UTI ENERGY CORP, 10-K, 1999-03-31

UTI ENERGY CORP
10-K, 1999-03-31
OIL & GAS FIELD SERVICES, NEC

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<PAGE> 1

SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
[X] Annual report pursuant to section 13 or 15(d) of the Securities Exchange
Act of 1934

FOR THE FISCAL YEAR ENDED DECEMBER 31, 1998

[ ] Transition report pursuant to section 13 or 15(d) of the Securities
Exchange Act of 1934 for the transition period from _______________ to
_______________.

Commission File Number 1-12542

UTI ENERGY CORP.
----------------------------------------------------
(Exact name of registrant as specified in its charter)

<TABLE>
<S> <C>
DELAWARE 23-2037823
- ---------------------------------------------- ------------------------------------
(State or other jurisdiction of incorporation) (I.R.S. Employer Identification No.)
</TABLE>

SUITE 225N
16800 GREENSPOINT PARK
HOUSTON, TEXAS 77060
- ---------------------------------------- ----------
(Address of principal executive offices) (Zip Code)

(281) 873-4111
--------------------------------------------------
(Registrant's telephone number, including area code)

Securities registered pursuant to section 12(b) of the Act:

COMMON STOCK, PAR VALUE $.001 AMERICAN STOCK EXCHANGE
- ----------------------------- -----------------------
Title of each class Name of each exchange on which registered

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 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. [ ]

Aggregate market value of the voting stock held by non-affiliates of the
registrant.
$114,814,071 AT MARCH 12, 1999

Number of shares outstanding of each class of registrant's common stock, as of
the latest practicable date.

16,489,281 SHARES OF COMMON STOCK AT MARCH 12, 1999

Documents incorporated by reference.
PROXY STATEMENT FOR THE 1999 ANNUAL MEETING OF SHAREHOLDERS. (PART III)

<PAGE> 2

PART I

ITEM 1. BUSINESS

INTRODUCTION

The Company is a leading provider of onshore contract drilling
services to exploration and production companies and operates one of the
largest land drilling rig fleets in the United States. The Company's drilling
operations currently are concentrated in the prolific oil and natural gas
producing basins of Texas, Oklahoma and New Mexico. The Company's rig fleet
consists of 104 land drilling rigs that are well suited to the requirements of
its markets. The Company also provides pressure pumping services in the
Appalachian Basin.

In March 1999, the Company sold certain assets of International
Petroleum Service Company, its wholly owned Pennsylvania subsidiary, to an
unrelated party. Included in the sale were five drilling rigs, related support
equipment, rolling stock, spare parts, tools and inventory.

BUSINESS SEGMENTS

The Company operates in two business segments: contract drilling and
pressure pumping. The Company also has investments in oil and natural gas
properties, which are not significant, and corporate headquarter activities.
Financial information and other disclosures relating to these business segments
are provided in the Notes to Consolidated Financial Statements.

CONTRACT DRILLING

The Company's contract drilling fleet currently consists of 104 land
drilling rigs having effective depth capacities ranging from 8,000 to 30,000
feet. As of March 12, 1999, the Company had a total of 90 rigs available for
contract compared to 77 rigs available for contract as of December 31, 1997. The
Company also has 14 stacked rigs that could be returned to operation at an
average estimated cost of approximately $500,000 per rig. The Company intends
to either use the stacked rigs as parts or place them into service in an orderly
basis as regional market conditions merit and trained crews are retained. The
Company's rig utilization rate was 55% for the year ended December 31, 1998.
Rig utilizations during the third and fourth quarters were lower than this
average and have further deteriorated during the first quarter of 1999.

The Company's contract drilling services are performed through four
regional drilling units: (1) East Texas (FWA Drilling Company), (2)
Mid-Continent (Triad Drilling Company), (3) South Texas (Southland Drilling
Company) and (4) Permian Basin (FWA/Peterson Drilling Company). The Company's
regional offices are located in Oklahoma City, Oklahoma and Midland, Tyler and
Victoria, Texas. Rigs and equipment are deployed and allocated among the
various drilling units based on regional need and profitability. The Company's
contract drilling customers include major oil companies and various sized
independent producers.

