form shall be
available for the sale of such Restricted Stock in accordance with the intended
method of distribution thereof, and use its reasonable efforts to cause such
registration statement to become effective; provided that if the Company shall
furnish to the Holders making such a request a certificate signed by either the
chief financial officer or the chief accounting officer of the Company stating
that in his good faith judgment it would be significantly disadvantageous to
the Company for such a registration statement to be filed on or before the date
filing would be required, the Company shall have an additional period of not
more than 90 days within which to file such registration statement; and
provided further, (i) that before filing a registration statement or prospectus
or any amendments or supplements thereto, the Company will furnish to one
counsel selected by the Holders of a majority in number of shares of the
Restricted Stock covered by such registration statement copies of all such
documents proposed to be filed, which documents will be subject to the review
of such counsel, and (ii) that after the filing of the registration statement,
the Company will promptly notify each selling Holder of Restricted Stock of any
stop order issued or, to the knowledge of the Company, threatened by the SEC
and take all reasonable actions to prevent the entry of such stop order or to
remove it if entered;
4
<PAGE> 5
b. in connection with a registration pursuant to Section
2, prepare and file with the SEC such amendments and supplements to such
registration statement and the prospectus used in connection therewith as may
be necessary to keep such registration statement effective for a period of not
less than 270 days or such shorter period as shall terminate when all
Restricted Stock covered by such registration statement have been sold (but not
before the expiration of the 90-day period referred to in Section 4(3) of the
Securities Act and Rule 174 thereunder, if applicable), and comply with the
provisions of the Securities Act with respect to the disposition of all
securities covered by such registration statement during such period in
accordance with the intended methods of disposition by the Selling Holders
thereof set forth in such registration statement;
c. as soon as reasonably practicable, furnish to each
selling Holder, prior to filing a registration statement, copies of such
registration statement as proposed to be filed, and thereafter furnish to such
selling Holder such number of copies of such registration statement, each
amendment and supplement thereto (in each case, if specified by such Holder,
including all exhibits thereto), the prospectus included in such registration
statement (including each preliminary prospectus) and such other documents as
such selling Holder may reasonably request in order to facilitate the
disposition of the Restricted Stock owned by such selling Holder;
d. with reasonable promptness, use its reasonable efforts
to register or qualify such Restricted Stock under such other securities or
blue sky laws of such jurisdictions within the United States as any selling
Holder reasonably (in light of such selling Holder's intended plan of
distribution) requests and do any and all other acts and things which may be
reasonably necessary or advisable to enable such selling Holder to consummate
the disposition in such jurisdictions of the Restricted Stock owned by such
selling Holder; provided that the Company will not be required to (i) qualify
generally to do business in any jurisdiction where it would not otherwise be
required to qualify but for this subsection d., (ii) subject itself to taxation
in any such jurisdiction or (iii) consent to general service of process in any
such jurisdiction;
e. with reasonable promptness, use reasonable efforts to
cause the Restricted Stock covered by such registration statement to be
registered with or approved by such other governmental agencies or authorities
as may be necessary by virtue of the business and operations of the Company to
enable the selling Holder or Holders thereof to consummate the disposition of
such Restricted Stock;
f. promptly notify each selling Holder of such Restricted
Stock, at any time when a prospectus relating thereto is required to be
delivered under the Securities Act, of the occurrence of any event known to the
Company requiring the preparation of a supplement or amendment to such
prospectus so that, as thereafter delivered to the purchasers of such
Restricted Stock, such prospectus will not contain an untrue statement of a
material fact or omit to state any material fact required to be stated therein
or necessary to make the statements therein not misleading and promptly make
available to each selling Holder any such supplement or amendment;
5
<PAGE> 6
g. in connection with a request pursuant to Section 2,
enter into an underwriting agreement in customary form, the form and substance
of such underwriting agreement being subject to the reasonable satisfaction of
the Company;
h. with reasonable promptness make available for
inspection by any selling Holder, any underwriter participating in any
disposition pursuant to such registration statement, and any attorney,
accountant or other agent retained by any such selling Holder or underwriter
(collectively, the "Inspectors"), all financial and other records, pertinent
corporate documents and properties of the Company (collectively, the
"Records"') as shall be reasonably necessary to enable them to exercise their
due diligence responsibility, and cause the Company's officers and employees to
supply all information reasonably requested for such purpose by any such
Inspector in connection with such registration statement; provided, however,
that the selection of any Inspector other than a selling Holder shall be
subject to the consent of the Company, which shall not be unreasonably
withheld. Each Inspector that actually reviews Records supplied by the Company
that include information that the Company determines, in good faith, to be
confidential ("Confidential Information") shall be required, prior to any such
review, to execute an agreement with the Company providing that such Inspector
shall not disclose any Confidential Information unless such disclosure is
required by applicable law or legal process. Each selling Holder of Restricted
Stock agrees that Confidential Information obtained by it as a result of such
inspections shall not be used by it as the basis for any transactions in
securities of the Company unless and until such information is made generally
available to the public. Each selling Holder of Restricted Stock further agrees
that it will, upon learning that disclosure of Confidential Information is
sought in a court of competent jurisdiction, give notice to the Company and
allow the Company, at its expense, to undertake appropriate action to prevent
disclosure of the Confidential Information. Each selling Holder also agrees
that the due diligence investigation made by the Inspectors shall be conducted
in a manner which shall not unreasonably disrupt the operations of the Company
or the work performed by the Company's officers and employees;
i. in the event such sale is pursuant to an underwritten
offering, use its reasonable efforts to obtain a comfort letter or letters from
the Company's independent public accountants in customary form and covering
such matters of the type customarily covered by comfort letters as the managing
underwriter reasonably requests;
j. otherwise use its reasonable efforts to comply with all
applicable rules and regulations of the SEC, and make available to its security
holders, as soon as reasonably practicable, an earnings statement covering a
period of twelve months, beginning within three months after the effective date
of the registration statement, which earnings statement shall satisfy the
provisions of Section 11(a) of the Securities Act; and
k. with reasonable promptness, use its reasonable efforts
to cause all such Restricted stock to be listed on each securities exchange on
which the Common Stock of the Company is then listed, provided that the
applicable listing requirements are satisfied.
6
<PAGE> 7
Each selling Holder of Restricted Stock agrees that, upon receipt of
any notice from the Company of the happening of any event of the kind described
in subsection f. hereof, such selling Holder will forthwith discontinue
disposition of Restricted Stock pursuant to the registration statement covering
such Restricted Stock until such selling Holder's receipt of the copies of the
supplemented or amended prospectus contemplated by subsection f. hereof, and,
if so directed by the Company, such selling Holder will deliver to the Company
(at the Company's expense) all copies, other than permanent file copies then in
such selling Holder's possession, of the prospectus covering such Restricted
Stock current at the time of receipt of such notice. In the event the Company
shall give any such notice, the Company shall extend the period during which
such registration statement shall be maintained effective pursuant to this
Agreement (including the period referred to in subsection b.) by the number of
days during the period from and including the date of the giving of such notice
pursuant to subsection f. hereof to and including the date when each selling
Holder of Restricted Stock covered by such registration statement shall have
received the copies of the supplemented or amended prospectus contemplated by
subsection f. hereof. Each selling Holder also agrees to notify the Company if
any event relating to such selling Holder occurs which would require the
preparation of a supplement or amendment to the prospectus so that such
prospectus will not contain an untrue statement of a material fact or omit to
state a material fact required to be stated therein or necessary to make the
statements therein not misleading.
5. Conditions and Limitations.
a. The Company's obligations under Section 2 shall be
subject to the following limitations:
i. the Company need not file a registration
statement either (x) during the period starting with the date 60 days prior to
the Company's estimated date of filing of, and ending 90 days after the
effective date of, any registration statement pertaining to securities of the
Company (other than a registration of securities in a Rule 145 transaction or
exchange offer or with respect to an employee benefit plan or dividend
reinvestment plan), provided that if such Company registration statement is not
filed within 90 days after the first date on which the Company notifies a
Holder of Restricted Stock that it will delay a Demand Registration pursuant to
this clause (x), the Company may not further postpone such Demand Registration
pursuant to this clause; or (y) during the period specified in the first
proviso of subparagraph a. of Section 4;
ii. the Company shall not be required to furnish
any audited financial statements other than those audited statements
customarily prepared at the end of its fiscal year, or to furnish any unaudited
financial information with respect to any period other than its regularly
reported interim quarterly periods unless in the absence of such other
unaudited financial information the registration statement would contain an
untrue statement of material fact or omit to state a material fact required to
be stated therein or necessary to make the statements therein not misleading;
7
<PAGE> 8
iii. except as provided in Section 2.b., the
Company shall not be required to file more than two Demand Registrations. A
registration statement will not count as a Demand Registration until it has
become effective; and
iv. the Company shall have received the
information and documents specified in Section 6 and each selling Holder shall
have observed or performed its other covenants and conditions contained in such
section and Section 8.
b. The Company's obligation under Section 3 shall be
subject to the limitations and conditions specified in such section and in
clauses (i), (ii) and (iv) of subsection a. of this Section 5, and to the
condition that the Company may at any time terminate its proposal to register
its shares and discontinue its efforts to cause a registration statement to
become or remain effective.
6. Information from and Certain Covenants of Holders of Restricted
Stock. Notices and requests delivered to the Company by Holders for whom
Restricted Stock are to be registered pursuant to this Agreement shall contain
such information regarding the Restricted Stock to be so registered, the Holder
and the intended method of disposition of such Restricted Stock as shall
reasonably be required in connection with the action to be taken. Any Holder
whose Restricted Stock is included in a registration statement pursuant to this
Agreement shall execute all consents, powers of attorney, registration
statements and other documents reasonably required to be signed by it in order
to cause such registration statement to become effective. Each selling Holder
covenants that, in disposing of such Holder's shares, such Holder will comply
with Regulation M of the SEC adopted pursuant to the Securities Exchange Act of
1934 (the "Exchange Act").
7. Registration Expenses. All Registration Expenses (as defined
herein) will be borne by the Company. Underwriting discounts and commissions
applicable to the sale of Restricted Stock shall be borne by the Holder of the
Restricted Stock to which such discount or commission relates, and each selling
Holder shall be responsible for the fees and expenses of any legal counsel,
accountants or other agents retained by such selling Holder and all other
out-of-pocket expenses incurred by such selling Holder in connection with any
registration under this Agreement.
As used herein, the term Registration Expenses means all expenses
incident to the Company's performance of or compliance with this Agreement
(whether or not the registration in connection with which such expenses are
incurred ultimately becomes effective), including without limitation all
registration and filing fees, fees and expenses of compliance with securities
or blue sky laws (including reasonable fees and disbursements of counsel in
connection with blue sky qualifications of the Restricted Stock), rating agency
fees, printing expenses, messenger and delivery expenses incurred by the
Company, internal expenses incurred by the Company (including, without
limitation, all salaries and expenses of its officers and employees performing
legal or accounting duties), the fees and expenses incurred in connection with
the listing of the securities to be registered on each securities exchange on
which similar securities issued by the Company are then listed, and fees and
disbursements of counsel for the Company and its independent certified public
accountants (including the expenses of any special audit or comfort letters
required by or incident to such
8
<PAGE> 9
performance), securities acts liability insurance (if the Company elects to
obtain such insurance), the reasonable fees and expenses of any special experts
retained by the Company in connection with such registration and the fees and
expenses of other persons retained by the Company.