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<PAGE> 3

The Company maintains an incentive compensation plan for its
managerial and key employees based on operating and budgeted results. The
Company believes that this plan provides the Company with the ability to
attract and retain qualified managers and key operating employees. The Company
also provides incentive compensation to its rig workers based on operating
results and safety records.

Drilling Rigs

A land drilling rig consists of various components including engines,
drawworks or hoist, derrick or mast, pumps, blowout preventers and drill pipe.
Rig size and configuration vary with depth, terrain and operator requirements.
An active maintenance program during the life of a drilling rig permits the
maintenance, replacement and upgrading of its components on an individual
basis. Over the life of a typical drilling rig, major components, such as
engines, pumps, drawworks and drill pipe are replaced or rebuilt on a periodic
basis as required while other components, such as the mast and substructure,
can be utilized for extended periods of time with proper maintenance. The
Company follows a policy of keeping its drilling rigs well maintained and
technologically competitive.

The following table sets forth certain information with respect to the
Company's rig fleet and the current distribution of rigs among the Company's
operating regions as of March 12, 1999.

<TABLE>
<CAPTION>
Average Rated
Active Idle Stacked Total Drilling
Region Rigs (1) Rigs (1) Rigs (1) Rigs Depths
------- ---------- ---------- ---------- ----------

<S> <C> <C> <C> <C> <C>
East Texas .. 9 2 -- 11 14,500 ft.
Mid Continent 14 11 9 34 13,500 ft.
South Texas . 5 10 -- 15 16,000 ft.
Permian ..... 10 29 5 44 13,500 ft.
------- ---------- ---------- ---------- ----------
Total ....... 38 52 14 104
</TABLE>

- ------------------
(1) A rig is considered active when under contract. An idle rig is one
that is not under contract but is available and being marketed. A
stacked rig is not currently being marketed and cannot be made
available without incurring refurbishing expenses.

-3-

<PAGE> 4

The following table sets forth, for the periods indicated, certain
data concerning the utilization of the Company's drilling rigs based on the
Company's total fleet, including stacked and idle rigs:

<TABLE>
<CAPTION>
Years Ended December 31,
----------------------------------------
1998 1997 1996
-------- -------- --------
(in thousands, except days and per day data)

<S> <C> <C> <C>
Revenues ................................. $162,600 $161,265 $ 81,534
Cost of revenues ......................... $124,111 $123,889 $ 67,545
Operating days (1) ....................... 20,308 21,576 11,912
Average revenue per day .................. $ 8,007 $ 7,474 $ 6,845
Average costs per day .................... $ 6,111 $ 5,742 $ 5,670
Average margin per day ................... $ 1,896 $ 1,732 $ 1,175
Number of owned rigs at end of year....... 109 89 65
Average number of rigs owned during year.. 100 82 59
Rig utilization percentage (2) ........... 55% 72% 54%
</TABLE>

- ----------------------
(1) An operating day is defined as a day during which a rig is being
operated, mobilized, assembled or dismantled while under contract.

(2) Utilization rates are based on a 365-day year and are calculated by
dividing the number of rigs utilized by the total number of rigs in
the Company's drilling fleet, including stacked rigs. A rig is
considered utilized when it is being operated, mobilized, assembled or
dismantled while under contract. For the year ended December 31, 1998,
the utilization rate of the Company's rigs, excluding stacked rigs,
was 63%.

Drilling Contracts

The Company's drilling rigs are employed under individual contracts
that encompass a well or a number of wells. Drilling contracts are generally
obtained through competitive bidding, although some may be obtained by
negotiation. The Company maintains a disciplined approach to bidding. Contracts
are bid on the basis of profitability and not to maximize rig utilization.
Contracts generally are subject to termination by the customer on short notice.
Drilling contracts may provide for compensation on a footage, turnkey or
dayrate basis. For the year ended December 31, 1998, approximately 40%, 23% and
37% of the revenue was derived on a footage, turnkey or dayrate basis,
respectively. Footage contracts are primarily limited to shallow wells that can
be drilled in less than 15 days, while turnkey contracts are pursued on a
limited basis considering the risks and potential benefits of the contracts.
Dayrate contracts are used primarily on wells that present higher risks.