8. Indemnification; Contribution.
a. Indemnification by the Company. The Company agrees to
indemnify and hold harmless each selling Holder of Restricted Stock, its
officers, directors and agents and each person, if any, who controls such
selling Holder within the meaning of either Section 15 of the Securities Act or
Section 20 of the Exchange Act, from and against any and all losses, claims,
damages, liabilities and expenses (including reasonable costs of investigation)
arising out of or based upon any untrue statement or alleged untrue statement
of a material fact contained in any registration statement or prospectus
relating to the Restricted Stock or in any amendment or supplement thereto or
in any preliminary prospectus relating to the Restricted Stock, or arising out
of or based upon any omission or alleged omission to state therein a material
fact required to be stated therein or necessary to make the statements therein
not misleading, except insofar as such losses, claims, damages, liabilities or
expenses arise out of, or are based upon, any such untrue statement or omission
or allegation thereof based upon information furnished in writing to the
Company by such selling Holder or on such selling Holder's behalf expressly for
use therein and provided further, that with respect to any untrue statement or
omission or alleged untrue statement or omission made in any preliminary
prospectus, the indemnity agreement contained in this subsection shall not
apply to the extent that any such loss, claim, damage, liability or expense
results from the fact that a copy of the final prospectus was not sent or given
to the person asserting any such losses, claims, damages, liabilities or
expenses at or prior to the written confirmation of the sale of the Restricted
Stock concerned to such person. The Company also agrees to include in any
underwriting agreement with any underwriters of the Restricted Stock provisions
indemnifying and providing for contribution to such underwriters, their
officers and directors and each person who controls such underwriters on
substantially the same basis as the provisions of this Section 8 indemnifying
and providing for contribution to the selling Holders.
b. Indemnification by Holders of Restricted Stock. Each
selling Holder agrees to indemnify and hold harmless the Company, its officers,
directors and agents and each person, if any, who controls the Company within
the meaning of either Section 15 of the Securities Act or Section 20 of the
Exchange Act, from and against any and all losses, claims, damages, liabilities
and expenses (including reasonable costs of investigation) arising out of or
based upon any untrue statement or alleged untrue statement of a material fact
contained in any registration statement or prospectus relating to the
Restricted Stock or in any amendment or supplement thereto or in any
preliminary prospectus relating to the Restricted Stock, or arising out of or
based upon any omission or alleged omission to state therein a material fact
required to be stated therein or necessary to make the statements therein not
misleading, provided (i) that such losses, claims, damages, liabilities or
expenses arise out of, or are based upon, any such untrue statement or omission
or allegation thereof based upon information furnished in writing to the
Company by such selling Holder or on such selling Holder's behalf expressly for
use therein, (ii) that with respect to any untrue statement or
9
<PAGE> 10
omission or alleged untrue statement or omission made in any preliminary
prospectus, the indemnity agreement contained in this subsection shall not
apply to the extent that any such loss, claim, damage, liability or expense
results from the fact that a copy of the final prospectus was not sent or given
to the person asserting any such losses, claims, damages, liabilities or
expenses at or prior to the written confirmation of the sale of the Restricted
Stock concerned to such person, and (iii) that no selling Holder shall be
liable for any indemnification under this Section 8 in an aggregate amount
which exceeds the total net proceeds (before deducting expenses) received by
such selling Holder from the offering. Each selling Holder also agrees to
include in any underwriting agreement with underwriters of the Restricted Stock
provisions indemnifying and providing for contribution to such underwriters,
their officers and directors and each person who controls such underwriters on
substantially the same basis as the provisions of this Section 8 indemnifying
and providing for contribution to the Company.
c. Conduct of Indemnification Proceedings. If any action
or proceeding (including any governmental investigation) shall be brought or
asserted against any indemnified party in respect of which indemnity may be
sought from an indemnifying party, the indemnifying party shall assume the
defense thereof, including the employment of counsel reasonably satisfactory to
such indemnified party, and shall assume the payment of all expenses. Such
indemnified party shall have the right to employ separate counsel in any such
action and to participate in the defense thereof, but the fees and expenses of
such counsel shall be at the expense of such indemnified party unless (i) the
indemnifying party has agreed to pay such fees and expenses, or (ii) the
indemnifying party shall have failed to assume the defense of such action or
proceeding and employ counsel reasonably satisfactory to such indemnified party
or (iii) the named parties to any such action or proceeding (including any
impleaded parties) include both such indemnified party and such indemnifying
party, and such indemnified party shall have been advised by counsel that there
may be one or more legal defenses available to such indemnified party which are
different from or additional to those available to the indemnifying party (in
which case, if such indemnified party notifies the indemnifying party in
writing that it elects to employ separate counsel at the expense of the
indemnifying party, the indemnifying party shall not have the right to assume
the defense of such action or proceeding on behalf of such indemnified party,
it being understood, however, that the indemnifying party shall not, in
connection with any one such action or proceeding or separate but substantially
similar or related actions or proceedings in the same jurisdiction arising out
of the same general allegations or circumstances, be liable for the fees and
expenses of more than one separate firm of attorneys (together with appropriate
local counsel) at any time for such indemnified party, which firm shall be
designated in writing by such indemnified party). The indemnifying party shall
not be liable for any settlement of any such action or proceeding effected
without its written consent, but if settled with its written consent, or if
there is a final judgment for the plaintiff in any such action or proceeding,
the indemnifying party agrees to indemnify and hold harmless such indemnified
party from and against any loss or liability (to the extent stated above) by
reason of such settlement or judgment.
d. Contribution. If the indemnification provided for in
this Section 8 is unavailable to the Company or the selling Holders in respect
of any losses, claims, damages,
10
<PAGE> 11
liabilities or judgments referred to therein, then each such indemnifying
party, in lieu of indemnifying such indemnified party, shall contribute to the
amount paid or payable by such indemnified party as a result of such losses,
claims, damages, liabilities and judgments, in such proportion as is
appropriate to reflect the relative fault of each such party in connection with
such statements or omissions, as well as any other relevant equitable
considerations. The relative fault of each such party shall be determined by
reference to, among other things, whether the untrue or alleged untrue
statement of a material fact or the omission or alleged omission to state a
material fact relates to information supplied by such party, and the parties'
relative intent, knowledge, access to information and opportunity to correct or
prevent such statement or omission.
The Company and the selling Holders agree that it would not
be just and equitable if contribution pursuant to this Section 8.d.
were determined by pro rata allocation or by any other method of
allocation which does not take account of the equitable considerations
referred to in the immediately preceding paragraph. The amount paid or
payable by an indemnified party as a result of the losses, claims,
damages, liabilities or judgments referred to in the immediately
preceding paragraph shall be deemed to include, subject to the
limitations set forth above, any legal or other expenses reasonably
incurred by such indemnified party in connection with investigation or
defending any such action or claim. Notwithstanding the provisions of
this Section 8.d., no selling Holder shall be required to contribute
any amount in excess of the amount by which the total price at which
the Restricted Stock of such selling Holder were offered to the public
exceeds the amount of any damages which such selling Holder has
otherwise been required to pay by reason of such untrue or alleged
untrue statement or omission or alleged omission. No person guilty of
fraudulent misrepresentation (within the meaning of Section 11(f) of
the Securities Act) shall be entitled to contribution from any person
who was not guilty of such fraudulent misrepresentation.
9. Cashless Exercises. The Company agrees to cooperate with the
Holder in order to permit the Holder to effect "cashless exercises" of Options.
10. Amendments. This Agreement may be amended or modified upon the
written consent thereto of the Company and the Holders of not less than 66-2/3%
of Restricted Stock.
11. Assignments. This Agreement shall be binding on and inure to the
benefit of the respective successors and assigns of the parties hereto.
12. Entire Agreement; Governing Law. This Agreement constitutes the
entire agreement of the parties relating to the subject matter hereof; all
prior or contemporaneous written or oral agreements are merged herein; this
Agreement shall be governed by the laws of the State of Texas.
13. Notices. Any notice, request, instruction, correspondence or
other document to be given hereunder by either party to the other (herein
collectively called "Notice") shall be in writing and delivered personally or
mailed, postage prepaid, or by telegram or telecopier, as follows:
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If to the Company:
Enron Corp.
1400 Smith Street
P. O. Box 1188
Houston, Texas 77251-1188
Attention: Vice President and Secretary
Telecopier No.: 713-853-3920
If to the Holder:
Enron Oil & Gas Company
1400 Smith Street
Houston, Texas 77002
Attention: General Counsel
Telecopier No.: 713-646-2750
Notice given by personal delivery or mail shall be effective upon actual
receipt. Notice given by telegram or telecopier shall be effective upon actual
receipt if received during the recipient's normal business hours, or at the
beginning of the recipient's next business day after receipt if not received
during the recipient's normal business hours. Any party may change any address
to which Notice is to be given to it by giving Notice as provided above of such
change of address.
IN WITNESS WHEREOF, the Company and the Holder have caused this
Agreement to be signed by their respective officers thereunto duly authorized.
ENRON CORP.
By: /s/ J. CLIFFORD BAXTER
---------------------------------------
Name: J. Clifford Baxter
Title: Senior Vice President, Corporate
Development
ENRON OIL & GAS COMPANY
By: /s/ FORREST E. HOGLUND
---------------------------------------
Name: Forrest E. Hoglund
Title: Chairman of the Board and
Chief Executive Officer
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EXHIBIT 10.63(a)
ENRON OIL & GAS COMPANY
1996 DEFERRAL PLAN
Enron Oil & Gas Company (the "Company") hereby establishes a
non-qualified deferred compensation program for certain of its employees as
described herein. The following shall constitute the terms of the Enron Oil &
Gas Company 1996 Deferral Plan (the "Deferral Plan"), effective January 1, 1996
(the "Effective Date").
I. PURPOSE
To allow key employees and outside directors of Enron Oil & Gas
Company to reduce current compensation and thereby reduce their current taxable
income, earn an attractive, tax-free rate of growth on monies deferred, and
accumulate funds on a tax-favored basis which can be used for retirement
planning or other future financial objectives.
II. ADMINISTRATION
2.1 Committee; Duties. This Plan shall be administered by a
Committee which shall consist of not more than three (3) persons appointed by
the Chief Executive Officer of the Company. Members of the Committee may be
Participants under this Plan. The Committee shall also have the authority to
make, amend, interpret, and enforce all appropriate rules and regulations for
the administration of this Plan and decide or resolve any and all questions,
including interpretations of this Plan, as may arise in connection with the
Plan. The Committee shall have the sole discretionary authority and all powers
necessary to accomplish these purposes, including, but not by way of
limitation, the right, power, authority and duty:
a. To make rules, regulations and procedures for the
administration of the Plan which are not inconsistent with the terms and
provisions hereof, provided such rules, regulations and procedures are
evidenced in writing and copies thereof are delivered to the Company;
b. To construe and interpret all terms, provisions,
conditions and limitations of the Plan;
c. To correct any defect, supply any omission, construe any
ambiguous or uncertain provisions, or reconcile any inconsistency that may
appear in the Plan, in such manner and to such extent as it shall deem
expedient to carry the Plan into effect;
d. To employ and compensate such accountants, attorneys,
investment advisors and other agents and employees as the Committee may deem
necessary or advisable in the proper and efficient administration of the Plan;
e. To determine all questions relating to eligibility;
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f. To determine the amount, manner and time of payment of any
benefits hereunder and to prescribe procedures to be followed by distributees
in obtaining benefits;
g. To prepare, file and distribute, in such manner as the
Committee determines to be appropriate, such information and material as is
required by the reporting and disclosure requirements of the Employee
Retirement Security Act of 1974, as amended;
h. And to make a determination as to the right of any person
to receive a benefit under the Plan.
2.2 Agent. In the administration of this Plan, the Committee may,
from time to time, employ an agent and delegate to it such administrative
duties as it sees fit and may, from time to time, consult with counsel who may
be counsel to the Company.
2.3 Binding Effect of Decisions. The decision or action of the
Committee in respect to any question arising out of or in connection with the
administration, interpretation and application of the Plan and the rules and
regulations promulgated hereunder shall be final, conclusive and binding upon
all persons having any interest in the Plan and shall not be subject to appeal
except as provided in Section XIII.
2.4 Indemnity of Committee. The Company shall indemnify and hold
harmless the members of the Committee against any and all claims, loss, damage,
expense or liability arising from any action or failure to act with respect to
this Plan, except in the case of gross negligence or willful misconduct by the
Committee or any of its members.
III. ELIGIBILITY
3.1 Participation. Key management and highly compensated
employees of the Company as determined by the Committee as well as outside
directors of the Company are eligible to be designated a participant
("Participant") under the Plan.
3.2 Minimum and Maximum Deferral. Each Participant may elect in
writing to defer up to 25% of his regular salary and up to 100% of his annual
bonus payable in cash, subject to such limits as the Company may establish from
year to year and to the following Plan provisions. Outside director
Participants may defer up to 100% of fees annually. The minimum deferral for
each category of compensation deferred (i.e., salary, bonus or director fees)
must be at least $2,000 for any deferral year.
3.3 Irrevocable Election. Elections to defer compensation shall
be irrevocable and shall be made prior to the first day of the calendar year
during which the compensation to be deferred shall be
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earned and payable, except that, employees becoming newly eligible may elect
within thirty (30) days after eligibility for the Plan to defer compensation to
be earned for services performed in the balance of the year remaining after
the date the deferral election is made. Such newly eligible employees shall be
deemed, for all other Plan purposes, to have made the deferral election on the
immediately preceding December 31.
3.4 Suspension of Deferral Commitment. The Committee may, in its
sole discretion upon the Participant's written request, suspend the deferral of
his salary that would otherwise occur under the deferral election, if it finds
that the Participant has suffered a financial hardship. The suspension will
take effect only with respect to deferrals which have not already been credited
to his deferred compensation account. The Participant's written request for
suspension of salary deferrals must be filed with the Committee on or before
the 15th day preceding the regular payday on which he desires the suspension to
take effect.
IV. INVESTMENT CHOICES
Participants may choose to have their deferrals of compensation
treated as having been invested in two types of investment accounts. These are
not mutually exclusive choices. A percentage of the deferred compensation may
be allocated to either account or the entire deferral may be allocated to only
one account. However, the allocation is irrevocable and funds cannot be
transferred between the two accounts. The two accounts are:
4.1 Phantom Stock Account ("PSA"). Deferrals will be treated as
if they had purchased shares of Enron Oil & Gas Company common stock at the
closing stock price on the date of deferral.
4.2 Flexible Deferral Account ("FDA"). Deferrals will be treated
as if they had been directed by Participants into various investment choices,
as determined by the Committee. Allocation of investment choices within the
FDA shall be made in increments of not less than 5% of a Participant's account
balance. Participants may choose investments once each year.
V. EARNINGS ON DEFERRALS
The Company shall establish a "Deferral Account" in the name of the
Participant on the books and records of the Company. The Account shall carry
the amount of the deferrals, as made, plus any earnings thereon, as a liability
of the Company to the Participant. A Deferral Account, PSA and/or FDA shall be
utilized solely as a device for the measurement and determination of the amount
to be paid to the Participant pursuant to this Plan.
5.1 Phantom Stock Account. Deferrals into the Participant's PSA
Deferral Account will be credited with cumulative appreciation and/or
depreciation based on the price of Enron Oil & Gas
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<PAGE> 4
Company common stock. Dividend equivalents will be credited quarterly to the
Participant's PSA Deferral Account and treated as if reinvested in Enron Oil &
Gas Company common stock.
5.2 Flexible Deferral Account. Participants will be asked to
select investment funds for their account balances, and returns on Deferral
Accounts will be based upon the performance of the Participant's investment
choices, less an administrative fee to be determined annually by the Committee.
Investment options will include different levels of risk and return such as
growth, balanced asset and bond funds, fixed interest accounts, etc.
5.3 Statement of Accounts. The Committee shall submit to each
Participant, within 120 days after the close of each plan year, a statement in
such form as the Committee deems desirable setting forth the balance to the
credit of such Participant in Participant's Deferral Account as of the last day
of the preceding plan year.
VI. TIMING OF BENEFIT PAYMENTS
Participants may elect a lump sum payout or periodic annual payouts
from two years to 15 years following the event of retirement, disability, death
or termination (except for cause). The period of benefit payments must be
chosen at the time that the election to defer compensation is made and this
election is irrevocable. A lump sum payment may be elected for any year of
Plan participation. However, the length of a multi-year payout may be elected
only one time, including elections made under the Enron Corp. 1994 Deferral
Plan, if applicable, and that annual payment period shall apply to all
subsequent deferrals for which a multi-year payout is desired.
VII. AMOUNT OF BENEFIT PAYMENTS
7.1 Phantom Stock Account. The Participant or his survivors will
have a choice at the start of the payout period as to the method of payment of
the account balance. The two methods of payment are the "PSA Method" and the
"Mid-Term Cost of Capital Method".
a. PSA Method. Under the PSA Method, the number of phantom
shares in the account at the beginning of the payout period will be treated as
if released in equal amounts over the payout period selected. The value of the
shares, and resulting payment amount, will be based on the closing price of
Enron Oil & Gas Company common stock on the Friday before the date of payment.
Dividend equivalents will be paid annually based on the number of phantom
shares remaining in the account.
b. Mid-Term Cost of Capital Method. Under the Mid-Term Cost
of Capital Method, the accumulated value of the shares (account balance) at the
beginning of the payout period will be paid in equal amounts over the payout
period selected. Interest on the declining balance will be paid
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<PAGE> 5
annually based on the Company's mid-term cost of capital, as established
annually by the Committee. If the PSA Method is chosen at the beginning of the
payout period, the Participant or his survivors may make one irrevocable
election during the payout period to change to the Mid-Term Cost of Capital
Method. The Participant cannot change from the Mid- Term Cost of Capital
Method to the PSA Method once payout has started.
7.2 Flexible Deferral Account. Payment of the account balance, as
of the beginning of the payout period, will be made in equal annual amounts
determined by dividing the account balance by the payout period selected.
Earnings/losses will be applied to the Deferral Account during the payout
period, based upon the investment choices made by the Participant or his
survivors. Earnings on the declining account balance will be paid annually.
Losses on the declining account balance will be deducted annually from the
remaining account balance and may shorten the payout period. Payments will
continue until the account balance reaches zero or the elected number of
payments have been made, whichever occurs first.
VIII. PAYMENTS AND BENEFITS
8.1 Retirement Benefit. The Account balance shall be paid as
elected by the Participant, with payments commencing by January 15 of the
calendar year following Retirement. "Retirement" means, after attainment of
age 55 with at least 5 years of service, a Participant's termination of
employment and eligibility to receive benefits under the Enron Corp. Retirement
Plan.
8.2 Disability Benefit. The Account balance shall be paid as
elected by January 15 of the calendar year following onset of the Disability.
"Disability" means a physical or mental condition of a Participant resulting
from a bodily injury or disease or mental disorder which: a) renders a
Participant incapable of continuing the further performance of his normal
employment activities with the Company and has been determined by the Committee
to be totally and permanently disabled for purposes of receiving long-term
benefits under a long-term disability plan maintained by the Company; or b)
renders a Director incapable of continuing the further performance of his
duties as a Director of the Board.
8.3 Termination Benefit. The Account balance shall be paid as
elected by the Participant in the event of termination, whether voluntary or
involuntary (except termination for cause), with payments commencing by January
15 of the calendar year following Termination.
8.4 Termination for Cause. Upon a Participant's Termination for
Cause, the Participant shall be entitled to receive the elective deferred
compensation credited to the Account; however, no interest shall be credited to
the Account. If the termination is as the result of the Participant's fraud
against or theft from the Company, the damages sustained by the Company shall
be deducted from the amount payable under this Section 8.4. Payment shall be
made in a single sum by January 15 of the calendar year following the date of
Termination for Cause. The Participant shall have no further interest in the
Account upon such termination of service and such payment. "Termination for
Cause"
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<PAGE> 6
shall mean termination of employment of Participant by the Company because of
(1) conviction of a felony relating to or in connection with the Company or the
Company's business; (2) willful refusal without proper legal cause to perform
duties and responsibilities of employment; or (3) willfully engaging in conduct
which the Participant has or reasonably should have reason to know is or will
be materially injurious to the Company. Such termination shall be effected by
notice thereof delivered by the Company to Participant and shall be effective
as of the date of such notice; provided, however, that if (a) termination is
because of Participant's willful refusal without proper legal cause to perform
any one or more of Participant's duties and responsibilities and (b) within
seven days following the date of such notice Participant shall cease such
refusal and shall use Participant's best efforts to perform such duties and
responsibilities, the termination shall not be effective, and provided further,
that the Company shall consult in good faith with Participant and provide an
opportunity for Participant to be heard prior to the Company making a
determination that any termination under (1), (2), or (3) of this paragraph is
Termination for Cause, and that failure to do so shall not constitute
Termination for Cause.
8.5 Hardship Distribution. The Committee has the authority to
make or accelerate distributions on account of hardship. Participants must
petition the Committee in writing for such distribution, which may be granted,
in the sole discretion of the Committee, on account of unforeseeable
circumstances causing urgent and severe financial hardship for the Participant.
The types of circumstances which usually meet these criteria are accidents and
illnesses, large theft and fire losses, severe financial reversals, and large
personal judgments. The distribution amount shall be limited to a reasonable,
necessary amount to eliminate the hardship.
8.6 Death Benefit. If death of the Participant should occur prior
to the commencement of any other benefits set forth in Section 8.1 - 8.4, the
Participant's beneficiary shall receive the Account balances as elected at the
time of the deferral election in lieu of any other benefits hereunder. If a
Participant dies after benefits have commenced on an installment basis, any
amounts unpaid pursuant to Section 8.1 - 8.4 shall be continued, in the manner
elected by the Participant, to the beneficiary. Interest will continue to be
paid on the Deferral Account during the period of distribution.
IX. PARTICIPANTS IN THE ENRON CORP. 1992 DEFERRAL PLAN
Any accrual credit of a Participant under the Enron Corp. 1992
Deferral Plan, and the obligation associated therewith, is assumed by the
Company upon the effective date of this Plan and shall become part of the
Participant's Deferred Benefit Account under this Plan. Each such Participant
will be allowed to make a one-time irrevocable election to have interest on his
Deferred Benefit Account credited using the Flexible Deferral Account method
effective January 1, 1996. If such an election is not timely made according to
guidelines established by the Company, such Participant's Deferred Benefit
Account will be credited with earnings based on the Company's mid-term cost of
capital, as established annually by the Committee.
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X. PARTICIPANTS IN THE PHANTOM STOCK ACCOUNT OF THE ENRON CORP. 1994
DEFERRAL PLAN
Any accrual credit of a Participant under the Enron Corp. 1994
Deferral Plan, and the obligation associated therewith, is assumed by the
Company upon the effective date of this Plan and shall become part of the
Participant's Deferred Benefit Account under this Plan. Each such participant
will be allowed to make a one-time irrevocable election to have his Phantom
Stock Account treated as if invested in the Company's common stock. If such an
election is timely made according to guidelines established by the Company,
conversion will occur on January 1, 1996 and will be based on the relative
values of Enron Corp. common stock and Company common stock as of December 29,
1995. If such an election is not made, such Participant's Phantom Stock
Account will continue to be treated as if invested in Enron Corp. common stock.
XI. BENEFICIARY DESIGNATION
11.1 Beneficiary Designation. Each Participant shall designate in
writing a legal or natural person as Beneficiary to whom benefits hereunder are
to be paid, if the Participant dies before receiving his entire Account. The
beneficiary designation may be changed by the Participant from time to time.
11.2 Amendments; Marital Status. If a Participant's compensation
is community property, any designation other than the spouse made by a
Participant then married shall not be valid or effective if any Beneficiary (or
combination thereof) is to receive more than fifty percent (50%) of such
Participant's aggregate benefits payable hereunder unless the spouse shall, in
a writing delivered to the Committee, approve such designation. Subject
thereto, any Beneficiary designation may be changed by a Participant by the
written filing of such change by a Participant by the written filing of such
change on a form prescribed by the Committee. The written designation of a new
Beneficiary will cancel all beneficiary designations previously filed.
11.3 No Beneficiary Designation. If a Participant fails to
designate a Beneficiary as provided above, or if all designated Beneficiaries
of a Participant die before the Participant, or before complete payment of all
amounts due hereunder, the Committee, in its discretion, may direct the Company
to pay the unpaid amounts to one or more of such Participant's relatives by
blood, adoption or marriage in any manner permitted by law which the Committee
considers to be appropriate, including but not limited to payment to the legal
representative or representatives of the estate of the last to die of
Participant and Participant's designated beneficiaries.
11.4 Incompetent. If, in the Committee's opinion, a Participant or
other person entitled to benefits under the Plan is under a legal disability or
is in any way incapacitated so as to be unable to manage his or her financial
affairs, then the Committee may, until claim is made by a conservator or other
person legally charged with the care of his or her person or of his estate,
direct the Company to make payment to a relative or friend of such person for
his benefit. Thereafter, any benefits under
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the Plan to which such Participant or other person is entitled shall be paid to
such conservator or other person legally charged with the care of his person or
his estate.
XII. RIGHTS OF PARTICIPANTS
12.1 Participants as General Creditors. Compensation deferred shall
be part of the general assets of the Company. The Company shall not be
required to segregate, set aside or escrow the compensation deferred, nor
earnings credited thereon. With respect to benefits payable under this Plan,
the Participants shall have the status of general creditors of the Company.
Participants may look only to the Company and its general assets for payment of
the Account.
12.2 Funding of Liabilities. In its sole discretion, the Company may
acquire insurance policies or other financial vehicles for the purpose of
providing future Company assets to meet its anticipated liabilities under this
Plan. Such policies or other investments, shall at all times be and remain
unrestricted general property and assets of the Company. Plan Participants
shall likewise have no rights, other than as general creditors, with respect to
such policies or other acquired assets.
XIII. DEFERRED COMPENSATION TRUST
13.1 Establishment of Trust. Notwithstanding any other provision or
interpretation of this Plan, the Company shall establish a trust in which to
hold cash, insurance policies or other assets to be used to make or reimburse
the Company for payments to the Participants of the benefits under this Plan,
provided, however, that the trust assets shall at all times remain subject to
the claims of general creditors of the Company in the event of the Company's
insolvency.
13.2 Trust Document. Participants shall be notified when the trust
is established and a copy of the trust document will be made available to them
on request.
13.3 Liability. The Company and not the trust shall be liable for
paying the benefits set forth in Section VIII. However, after its payment of
benefits pursuant to this Plan, the Company may be reimbursed by the trust for
the after-tax cost of the benefit payment, upon proof of payment and request
for reimbursement.
13.4 Payment of Benefits. Any payment of benefits made by the trust
shall satisfy the Company's obligation to make such payment to the affected
Participant.
XIV. EFFECT ON OTHER BENEFITS
Participation in this Plan may affect the Participant's benefit under
other Company plans which are based on compensation.
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14.1 Retirement Plan. Employees of the Company participate in the
Enron Corp. Retirement Plan. If a Participant is deferring salary, Enron
Corp.'s Pension Program for Deferral Plan Participants provides additional
pension benefits equal to the difference between the amount of pension benefits
that would have been paid had compensation not been deferred under this Plan
and the actual qualified pension plan benefits. This also applies if the
Participant is vested in the Enron Corp. Retirement Plan and terminates for
reasons other than retirement.
14.2 Savings Plan. Contributions which the Participant is entitled
to make to the Enron Corp. Savings Plan are based on a percentage of the
Participant's compensation. When electing to defer compensation under this
Plan, it will reduce the Participant's income used in determining the amount of
the Participant's compensation considered under the Savings Plan. Accordingly,
the maximum dollar amount which the Participant will be entitled to contribute
to the Savings Plan will be based on their compensation after deferral.
14.3 Employee Stock Ownership Plan (ESOP). Participation in the Plan
will impact the number of shares allocated to the Participant's ESOP accounts.
Shares are allocated to the Participant's account in part based on the
Participant's base salary. If the Participant has a salary deferral, the
determination of the amount of ESOP shares to be allocated to a Participant's
account will be based on their base salary after deferrals.
XV. CLAIMS PROCEDURE
15.1 Claim. Any claim by a Participant or his Beneficiary
(hereinafter "Claimant") for benefits shall be submitted to the Committee. The
Committee shall be responsible for deciding whether such claim is within the
scope provided by the Plan (a "Covered Claim") or is otherwise subject to
payment pursuant to the terms of any plan, and for providing full and fair
review of the decision on such claim. In addition, the Committee shall provide
a full and fair review in accordance with ERISA, including without limitation
Section 503 thereof.
15.2 Filing a Claim. Each Claimant or other interested person shall
file with the Committee such pertinent information as the Committee may
specify, and in such manner and form as the Committee may specify and provide,
and such person shall not have any rights or be entitled to any benefits or
further benefits hereunder, as the case may be, unless such information is
filed by the Claimant or on behalf of the Claimant. Each Claimant shall supply
at such times and in such manner as may be required, written proof that the
benefit is covered under the Plan. If it is determined that a Claimant has not
incurred a Covered Claim or if the Claimant shall fail to furnish such proof as
is requested, no benefits or no further benefits hereunder, as the case may be,
shall be payable to such Claimant.
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15.3 Notice of Decision. Notice of a decision by the Committee with
respect to a Claim shall be furnished to the Claimant within ninety (90) days
following the receipt of the claim by the Committee (or within ninety (90) days
following the expiration of the initial ninety (90) day period, in a case where
there are special circumstances requiring extension of time for processing the
claim). If special circumstances require an extension of time for processing
the claim, written notice of the extension shall be furnished by the Committee
to the Claimant prior to the expiration of the initial ninety (90) day period.
The notice of extension shall indicate the special circumstances requiring the
extension and the date by which the notice of decisions with respect to the
claim shall be furnished. Commencement of benefit payments shall constitute
notice of approval of a claim to the extent of the amount of the approved
benefit. If such claim shall be wholly or partially denied, such notice shall
be in writing and worded in a manner calculated to be understood by the
Claimant, and shall set forth: (1) the specific reason or reasons for the
denial; (2) specific reference to pertinent provisions of the Plan on which the
denial is based; (3) a description of any additional material or information
necessary for the Claimant to perfect the claim and an explanation of why such
material or information is necessary; and (4) an explanation of the Plan's
claims review procedure. If the Committee fails to notify the Claimant of the
decision regarding his claim in accordance with the "Claims Procedure"
provision, the claim shall be deemed denied and the Claimant shall then be
permitted to proceed with the claims review procedure provided herein.
15.4 Review of Claim. Within sixty (60) days following receipt by
the Claimant of notice of the claim denial, or within sixty (60) days following
the close of the ninety (90) day period referred to herein, or if the Committee
fails to notify the Claimant of the decision within such ninety (90) day
period, the Claimant may appeal denial of the claim by filing a written
application for review with the Committee. Following such request for review,
the Committee shall fully and fairly review the decision denying the claim.
Prior to the decision of the Committee, the Claimant shall be given an
opportunity to review pertinent documents and to submit issues and comments to
the Committee in writing. The decision of the Committee shall be made within
sixty (60) days following receipt by the Committee of the request for review
(or within one hundred and twenty (120) days after such receipt, in a case
where there are special circumstances requiring extension of time for reviewing
such denied claim). The Committee shall deliver its decision to the Claimant
in writing. If the decision on review is not furnished within the prescribed
time, the claim shall be deemed denied on review.
15.5 Final Decision. For all purposes under the Plan, the decision
with respect to a claim if no review is requested and the decision with respect
to a claim if review is requested shall be final, binding and conclusive on all
interested parties as to matters relating to the Plan.
XVI. MISCELLANEOUS PROVISIONS
16.1 Non-assignability. Neither a Participant nor anyone claiming
through him shall have any right to commute, sell, assign, transfer or
otherwise convey the right to receive any payments hereunder, which payments
and the rights thereto hereby are expressly declared to be non-assignable and
non-transferable, nor shall any such right to receive payments hereunder be
subject
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to the claims of creditors of a Participant or anyone claiming through him or
to any legal, equitable, or other proceeding or process for the enforcement of
such claims.
16.2 Right of Offset. Pursuant to the following provisions of this
paragraph 14.2, the Company shall have a right to offset any benefit payable to
a Participant under this Plan by an amount of money owed by Participant to the
Company or subsidiary or claimed by the Company or subsidiary to be owed by
Participant, for which (a) the Company or subsidiary shall file a lawsuit
against Participant and (b) recover a judgment therefor. Upon the filing of
such a lawsuit by the Company or a subsidiary against the Participant while
benefits under the Plan are payable to Participant, benefits in the amount of
judgment claimed in the lawsuit will be suspended until either a judgment is
rendered in the lawsuit which is not subject to appeal, or the lawsuit is
dismissed and such dismissal is not subject to appeal. If a final judgment is
rendered in such lawsuit, then the party in whose favor the final judgment is
rendered shall be entitled to petition the court and recover from the other
party an amount of money equal to the reasonable costs and expenses of the
successful party, including the fees and expenses of counsel, and court costs.
16.3 Tax Withholding. Notwithstanding the provisions of Section XI,
the Company may withhold from any payment made by it under the Plan such amount
or amounts as may be required for purposes of complying with the tax
withholding or other provisions of the Internal Revenue Code of 1986 or the
Social Security Act or any state or local income or employment tax act or for
purposes of paying any estate, inheritance or other tax attributable to any
amounts payable hereunder.
16.4 Non-Secured Promise. The rights under this Plan of a
Participant and any person or entity claiming through him shall be solely those
of an unsecured, general creditor of the Company. Any insurance policy or
other asset acquired or held by the Company shall not be deemed to be held by
the Company for or on behalf of a Participant, or any other person, or to be
security for the performance of any obligations hereunder of the Company, but
shall, with respect to this Plan, be a general, unpledged, unrestricted asset
of the Company. No assets held by any trust established under Section XI shall
constitute security for the performance of any obligations hereunder.
16.5 Independent of Plan. Except as otherwise expressly provided
herein, this Plan shall be independent of, and in addition to, any other
employment agreement or employment benefit agreement or plan or rights that may
exist from time to time between the parties hereto. This Plan shall not be
deemed to constitute a contract of employment between the Company and a
Participant, nor shall any provision hereof restrict the right of the Company
to discharge a Participant, or restrict the right of a Participant to terminate
his employment with the Company.
16.6 Not a Contract of Employment. The terms and conditions of this
Plan shall not be deemed to constitute a contract of employment between the
Company or a subsidiary and the Participant, and the Participant (or
Participant's Beneficiary) shall have no rights against the Company or a
subsidiary except as may otherwise be specifically provided herein. Moreover,
nothing in this Plan shall be deemed to give a Participant the right to be
retained in the service of the
11
<PAGE> 12
Company or a subsidiary or to interfere with the right of the Company or a
subsidiary to discipline or discharge Participant at any time.
16.7 Paragraph Headings. The Paragraph headings used in this Plan
are for convenience of reference only and shall not be considered in construing
this Plan.
16.8 Terms. Whenever any words are used herein in the masculine,
they shall be construed as though they were used in the feminine in all cases
where they would so apply; and wherever any words are used herein in the
singular or in the plural, they shall be construed as though they were used in
the plural or the singular, as the case may be, in all cases where they would
so apply.
16.9 Validity. In case any provision of this Plan shall be held
illegal or invalid for any reason, said illegality or invalidity shall not
affect the remaining parts hereof, but this Plan shall be construed and
enforced as if such illegal and invalid provision had never been inserted
herein.
16.10 Responsibility for Legal Effect. Neither the Committee nor the
Company makes any representations or warranties, express or implied, or assumes
any responsibility concerning the legal, tax, or other implications or effects
of this Plan.
16.11 Committee Determinations Final. Each determination provided for
in the Plan shall be made in the absolute discretion of the Committee. Any
such determination shall be binding on all persons.
16.12 Amendment. The Company may in its sole discretion amend the
Plan from time to time. No such amendment shall adversely affect the rights of
any Participant or beneficiary with respect to benefits under the Plan related
to amounts previously deferred.
16.13 Termination of the Plan at the Company's Option.
Notwithstanding any other provision of this Plan, the Company may terminate
this Plan at any time if the Committee, in its sole and absolute discretion,
determines that any change in federal or state law, or judicial or
administrative interpretation thereof, has materially affected the Company's
cost of providing the benefits otherwise payable under this Plan, or for any
other reason whatsoever. Except with the consent of a Participant, no such
termination shall adversely affect the rights of any Participant or beneficiary
with respect to benefits under the Plan related to amount previously deferred.
Notwithstanding, payment of benefits accrued under the Plan shall not be
accelerated as a result of a Plan termination but shall continue to be paid in
the normal forms provided for in the Plan.
16.14 Successors, Acquisitions, Mergers, Consolidations. The terms
and conditions of this Plan and each Deferral Election shall inure to the
benefit of and bind the Company, the Participants, their successors, assigns,
and personal representatives. The terms successors and assigns as used herein
shall include any corporate or other business entity which shall include any
consolidation, purchase or otherwise, acquire all or substantially all of the
business and assets of Enron Oil & Gas Company and successors of any such
corporation or other business entity.
12
<PAGE> 13
16.15 Controlling Law and Venue. The Plan shall be construed in
accordance with the laws of the State of Texas to the extent not preempted by
laws of the United States of America. Venue shall lie in Harris County, Texas.
Executed this 1st day of November, 1997, with the approval and authorization
of the Board of Directors.
ENRON OIL & GAS COMPANY
By: /s/ Patricia Edwards
----------------------------------------------------
Title: Vice President, Human Resources & Administration
-------------------------------------------------
ATTEST:
/s/ Angus H. Davis
---------------------------------------------------
Vice President, Communications and Corporate Secretary
13
<PAGE> 1
EXHIBIT 10.63(b)
FIRST AMENDMENT TO
ENRON OIL & GAS COMPANY 1996 DEFERRAL PLAN
WHEREAS, Enron Oil & Gas Company (the "Company") has heretofore
adopted the Enron Oil & Gas Company 1996 Deferral Plan (the "Plan"); and
WHEREAS, the Company desires to amend the Plan;
NOW, THEREFORE, the Plan is amended as follows:
1. New Section 3.5 and Section 3.6 are added to the end of
Article III:
"3.5 Stock Option Deferral. Participants, designated by
the Committee, may make an advance written election to defer receipt
of shares of Enron Oil & Gas Company common stock from the exercise of
a stock option granted under a stock plan sponsored by Enron Oil & Gas
Company, when such exercise is made by means of a stock swap using
shares owned by the Participant. Elections to defer receipt of such
shares shall be made pursuant to guidelines established by the
Committee, and the value of such shares shall be credited to a Stock
Option Deferral Account in a Participant's name who makes such an
election. A deferral credited to a Participant's Stock Option
Deferral Account shall be in an amount equal to the number of shares
deferred multiplied by the per share exercise price of the exercised
stock option, and shall be treated as if the amount of the deferral
had purchased shares of Enron Oil & Gas Company common stock at such
per share exercise price. Such deferrals will be credited with
cumulative appreciation and/or depreciation based on the price of
Enron Oil & Gas Company common stock. Dividend equivalents will be
credited quarterly to the Participant's Stock Option Deferral Account
and treated as if reinvested in Enron Oil & Gas Company common stock.
Payments from a Participant's Stock Option Deferral Account will be
made subject to applicable provisions of the Plan and the
Participant's deferral election, on a form acceptable to the
Committee. The Committee shall cause such payments to be made in
shares of Enron Oil & Gas Company common stock."
"3.6 Restricted Stock Deferral. Participants, designated
by the Committee, may make an advance written election to defer
receipt of shares of Enron Oil & Gas Company common stock to be
released according to a grant to them of Restricted Shares under a
stock plan sponsored by Enron Oil & Gas Company. Elections to defer
receipt of
<PAGE> 2
such shares shall be made pursuant to guidelines established by the
Committee, and the value of such shares shall be credited to a
Restricted Stock Deferral Account in a Participant's name who makes
such an election. A deferral credited to a Participant's Restricted
Stock Deferral Account shall be in an amount equal to the number of
shares deferred multiplied by the closing price of a share of Enron
Oil & Gas Company common stock as reported in the "NYSE -- Composite
Transactions" section of the Midwest Edition of the Wall Street
Journal on the date the shares deferred otherwise would have been
released to the Participant or, if no prices are so reported on such
day, on the last preceding day on which such closing price was
actually reported, and shall be treated as if the amount of the
deferral had purchased shares of Enron Oil & Gas Company common stock
at such closing price. Such deferrals will be credited with
cumulative appreciation and/or depreciation based on the price of
Enron Oil & Gas Company common stock. Dividend equivalents will be
credited quarterly to the Participant's Restricted Stock Deferral
Account and treated as if reinvested in Enron Oil & Gas Company common
stock. Payments from a Participant's Restricted Stock Deferral
Account will be made subject to applicable provisions of the Plan and
the Participant's deferral election, on a form acceptable to the
Committee. The Committee shall cause such payments to be made in
shares of Enron Oil & Gas Company common stock."
2. New Section 5.4 is added to the end of Article V:
"5.4 Change of FDA Elections. Before and after
commencement of benefit payments under the Plan, a Participant with deferred
compensation allocated to the FDA, may from time to time, but not more than
once a month, according to written procedures adopted by the Committee, change
his investment choices in the FDA.
3. Effective January 1, 1998, Article VI is deleted in its
entirety and the following is substituted therefor:
"VI. Timing of Benefit Payments.
6.1 Participant Elections. Participants may elect a lump
sum payout or periodic annual payouts from two years to 15 years following the
event of retirement, disability, death or termination (except for cause). The
period of benefit payments must be chosen at the time that the election to
defer compensation is made (an "Initial Payout Election"). A lump sum payment
may be elected for 1994 deferrals or for any subsequent year of Plan
participation. However, the length of a multi-year payout may be elected only
one time, and the annual payment period shall apply to all subsequent deferrals
for which a multi-year payout is elected.
-2-
<PAGE> 3
6.2 Change of Participant Elections.
A. Subject to the consent of the Committee and the
provisions of this Section 6.2, a Participant may change all of his or her
Initial Payout Election(s), other than a multi-year payout election, on a form
acceptable to the Committee (a "Revised Payout Election"), which Revised Payout
Election shall supersede and replace all prior Initial Payout Elections
previously made by the Participant with respect to all deferrals under the
Plan, except those deferrals for which a multi-year payout election has been
made; such Revised Payout Election shall apply to the Participant's aggregate
accounts of deferral for which a multi-year payout election has not been made.
In such Revised Payout Election, the Participant may designate a combination of
lump sum and annual payments from 2 to 15 years following the event of
retirement, disability, death or termination (except for cause) subject to
approval of the Committee. If in the Revised Payout Election, the Participant
wishes to elect a multi-year payout, and has previously made a multi-year
payout election with respect to a deferral under the Plan, the Participant's
Revised Payout Election will be restricted to the previous multi-year payout
election.
B. Subject to the consent of the Committee and the
provisions of this Section 6.2, from time to time, a Participant may change a
previous Revised Payout Election with a new Revised Payout Election which shall
supersede such previous election.
C. A Revised Payout Election shall not become effective
until one full calendar-tax year (Jan 1 - December 31) has expired after such
election has been received by the Committee, unless the Committee in its sole
discretion accelerates the effectiveness of such Revised Payout Election. If a
Revised Payout Election does not become effective, the previous effective
election of the Participant shall control.
6.3 Accelerated Distribution. Notwithstanding any other provision
of the Plan, subject to the consent of the Committee, a Participant may elect
to receive, on a form acceptable to the Committee, a single sum distribution of
all or a portion of the Participant's deferral accounts under the Plan, subject
to the following penalties: ten percent (10%) of the elected distribution
amount shall be forfeited and ninety percent (90%) of the elected distribution
amount shall be paid to the Participant; and the Participant shall be suspended
from participation in the Plan for thirty six (36) calendar months from the
date of such distribution. All eligibility requirements must be met to reenter
the Plan. The account balance shall be determined as of the last day of the
month preceding the date on which the Committee receives the written request of
the Participant. If approved by the Committee, the amount payable shall be
paid in a single sum within sixty (60) days following the receipt of the
participant's written request by the Plan Committee."
4. Effective January 1, 1998, Section 7.1 is deleted in its entirety and
the following is substituted therefor:
- 3 -
<PAGE> 4
"7.1 Phantom Stock Account.
A. With respect to deferral elections of a Participant
for calendar years prior to 1998, the Participant or his survivors will have a
choice at the start of the payout period as to the method of payment of the
account balance. The two methods of payment are the "PSA Method" and the
"Mid-Term Cost of Capital Method".
(1) PSA Method. Under the PSA Method, the number
of phantom shares in the account at the beginning of the payout period will be
treated as if released in equal amounts over the payout period selected. The
value of the shares, and resulting payment amount, will be based on the closing
price of Enron Oil & Gas Company common stock on the Friday before the date of
payment. Dividend equivalents will be paid annually based on the number of
phantom shares remaining in the account.
(2) Mid-Term Cost of Capital Method. Under the
Mid-Term Cost of Capital Method, the accumulated value of the shares (account
balance) at the beginning of the payout period will be paid in equal amounts
over the payout period selected. Interest on the declining balance will be
paid annually based on Enron's mid-term cost of capital, as established
annually by the Committee. If the PSA Method is chosen at the beginning of the
payout period, the Participant or his survivors may make one irrevocable
election during the payout period to change to the Mid-Term Cost of Capital
Method. The Participant cannot change from the Mid-Term Cost of Capital Method
to the PSA Method once payout has started.
Additionally, such a Participant or survivors may, subject to
the consent of the Committee, elect to receive payment of the Participant's
account balance in shares of Enron Oil & Gas Company common stock on the
condition that such election is made and is approved by the Committee before
the Participant or survivors have an unconditional right to receive payment.
B. For deferral elections of a Participant for calendar
years 1998 and thereafter, the Participant or his survivors will have no choice
as to the method of payment of the account balance. Payment of the account
balance shall be in the form of shares of Enron Oil & Gas Company common stock
according to the payout election of the Participant in effect at the time
payment of the account balance commences, provided, however, a multi-year
payout election shall be subject to adjustment as determined in guidelines
adopted by the Committee and reflected in the Participant's deferral election
agreement."
5. Section 8.1 is deleted in its entirety and the following is
substituted therefor:
"8.1 Retirement Benefit. The Account balance shall be paid as
elected by the Participant, with payments commencing by February 15 of the
calendar year following Retirement. "Retirement" means, after attainment of
age 55 with at least 5 years of service, a Participant's termination of
employment and eligibility to receive benefits under the Enron Corp. Retirement
Plan."
- 4 -
<PAGE> 5
6. Section 8.2 is deleted in its entirety and the following is
substituted therefor:
"8.2 Disability Benefit. The Account balance shall be paid as
elected by the Participant by February 15 of the calendar year following onset
of the Disability. "Disability" means a physical or mental condition of a
Participant resulting from a bodily injury or disease or mental disorder which:
a) renders a Participant incapable of continuing the further performance of his
normal employment activities with the Company and has been determined by the
Committee to be totally and permanently disabled for purposes of receiving
long-term benefits under a long-term disability plan maintained by the Company;
or b) renders a Director incapable of continuing the further performance of his
duties as a Director of the Board."
7. Section 8.3 is deleted in its entirety and the following is
substituted therefor:
"8.3 Termination Benefit. The Account balance shall be paid as
elected by the Participant in the event of termination, whether voluntary or
involuntary (except termination for cause), with payments commencing by
February 15 of the calendar year following Termination."
8. Section 8.4 is deleted in its entirety and the following is
substituted therefor:
"8.4 Termination for Cause. Upon a Participant's Termination for
Cause, the Participant shall be entitled to receive the elective deferred
compensation credited to the Account; however, no interest shall be credited to
the Account. If the termination is as the result of the Participant's fraud
against or theft from the Company, the damages sustained by the Company shall
be deducted from the amount payable under this Section 8.4. Payment shall be
made in a single sum by February 15 of the calendar year following the date of
Termination for Cause. The Participant shall have no further interest in the
Account upon such termination of service and such payment. "Termination for
Cause" shall mean termination of employment of Participant by the Company
because of (1) conviction of a felony relating to or in connection with the
Company or the Company's business; (2) willful refusal without proper legal
cause to perform duties and responsibilities of employment; or (3) willfully
engaging in conduct which the Participant has or reasonably should have reason
to know is or will be materially injurious to the Company. Such termination
shall be effected by notice thereof delivered by the Company to Participant and
shall be effective as of the date of such notice; provided, however, that if
(a) termination is because of Participant's willful refusal without proper
legal cause to perform any one or more of Participant's duties and
responsibilities and (b) within seven days following the date of such notice
Participant shall cease such refusal and shall use Participant's best efforts
to perform such duties and responsibilities, the termination shall not be
effective, and provided further, that the Company shall consult in good faith
with Participant and provide an opportunity for Participant to be heard prior
to the Company making a determination that any termination under (1), (2), or
(3) of this paragraph is Termination for Cause, and that failure to do so shall
not constitute Termination for Cause."
- 5 -
<PAGE> 6
9. The following sentence is added to the end of Article VI of the Plan:
"Notwithstanding any provision in this Article VI, or elsewhere in the
Plan, with respect to Participants who are employed in states which impose
state income tax on Plan benefits, the Committee may determine the amount,
manner and/or time of payment of benefits under the Plan, including, but no
limited to, a requirement of at least a ten-year minimum payout period for
Deferral Plan benefits."
- 6 -
<PAGE> 7
AS AMENDED HEREBY, the Plan is specifically ratified and reaffirmed.
Dated effective as of December 9, 1997.
ATTEST: ENRON OIL & GAS COMPANY
By: /s/ Angus H. Davis By: /s/ Patricia L. Edwards
------------------------------ ----------------------------
Angus H. Davis Patricia L. Edwards
Vice President, Communications Vice President, Human
and Corporate Secretary Resources
& Administration
- 7 -
<PAGE> 1
EXHIBIT 10.64
EXECUTIVE EMPLOYMENT AGREEMENT
This Employment Agreement ("Agreement"), including the attached
Exhibit "A," is entered into between Enron Oil & Gas Company., a Delaware
corporation, having offices at 1400 Smith Street, Houston, Texas 77002
("Employer"), and Mark G. Papa, an individual currently residing at 3731
Panorama, Missouri City, Texas 77459 ("Employee"), to be effective as of
November 1, 1997 (the "Effective Date").
WITNESSETH:
WHEREAS, Employer is desirous of employing Employee pursuant to the
terms and conditions and for the consideration set forth in this Agreement, and
Employee is desirous of entering the employ of Employer pursuant to such terms
and conditions and for such consideration.
NOW, THEREFORE, for and in consideration of the mutual promises,
covenants, and obligations contained herein, Employer and Employee agree as
follows:
ARTICLE 1: EMPLOYMENT AND DUTIES:
1.1 Employer agrees to employ Employee, and Employee agrees to be
employed by Employer, beginning as of the Effective Date and continuing until
the date set forth on Exhibit "A" (the "Term"), subject to the terms and
conditions of this Agreement.
1.2 Employee initially shall be employed in the position set forth
on Exhibit A, provided however, if at the earlier of four years from the
Effective Date of this Agreement or Forrest E. Hoglund vacating the position of
Chief Executive Officer of the Employer, Employee is not promoted into the
position of Chief Executive Officer, then for a period of six (6) months
following notification to Employee of such decision, Employee shall have the
option to resign and said resignation shall be treated as described in Article
3, Section 3.10. Employee agrees to serve in the assigned position and to
perform diligently and to the best of Employee's abilities the duties and
services appertaining to such position as determined by Employer, as well as
such additional or different duties and services appropriate to such position
which Employee from time to time may be reasonably directed to perform by
Employer. Employee shall at all times comply with and be subject to such
policies and procedures as Employer may establish from time to time.
1.3 Employee shall, during the period of Employee's employment by
Employer, devote Employee's full business time, energy, and best efforts to the
business and affairs of Employer. Employee may not engage, directly or
indirectly, in any other business, investment, or activity that interferes with
Employee's performance of Employee's duties hereunder, is contrary to the
interests of Employer or Enron, or requires any significant portion of
Employee's business time.
<PAGE> 2
1.4 In connection with Employee's employment by Employer, Employer
shall endeavor to provide Employee access to such confidential information
pertaining to the business and services of Employer as is appropriate for
Employee's employment responsibilities. Employer also shall endeavor to
provide to Employee the opportunity to develop business relationships with
those of Employer's clients and potential clients that are appropriate for
Employee's employment responsibilities.
1.5 Employee acknowledges and agrees that, at all times during the
employment relationship Employee owes fiduciary duties to Employer, including
but not limited to the fiduciary duties of the highest loyalty, fidelity and
allegiance to act at all times in the best interests of the Employer, to make
full disclosure to Employer of all information that pertains to Employer's
business and interests, to do no act which would injure Employer's business,
its interests, or its reputation, and to refrain from using for Employee's own
benefit or for the benefit of others any information or opportunities
pertaining to Employer's business or interests that are entrusted to Employee
or that he learned while employed by Employer. Employee acknowledges and
agrees that upon termination of the employment relationship, Employee shall
continue to refrain from using for his own benefit or the benefit of others any
information or opportunities pertaining to Employer's business or interests
that were entrusted to Employee during the employment relationship or that he
learned while employed by Employer. Employee agrees that while employed by
Employer and thereafter he shall not knowingly take any action which interferes
with the internal relationships between Employer and its employees or
representatives or interferes with the external relationships between Employer
and third parties.
1.6 It is agreed that any direct or indirect interest in,
connection with, or benefit from any outside activities, particularly
commercial activities, which interest might in any way adversely affect
Employer or any of its affiliates, involves a possible conflict of interest.
In keeping with Employee's fiduciary duties to Employer, Employee agrees that
during the employment relationship Employee shall not knowingly become involved
in a conflict of interest with Employer or its affiliates, or upon discovery
thereof, allow such a conflict to continue. Moreover, Employee agrees that
Employee shall disclose to Employer's Chairman any facts which might involve
such a conflict of interest that has not been approved by Employer's Chairman.
Employer and Employee recognize that it is impossible to provide an exhaustive
list of actions or interests which constitute a "conflict of interest."
Moreover, Employer and Employee recognize there are many borderline situations.
In some instances, full disclosure of facts by the Employee to Employer's
Chairman may be all that is necessary to enable Employer or its affiliates to
protect its interests. In others, if no improper motivation appears to exist
and the interests of Employer or its affiliates have not suffered, prompt
elimination of the outside interest will suffice. In still others, it may be
necessary for Employer to terminate the employment relationship. Employer and
Employee agree that Employer's determination as to whether a conflict of
interest exists shall be conclusive. Employer reserves the right to take such
action as, in its judgment, will end the conflict.
ARTICLE 2: COMPENSATION AND BENEFITS:
2.1 Employee's monthly base salary during the Term shall be not
less than the amount set forth under the heading "Monthly Base Salary" on
Exhibit A, subject to increase at the sole discretion of the Employer, which
shall be paid in semimonthly installments in accordance with
<PAGE> 3
Employer's standard payroll practice. Any calculation to be made under this
Agreement with respect to Employee's Monthly Base Salary shall be made using
the then current Monthly Base Salary in effect at the time of the event for
which such calculation is made.
2.2 While employed by Employer (both during the Term and
thereafter), Employee shall be allowed to participate, on the same basis
generally as other employees of Employer, in all general employee benefit plans
and programs, including improvements or modifications of the same, which on the
effective date or thereafter are made available by Employer to all or
substantially all of Employer's employees. Such benefits, plans, and programs
may include, without limitation, medical, health, and dental care, life
insurance, disability protection, and pension plans. Nothing in this Agreement
is to be construed or interpreted to provide greater rights, participation,
coverage, or benefits under such benefit plans or programs than provided to
similarly situated employees pursuant to the terms and conditions of such
benefit plans and programs.
2.3 Employer shall not by reason of this Article 2 be obligated to
institute, maintain, or refrain from changing, amending, or discontinuing, any
such incentive compensation or employee benefit program or plan, so long as
such actions are similarly applicable to covered employees generally.
Moreover, unless specifically provided for in a written plan document adopted
by the Board of Directors of either Employer or Enron, none of the benefits or
arrangements described in this Article 2 shall be secured or funded in any way,
and each shall instead constitute an unfunded and unsecured promise to pay
money in the future exclusively from the general assets of Employer.
2.4 Employer may withhold from any compensation, benefits, or
amounts payable under this Agreement all federal, state, city, or other taxes
as may be required pursuant to any law or governmental regulation or ruling.
ARTICLE 3: TERMINATION PRIOR TO EXPIRATION OF TERM AND EFFECTS OF SUCH
TERMINATION:
3.1 Notwithstanding any other provisions of this Agreement,
Employer shall have the right to terminate Employee's employment under this
Agreement at any time prior to the expiration of the Term for any of the
following reasons:
(i) For "cause" upon the good faith determination by the
Employer's management committee (or, if there is no management
committee, the highest applicable level of management) of
Employer that "cause" exists for the termination of the
employment relationship. As used in this Section 3.1(i), the
term "cause" shall mean [a] Employee's gross negligence or
willful misconduct in the performance of the duties and
services required of Employee pursuant to this Agreement; or
[b] Employee's final conviction of a felony or of a
misdemeanor involving moral turpitude; [c] Employee's
involvement in a conflict of interest as referenced in
Sections 1.5-1.6 for which Employer makes a determination to
terminate the employment of Employee; or [d] Employee's
material breach of any material
<PAGE> 4
provision of this Agreement which remains uncorrected for
thirty (30) days following written notice to Employee by
Employer of such breach. It is expressly acknowledged and
agreed that the decision as to whether "cause" exists for
termination of the employment relationship by Employer is
delegated to the management committee (or, if there is no
management committee, the highest applicable level of
management) of Employer for determination. If Employee
disagrees with the decision reached by Employer, the dispute
will be limited to whether the management committee (or, if
there is no management committee, the highest applicable level
of management) of Employer reached its decision in good faith;
(ii) for any other reason whatsoever, with or without cause, in the
sole discretion of the management committee (or, if there is
no management committee, the highest applicable level of
management) of Employer;
(iii) upon Employee's death; or
(iv) upon Employee's becoming disabled so as to entitle Employee to
benefits under Enron's long-term disability plan or, if
Employee is not eligible to participate in such plan, then
Employee is permanently and totally unable to perform
Employee's duties for Employer as a result of any medically
determinable physical or mental impairment as supported by a
written medical opinion to the foregoing effect by a physician
selected by Employer.
The termination of Employee's employment by Employer prior to the expiration of
the Term shall constitute a "Termination for Cause" if made pursuant to Section
3.1(i); the effect of such termination is specified in Section 3.4. The
termination of Employee's employment by Employer prior to the expiration of the
Term shall constitute an "Involuntary Termination" if made pursuant to Section
3.1(ii); the effect of such termination is specified in Section 3.5. The
effect of the employment relationship being terminated pursuant to Section
3.1(iii) as a result of Employee's death is specified in Section 3.6. The
effect of the employment relationship being terminated pursuant to Section
3.1(iv) as a result of the Employee becoming incapacitated is specified in
Section 3.7.
3.2 Notwithstanding any other provisions of this Agreement except
Section 7.5, Employee shall have the right to terminate the employment
relationship under this Agreement at any time prior to the expiration of the
Term of employment for any of the following reasons:
(i) a material breach by Employer of any material provision of
this Agreement which remains uncorrected for 30 days following
written notice of such breach by Employee to Employer; or
(ii) for any other reason whatsoever, in the sole discretion of
Employee.
The termination of Employee's employment by Employee prior to the expiration of
the Term shall constitute an "Involuntary Termination" if made pursuant to
Section 3.2(i); the effect of such
<PAGE> 5
termination is specified in Section 3.5. The termination of Employee's
employment by Employee prior to the expiration of the Term shall constitute a
"Voluntary Termination" if made pursuant to Section 3.2(ii); the effect of such
termination is specified in Section 3.3.
3.3 Upon a "Voluntary Termination" of the employment relationship
by Employee prior to expiration of the Term, all future compensation to which
Employee is entitled and all future benefits for which Employee is eligible
shall cease and terminate as of the date of termination. Employee shall be
entitled to pro rata salary through the date of such termination, but Employee
shall not be entitled to any individual bonuses or individual incentive
compensation not yet paid at the date of such termination.
3.4 If Employee's employment hereunder shall be terminated by
Employer for Cause prior to expiration of the Term, all future compensation to
which Employee is entitled and all future benefits for which Employee is
eligible shall cease and terminate as of the date of termination. Employee
shall be entitled to pro rata salary through the date of such termination, but
Employee shall not be entitled to any individual bonuses or individual
incentive compensation not yet paid at the date of such termination.
3.5 Upon an Involuntary Termination of the employment relationship
by either Employer or Employee prior to the expiration of the Term, Employee
shall be entitled, in consideration of Employee's continuing obligations
hereunder after such termination (including, without limitation, Employee's
non-competition obligations), to receive the then current Monthly Base Salary
as if Employee's employment (which shall cease on the date of such Involuntary
Termination) had continued for the full Term of this Agreement. Employee shall
not be under any duty or obligation to seek or accept other employment
following Involuntary Termination and the amounts due Employee hereunder shall
not be reduced or suspended if Employee accepts subsequent employment.
Employee's rights under this Section 3.5 are Employee's sole and exclusive
rights against Employer, Enron, or their affiliates, and Employer's sole and
exclusive liability to Employee under this Agreement, in contract, tort, or
otherwise, for any Involuntary Termination of the employment relationship.
Employee covenants not to sue or lodge any claim, demand or cause of action
against Employer for any sums for Involuntary Termination other than those sums
specified in this Section 3.5. If Employee breaches this covenant, Employer
shall be entitled to recover from Employee all sums expended by Employer
(including costs and attorneys fees) in connection with such suit, claim,
demand or cause of action.
3.6 Upon termination of the employment relationship as a result of
Employee's death, Employee's heirs, administrators, or legatees shall be
entitled to Employee's pro rata salary through the date of such termination,
but Employee's heirs, administrators, or legatees shall not be entitled to any
individual bonuses or individual incentive compensation not yet paid to
Employee at the date of such termination.
3.7 Upon termination of the employment relationship as a result of
Employee's incapacity, Employee shall be entitled to his or her pro rata salary
through the date of such termination, but Employee shall not be entitled to any
individual bonuses or individual incentive compensation not yet paid to
Employee at the date of such termination.
<PAGE> 6
3.8 In all cases, the compensation and benefits payable to
Employee under this Agreement upon termination of the employment relationship
shall be offset against any amounts to which Employee may otherwise be entitled
under any and all severance plans, and policies of Employer, Enron, or its
affiliates.
3.9 Termination of the employment relationship does not terminate
those obligations imposed by this Agreement which are continuing obligations,
including, without limitation, Employee's obligations under Articles 5 and 6.
3.10 In the event of Employee's termination as a result of
Employer's failure to promote Employee into the position of Chief Executive
Officer upon the earlier of four years from the Effective Date of this
Agreement or the departure of Forrest E. Hoglund from the position of Chief
Executive Officer of Employer, for a period of six (6) months following
notification to Employee of such decision, Employee shall have the option to
resign and receive the following:
a) one year's annual base salary;
b) immediate vesting of all unvested options and
treatment as involuntary termination;
c) immediate vesting and release of all unvested
restricted stock;
d) treatment under the 1985 Enron Corp. Deferral Plan as
an Involuntary termination; and
e) the non-competition obligations described at Section
6.1 (i) and (ii) shall be waived by Employer and
Employee agrees that the non-competition obligations
described at Section 6.1(iii) shall extend for a
period of two years after the date of termination.
ARTICLE 4: CONTINUATION OF EMPLOYMENT BEYOND TERM; TERMINATION AND
EFFECTS OF TERMINATION:
4.1 Should Employee remain employed by Employer beyond the
expiration of the Term specified on Exhibit "A," such employment shall convert
to a month-to-month relationship terminable at any time by either Employer or
Employee for any reason whatsoever, with or without cause. Upon such
termination of the employment relationship by either Employer or Employee for
any reason whatsoever, all future compensation to which Employee is entitled
and all future benefits for which Employee is eligible shall cease and
terminate. Employee shall be entitled to pro rata salary through the date of
such termination, but Employee shall not be entitled to any individual bonuses
or individual incentive compensation not yet paid at the date of such
termination.
<PAGE> 7
ARTICLE 5: OWNERSHIP AND PROTECTION OF INFORMATION; COPYRIGHTS:
5.1 All information, ideas, concepts, improvements, discoveries,
and inventions, whether patentable or not, which are conceived, made, developed
or acquired by Employee, individually or in conjunction with others, during
Employee's employment by Employer (whether during business hours or otherwise
and whether on Employer's premises or otherwise) which relate to Employer's
business, products or services (including, without limitation, all such
information relating to corporate opportunities, research, financial and sales
data, pricing and trading terms, evaluations, opinions, interpretations,
acquisition prospects, the identity of customers or their requirements, the
identity of key contacts within the customer's organizations or within the
organization of acquisition prospects, or marketing and merchandising
techniques, prospective names, and marks) shall be disclosed to Employer and
are and shall be the sole and exclusive property of Employer. Moreover, all
drawings, memoranda, notes, records, files, correspondence, drawings, manuals,
models, specifications, computer programs, maps and all other writings or
materials of any type embodying any of such information, ideas, concepts,
improvements, discoveries, and inventions are and shall be the sole and
exclusive property of Employer.
5.2 Employee acknowledges that the business of Employer, Enron,
and their affiliates is highly competitive and that their strategies, methods,
books, records, and documents, their technical information concerning their
products, equipment, services, and processes, procurement procedures and
pricing techniques, the names of and other information (such as credit and
financial data) concerning their customers and business affiliates, all
comprise confidential business information and trade secrets which are
valuable, special, and unique assets which Employer, Enron, or their affiliates
use in their business to obtain a competitive advantage over their competitors.
Employee further acknowledges that protection of such confidential business
information and trade secrets against unauthorized disclosure and use is of
critical importance to Employer, Enron, and their affiliates in maintaining
their competitive position. Employee hereby agrees that Employee will not, at
any time during or after his or her employment by Employer, make any
unauthorized disclosure of any confidential business information or trade
secrets of Employer, Enron, or their affiliates, or make any use thereof,
except in the carrying out of his or her employment responsibilities hereunder.
Enron and its affiliates shall be third party beneficiaries of Employee's
obligations under this Section. As a result of Employee's employment by
Employer, Employee may also from time to time have access to, or knowledge of,
confidential business information or trade secrets of third parties, such as
customers, suppliers, partners, joint venturers, and the like, of Employer,
Enron, and their affiliates. Employee also agrees to preserve and protect the
confidentiality of such third party confidential information and trade secrets
to the same extent, and on the same basis, as Employer's confidential business
information and trade secrets. Employee acknowledges that money damages would
not be sufficient remedy for any breach of this Article 5 by Employee, and
Employer shall be entitled to enforce the provisions of this Article 5 by
terminating any payments then owing to Employee under this Agreement and/or to
specific performance and injunctive relief as remedies for such breach or any
threatened breach. Such remedies shall not be deemed the exclusive remedies
for a breach of this Article 5, but shall be in addition to all remedies
available at law or in equity to
<PAGE> 8
Employer, including the recovery of damages from Employee and his or her agents
involved in such breach.
5.3 All written materials, records, and other documents made by,
or coming into the possession of, Employee during the period of Employee's
employment by Employer which contain or disclose confidential business
information or trade secrets of Employer, Enron, or their affiliates shall be
and remain the property of Employer, Enron, or their affiliates, as the case
may be. Upon termination of Employee's employment by Employer, for any reason,
Employee promptly shall deliver the same, and all copies thereof, to Employer.
5.4 If, during Employee's employment by Employer, Employee creates
any original work of authorship fixed in any tangible medium of expression
which is the subject matter of copyright (such as videotapes, written
presentations on acquisitions, computer programs, drawings, maps, architectural
renditions, models, manuals, brochures, or the like) relating to Employer's
business, products, or services, whether such work is created solely by
Employee or jointly with others (whether during business hours or otherwise and
whether on Employer's premises or otherwise), Employee shall disclose such work
to Employer. Employer shall be deemed the author of such work if the work is
prepared by Employee in the scope of his or her employment; or, if the work is
not prepared by Employee within the scope of his or her employment but is
specially ordered by Employer as a contribution to a collective work, as a part
of a motion picture or other audiovisual work, as a translation, as a
supplementary work, as a compilation, or as an instructional text, then the
work shall be considered to be work made for hire and Employer shall be the
author of the work. If such work is neither prepared by the Employee within
the scope of his or her employment nor a work specially ordered and is deemed
to be a work made for hire, then Employee hereby agrees to assign, and by these
presents does assign, to Employer all of Employee's worldwide right, title, and
interest in and to such work and all rights of copyright therein.
5.5 Both during the period of Employee's employment by Employer
and thereafter, Employee shall assist Employer and its nominee, at any time, in
the protection of Employer's worldwide right, title, and interest in and to
information, ideas, concepts, improvements, discoveries, and inventions, and
its copyrighted works, including without limitation, the execution of all
formal assignment documents requested by Employer or its nominee and the
execution of all lawful oaths and applications for applications for patents and
registration of copyright in the United States and foreign countries.
ARTICLE 6: POST-EMPLOYMENT NON-COMPETITION OBLIGATIONS:
6.1 As part of the consideration for the compensation and benefits
to be paid to Employee hereunder, in keeping with Employee's duties as a
fiduciary and in order to protect Employer's interests in the confidential
information of Employer and the business relationships developed by Employee
with the clients and potential clients of Employer, and as an additional
incentive for Employer to enter into this Agreement, Employer and Employee
agree to the non-competition provisions of this Article 6. Employee agrees
that during the period of Employee's non-competition obligations hereunder,
Employee will not, directly or indirectly for Employee or
<PAGE> 9
for others, in any geographic area or market where Employer or Enron or any of
their affiliated companies are conducting any business as of the date of
termination of the employment relationship or have during the previous twelve
months conducted any business:
(i) engage in any business competitive with the business conducted
by Employer;
(ii) render advice or services to, or otherwise assist, any other
person, association, or entity who is engaged, directly or indirectly, in any
business competitive with the business conducted by Employer;
(iii) induce any employee of Employer or Enron or any of their
affiliates to terminate his or her employment with Employer, Enron, or their
affiliates, or hire or assist in the hiring of any such employee by person,
association, or entity not affiliated with Enron.
These non-competition obligations shall extend until the earlier of (a)
expiration of the Term, or (b) one year after the termination of the employment
relationship unless the termination is a Voluntary Termination as defined at
Section 3.2 (ii). In the event of a Voluntary Termination, these
non-competition obligations shall extend for a period of one (1) year after
Employee's Voluntary Termination.
6.2 Employee understands that the foregoing restrictions may limit
his or her ability to engage in certain businesses anywhere in the world during
the period provided for above, but acknowledges that Employee will receive
sufficiently high remuneration and other benefits (e.g., the right to receive
compensation under Section 3.5 for the remainder of the Term upon Involuntary
Termination) under this Agreement to justify such restriction. Employee
acknowledges that money damages would not be sufficient remedy for any breach
of this Article 6 by Employee, and Employer shall be entitled to enforce the
provisions of this Article 6 by terminating any payments then owing to Employee
under this Agreement and/or to specific performance and injunctive relief as
remedies for such breach or any threatened breach. Such remedies shall not be
deemed the exclusive remedies for a breach of this Article 6, but shall be in
addition to all remedies available at law or in equity to Employer, including,
without limitation, the recovery of damages from Employee and his or her agents
involved in such breach.
6.3 It is expressly understood and agreed that Employer and
Employee consider the restrictions contained in this Article 6 to be reasonable
and necessary to protect the proprietary information of Employer.
Nevertheless, if any of the aforesaid restrictions are found by a court having
jurisdiction to be unreasonable, or overly broad as to geographic area or time,
or otherwise unenforceable, the parties intend for the restrictions therein set
forth to be modified by such courts so as to be reasonable and enforceable and,
as so modified by the court, to be fully enforced.
ARTICLE 7: MISCELLANEOUS:
7.1 For purposes of this Agreement the terms "affiliates" or
"affiliated" means an entity who directly, or indirectly through one or more
intermediaries, controls, is controlled by,
<PAGE> 10
or is under common control with Enron or Employer. In the event Employer has
not adopted a Change of Control Severance Plan, and if during the Term of this
Agreement Enron Corp. elects to sell its interest in Employer such that
Employer ceases to be an affiliate of Enron Corp., Employee shall be entitled
to benefits identical to those described in the Enron Corp. Change of Control
Severance Plan.
7.2 For purposes of this Agreement, notices and all other
communications provided for herein shall be in writing and shall be deemed to
have been duly given when personally delivered or when mailed by United States
registered or certified mail, return receipt requested, postage prepaid,
addressed as follows:
If to Employer, to:
Enron Oil & Gas Company
1400 Smith Street
Houston, Texas 77002
Attention: Corporate Secretary
If to Employee, to the address shown on the first page hereof.
Either Employer or Employee may furnish a change of address to the other in
writing in accordance herewith, except that notices of changes of address shall
be effective only upon receipt.
7.3 This Agreement shall be governed in all respects by the laws
of the State of Texas, excluding any conflict-of-law rule or principle that
might refer the construction of the Agreement to the laws of another State or
country.
7.4 No failure by either party hereto at any time to give notice
of any breach by the other party of, or to require compliance with, any
condition or provision of this Agreement shall be deemed a waiver of similar or
dissimilar provisions or conditions at the same or at any prior or subsequent
time.
7.5 If a dispute arises out of or related to this Agreement, other
than a dispute regarding Employee's obligations under Sections 5.2, Article 5,
or Section 6.1, and if the dispute cannot be settled through direct
discussions, then Employer and Employee agree to first endeavor to settle the
dispute in an amicable manner by mediation, before having recourse to any other
proceeding or forum. Thereafter, if either party to this Agreement brings
legal action to enforce the terms of this Agreement, the party who prevails in
such legal action, whether plaintiff or defendant, in addition to the remedy or
relief obtained in such legal action shall be entitled to recover its, his, or
her expenses incurred in connection with such legal action, including, without
limitation, costs of Court and attorneys fees.
7.6 It is a desire and intent of the parties that the terms,
provisions, covenants, and remedies contained in this Agreement shall be
enforceable to the fullest extent permitted by law. If any such term,
provision, covenant, or remedy of this Agreement or the application thereof to
<PAGE> 11
any person, association, or entity or circumstances shall, to any extent, be
construed to be invalid or unenforceable in whole or in part, then such term,
provision, covenant, or remedy shall be construed in a manner so as to permit
its enforceability under the applicable law to the fullest extent permitted by
law. In any case, the remaining provisions of this Agreement or the
application thereof to any person, association, or entity or circumstances
other than those to which they have been held invalid or unenforceable, shall
remain in full force and effect.
7.7 This Agreement shall be binding upon and inure to the benefit
of Employer and any other person, association, or entity which may hereafter
acquire or succeed to all or substantially all of the business or assets of
Employer by any means whether direct or indirect, by purchase, merger,
consolidation, or otherwise. Employee's rights and obligations under Agreement
hereof are personal and such rights, benefits, and obligations of Employee
shall not be voluntarily or involuntarily assigned, alienated, or transferred,
whether by operation of law or otherwise, without the prior written consent of
Employer.
7.8 There exist other agreements between Employer and Employee
relating to the employment relationship between them, e.g., the agreement with
respect to company policies contained in Employer's Conduct of Business Affairs
booklet and agreements with respect to benefit plans. This Agreement replaces
and merges previous agreements and discussions pertaining to the following
subject matters covered herein: the nature of Employee's employment
relationship with Employer and the term and termination of such relationship.
This Agreement constitutes the entire agreement of the parties with regard to
such subject matters, and contains all of the covenants, promises,
representations, warranties, and agreements between the parties with respect
such subject matters. Each party to this Agreement acknowledges that no
representation, inducement, promise, or agreement, oral or written, has been
made by either party with respect to such subject matters, which is not
embodied herein, and that no agreement, statement, or promise relating to the
employment of Employee by Employer that is not contained in this Agreement
shall be valid or binding. Any modification of this Agreement will be
effective only if it is in writing and signed by each party whose rights
hereunder are affected thereby, provided that any such modification must be
authorized or approved by the Board of Directors of Employer.
<PAGE> 12
IN WITNESS WHEREOF, Employer and Employee have duly executed this
Agreement in multiple originals to be effective on the date first stated above.
ENRON OIL & GAS COMPANY
By: /s/ Patricia Edwards
----------------------------
Name: Patricia Edwards
Title: VP Human Resources & Admin.
----------------------------
This 14th day of January, 1998
MARK G. PAPA
/s/ Mark G. Papa
------------------------------------
This 14th day of January, 1998
<PAGE> 13
EXHIBIT "A" TO
EXECUTIVE EMPLOYMENT AGREEMENT
BETWEEN ENRON OIL & GAS COMPANY AND MARK G. PAPA
Employee Name: Mark G. Papa
Term: November 1, 1997 through October 31, 2001
Position: President and Chief Operating Officer
Location: Houston, Texas
Reporting Relationship: Reports to Forrest E. Hoglund, Chairman and
Chief Executive Officer
Monthly Base Salary: Thirty Three Thousand Three Hundred Thirty
Three and 33/100 Dollars ($33,333.33) per
month
Bonus: Employee shall be eligible to participate in
the Enron Oil & Gas Company Annual Incentive
Plan ("Plan"). All bonuses shall be paid in
accordance with the terms and provisions of
the Plan, and may be paid in a combination
of cash, stock options, and/or phantom stock
units, as determined by the Compensation
Committee of Employer's Board of Directors.
ENRON OIL & GAS COMPANY
By: /s/ Patricia Edwards
------------------------------
Name: Patricia Edwards
Title: VP Human Resources & Admin.
---------------------------
This 14th day of January, 1998
MARK G. PAPA
/s/ Mark G. Papa
----------------------------------
This 14th day of January, 1998
<PAGE> 1
ENRON OIL & GAS COMPANY
LIST OF SUBSIDIARIES EXHIBIT 21
<TABLE>
<CAPTION>
DATE OF WHERE
COMPANY NAME INCORPORATION INCORPORATED
- ------------------------------------------------------------------------------- --------------- -------------------
<S> <C> <C>
INTERNATIONAL SUBSIDIARIES:
Enron Oil & Gas Company 06/12/85 Delaware
Enron Oil & Gas International, Inc. 05/27/93 Delaware
EOGI-Trinidad, Inc. 06/02/93 Delaware
EOGI Trinidad Company 06/02/93 Cayman Islands
Enron Gas & Oil Trinidad Limited 11/04/92 Trinidad
Enron Oil & Gas Capital Management I, Ltd. 12/08/95 Cayman Islands
Wilsyx International Finance B.V. 09/27/96 The Netherlands
EOGI Company of Trinidad 03/14/97 Cayman Islands
Harfin Capital and Finance Ltd. 07/24/97 Cayman Islands
OCC Investment Company Ltd. 10/27/97 Cayman Islands
EOGI - Trinidad U(a) Block, Inc. 11/07/95 Delaware
EOGI Trinidad - U(a) Block Company 11/09/95 Cayman Islands
Enron Gas & Oil Trinidad - U(a) Block Limited 11/10/95 Cayman Islands
EOGI-Australia, Inc. 06/02/93 Delaware
EOGI-France, Inc. 06/02/93 Delaware
Enron Exploration France S.A. 11/13/92 France
EOGI-Kazakhstan, Inc. 07/29/93 Delaware
Enron Oil & Gas Kazakhstan Ltd. 08/18/94 Cayman Islands
EOGI-United Kingdom, Inc. 07/29/93 Delaware
EOGI United Kingdom Company B.V. 12/04/81 The Netherlands
Enron Oil UK Limited 05/22/90 England
EOGI-India, Inc. 03/17/94 Delaware
Enron Oil & Gas India Ltd. 06/02/93 Cayman Islands
EOGI-China, Inc. 08/18/94 Delaware
Enron Oil & Gas China International Ltd. 05/07/97 Cayman Islands
EOGI-Qatar, Inc. 09/22/94 Delaware
Enron Oil & Gas Qatar Ltd. 09/23/94 Cayman Islands
EOGI-Uzbekistan, Inc. 01/30/95 Delaware
Enron Oil & Gas Uzbekistan Ltd. 01/31/95 Cayman Islands
EOGI - Kuwait, Inc. 04/11/95 Delaware
Enron Oil & Gas Kuwait Ltd. 04/12/95 Cayman Islands
EOGI - Algeria, Inc. 11/07/95 Delaware
Enron Oil & Gas Algeria Ltd. 11/09/95 Cayman Islands
Enron Oil & Gas Jordan Ltd. 12/08/95 Cayman Islands
EOGI - Venezuela, Inc. 06/17/96 Delaware
EOGI Venezuela Company 06/20/96 Cayman Islands
Gulf of Paria East Operating Company 06/21/96 Cayman Islands
Enron Oil & Gas Venezuela Ltd. 01/11/96 Cayman Islands
Administradora del Golfo de Paria Este, S.A. 08/07/96 Venezuela
EOG Venezuela III Ltd. 05/29/97 Cayman Islands
EOGI Venezuela (Guarico), Inc. 05/15/96 Delaware
Enron Oil & Gas Venezuela - Guarico Ltd. 04/03/96 Cayman Islands
EOGI - China (Sichuan), Inc. 05/07/96 Delaware
Enron Oil & Gas China Ltd. 05/08/96 Cayman Islands
EOGI - Mozambique, Inc. 05/15/96 Delaware
Enron Oil & Gas Mozambique Ltd. 05/16/96 Cayman Islands
Enron Oil & Gas Bangladesh Ltd. 06/27/97 Cayman Islands
</TABLE>
Page 1 of 2
<PAGE> 2
<TABLE>
<CAPTION>
DATE OF WHERE
COMPANY NAME INCORPORATION INCORPORATED
- ------------------------------------------------------------------------------- --------------- -------------------
<S> <C> <C>
DOMESTIC SUBSIDIARIES:
Enron Oil & Gas Company 06/12/85 Delaware
Enron Oil & Gas - Carthage, Inc. 03/21/95 Delaware
ERSO, Inc. 04/24/67 Texas
Enron Oil & Gas Property Management, Inc. 04/20/95 Delaware
Enron Oil & Gas Investments, Inc. 04/24/95 Delaware
Enron Oil & Gas Acquisitions L.P. 04/24/95 Delaware
EOG Expat Services, Inc. 02/01/96 Delaware
Enron Oil & Gas Marketing, Inc. 04/09/90 Delaware
EOG - Canada, Inc. 03/13/85 Delaware
EOG Company of Canada 12/14/95 Nova Scotia
EOG Canada Company Ltd. 12/12/95 Alberta
Enron Oil Canada Ltd. 04/01/82 Alberta
Nilo Operating Company 04/04/94 Delaware
Enron Oil & Gas - Callaghan, Inc. 04/11/97 Delaware
</TABLE>
Page 2 of 2
<PAGE> 1
EXHIBIT 23.1
[DEGOLYER AND MACNAUGHTON LETTERHEAD]
March 12, 1998
Enron Oil & Gas Company
1400 Smith Street
Houston, Texas 77002
Gentlemen:
We hereby consent to the references to our firm and to the opinions
delivered to Enron Oil & Gas Company (the Company) regarding our comparison of
estimates prepared by us with those furnished to us by the Company of the
proved oil, condensate, natural gas liquids, and natural gas reserves of
certain selected properties owned by the Company. The opinions are contained in
our letter reports dated January 22, 1996, January 17, 1997, and January 13,
1998, for estimates as of December 31, 1995, December 31, 1996, and December
31, 1997, respectively. The opinions are referred to in the section
"Supplemental Information to Consolidated Financial Statements--Oil and Gas
Producing Activities" in the Company's Annual Report on Form 10-K for the year
ended December 31, 1997, to be filed with the Securities and Exchange
Commission on or about March 13, 1998. DeGolyer and MacNaughton also consents
to the inclusion of our letter report, dated January 13, 1998, addressed to the
Company as Exhibit (23.2) to the Company's Annual Report on Form 10-K for the
year ended December 31, 1997, to be filed with the Securities and Exchange
Commission. Additionally, we hereby consent to the incorporation by reference
of such references to our firm and to our opinions included in the Company's
Form 10-K in the Company's previously filed Registration Statement nos.
33-42620, 33-48358, 33-52201, 33-58103, 33-62005, 33-64055, 333-09919,
333-20841, 333-18511, 333-31715, and 333-44785.
Very truly yours,
/s/ DEGOLYER and MACNAUGHTON
----------------------------
DeGOLYER and MacNAUGHTON
<PAGE> 1
EXHIBIT 23.2
[DEGOLYER AND MACNAUGHTON LETTERHEAD]
January 13, 1998
Enron Oil & Gas Company
1400 Smith Street
Houston, Texas 77002
Gentlemen:
Pursuant to your request, we have prepared estimates, as of December
31, 1997, of the proved oil, condensate, natural gas liquids, and natural gas
reserves of certain selected properties in the United States, Canada, and
Trinidad owned by Enron Oil & Gas Company (Enron). The properties consist of
working interests located in California, New Mexico, Texas, Utah, and Wyoming
and in the offshore waters of Texas, Louisiana, and Alabama, in Saskatchewan,
Canada, and in the offshore waters of Trinidad. The estimates are reported in
detail in our "Report as of December 31, 1997, on Proved Reserves of Certain
Properties in the United States owned by Enron Oil & Gas Company - Selected
Properties," our "Report as of December 31, 1997, on Proved Reserves of Certain
Properties in Canada owned by Enron Oil & Gas Company - Selected Properties,"
and our "Report as of December 31, 1997, on Proved Reserves of the Kiskadee
Field, Offshore Trinidad for Enron Oil and Gas Company," hereinafter
collectively referred to as the "Reports." We also have reviewed information
provided to us by Enron that it represents to be Enron's estimates of the
reserves, as of December 31, 1997, for the same properties as those included in
the Reports.
Proved reserves estimated by us and referred to herein are judged to
be economically producible in future years from known reservoirs under existing
economic and operating conditions and assuming continuation of current
regulatory practices using conventional production methods and equipment.
Proved reserves are defined as those that have been proved to a high degree of
certainty by reason of actual completion, successful testing, or in certain
cases by adequate core analyses and electrical-log interpretation when the
producing characteristics of the formation are known from nearby fields. These
reserves are defined areally by reasonable geological interpretation of
structure and known continuity of oil- or gas-saturated material. This
definition is in agreement with the definition of proved reserves prescribed by
the Securities and Exchange Commission.
<PAGE> 2
Enron represents that its estimates of the proved reserves, as of
December 31, 1997, net to its leasehold interests in the properties included in
the Reports are as follows, expressed in thousands of barrels (Mbbl) or
millions of cubic feet (MMcf):
Oil, Condensate, and Net
Natural Gas Liquids Natural Gas Equivalent
(Mbbl) (MMcf) (MMcf)
- ------------------------ -------------- ---------------
29,694 1,593,114 1,771,278
Enron has advised us, and we have assumed, that its estimates of
proved oil, condensate, natural gas liquids, and natural gas reserves are in
accordance with the rules and regulations of the Securities and Exchange
Commission.
Proved reserves estimated by us for the properties included in the
Reports, as of December 31, 1997, are as follows, expressed in thousands (Mbbl)
or millions of cubic feet (Mmcf):
Oil, Condensate, and Natural Net
Natural Gas Liquids Gas Equivalent
(Mbbl) (MMcf) (MMcf)
- ------------------------ -------------- ---------------
29,733 1,577,185 1,755,583
In making a comparison of the detailed reserves estimates prepared by
us and by Enron of the properties involved, we have found differences, both
positive and negative, in reserves estimates for individual properties. These
differences appear to be compensating to a great extent when considering the
reserves of Enron in the properties included in our reports, resulting in
overall differences not being substantial. It is our opinion that the reserves
estimates prepared by Enron on the properties reviewed by us and referred to
above, when compared on the basis of net equivalent million cubic feet of gas,
do not differ materially from those prepared by us.
Submitted,
DeGOLYER and MacNAUGHTON
<PAGE> 1
EXHIBIT 23.3
CONSENT OF INDEPENDENT PUBLIC ACCOUNTANTS
As independent public accountants, we hereby consent to the incorporation of
our report included in this Form 10-K, into Enron Oil & Gas Company and
subsidiaries' previously filed Registration Statement File Nos. 33-42620,
33-48358, 33-52201, 33-58103, 33-62005, 33-64055, 333-09919, 333-20841,
333-18511, 333-31715 and 333-44785.
ARTHUR ANDERSEN LLP
Houston, Texas
March 13, 1998
<PAGE> 1
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ Fred C. Ackman
------------------------------
Fred C. Ackman
<PAGE> 2
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ Kenneth L. Lay
-----------------------------------
Kenneth L. Lay
<PAGE> 3
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ Edward Randall, III
-------------------------------
Edward Randall, III
<PAGE> 4
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ Ken L. Harrison
----------------------------------
Ken L. Harrison
<PAGE> 5
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ Frank G. Wisner
-----------------------------
Frank G. Wisner
<PAGE> 6
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ Jeffrey K. Skilling
-------------------------------
Jeffrey K. Skilling
<PAGE> 7
EXHIBIT 24
POWER OF ATTORNEY
KNOW ALL MEN BY THESE PRESENTS:
The undersigned, as a director of Enron Oil & Gas Company, a Delaware
corporation (the "Company"), in connection with the filing by the Company of its
Annual Report on Form 10-K for the year ended December 31, 1997, with the
Securities and Exchange Commission, does hereby make, constitute and appoint
Forrest E. Hoglund, Walter C. Wilson and Angus H. Davis, each of them with full
power (any one of them acting alone), as true and lawful attorneys-in-fact and
agents, for and on behalf and in the name, place and stead of the undersigned,
in any and all capacities, to sign, execute and file such Annual Report on Form
10-K, together with any amendments or supplements thereto, with all exhibits and
any and all documents required to be filed with respect thereto with any
regulatory authority, granting unto each above-mentioned individual the full
power and authority to do and perform each and every act and action requisite
and necessary to be done in and about the premises in order to effectuate the
same as fully to all intents and purposes as the undersigned might or could do
if personally present, hereby ratifying and confirming all the said
attorneys-in-fact and agents, or any of them, may lawfully do or cause to be
done by virtue hereof.
IN WITNESS WHEREOF, the undersigned has hereto set his hand this 11th
day of February, 1998.
/s/ James V. Derrick, Jr.
---------------------------------
James V. Derrick, Jr.
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