In a footage contract, the Company undertakes to drill a well to a
specified depth at a fixed price per foot of hole. In a turnkey contract, the
Company undertakes to drill a well to a specified depth for a fixed price. In
both footage and turnkey contracts, the Company must bear the cost of
performing the drilling services until the well has been drilled, and
accordingly, such contracts require significant cash commitments by the
Company. In both footage and turnkey contracts, the Company generally agrees to
furnish services such as testing, coring and casing the hole and other services
which are not normally provided by a drilling contractor working under a
dayrate contract. In both situations, compensation is earned upon completion of
the well to the specified depth. Although the Company seeks to minimize the
risks associated in both footage and turnkey contracts by generally limiting
these contracts to lower risk wells, footage and turnkey contracts,
nevertheless, involve a higher degree of

-4-

<PAGE> 5

risk to the Company than dayrate contracts because the Company assumes greater
risks and bears the cost of unanticipated downhole problems and cost escalation.
The Company enters into footage and turnkey contracts in situations where the
Company possesses experience and expertise in the geological and operational
aspect of the project. As competitive pressures increase due to a continuation
of depressed market conditions, or due to any further deterioration in market
conditions, the Company expects footage and turnkey contracts to represent an
increasing percentage of its total drilling contracts.

A dayrate contract provides for a basic rate per day when drilling and
provides for lower rates when the rig is moving or when drilling operations are
interrupted or restricted by equipment breakdowns, actions of the customer or
adverse weather conditions or other conditions beyond the control of the
Company. In addition, dayrate contracts typically provide for a lump sum fee
for the mobilization and demobilization of the drilling rig. The dayrate
depends on market and competitive conditions, the nature of the operations to
be performed, the duration of the work, the equipment and services to be
provided, the geographic area involved and other variables.

The Company also provides horizontal boring services ("Boring"). Boring
applies vertical drilling technology to bore horizontal holes using a patented
process and equipment for the placement of pipelines and cables, including fiber
optic cables, under obstacles such as highways and railroads when hard rock
conditions are encountered. Boring currently markets its services in the eastern
half of the United States.

PRESSURE PUMPING

The Company, through its subsidiary Universal Well Services, Inc., is
a leading provider of pressure pumping services in the northern Appalachian
Basin. Pressure pumping services consist primarily of well stimulation and
cementing for the completion of new wells and remedial work on existing wells.
Generally, all completed Appalachian Basin wells require cementing services
before production commences. In addition, most completed wells drilled in the
Appalachian Basin require some form of fracturing or other stimulation to
enhance the flow of gas and oil to the well bore.

The Company's pressure pumping equipment consists of cement, fracturing
and nitrogen pumpers, blenders and cement, sand, acid, connection and nitrogen
transport trucks. The Company continuously maintains its pressure pumping
equipment and virtually all is in use on a regular basis. As of March 12, 1999,
the Company operated the following pressure pumping equipment:

<TABLE>
<CAPTION>
Number
Equipment Type of Units
-------------- --------
<S> <C>
Pumper trucks ............................................. 38
Blender trucks ............................................ 10
Bulk cement trucks......................................... 15
Sand trucks ............................................... 20
Acid trucks ............................................... 11
Connection trucks ......................................... 7
Other ..................................................... 4
-------
Total ............................................ 105
=======
</TABLE>

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<PAGE> 6

The following table sets forth, for the periods indicated, certain
data concerning the pressure pumping operations during 1998, 1997 and 1996:

<TABLE>
<CAPTION>
Years Ended December 31,
-----------------------------------
1998 1997 1996
------- ------- -------
(in thousands, except job data)

<S> <C> <C> <C>
Revenues ...................... $23,365 $20,923 $15,484
Cost of revenues .............. $13,645 $12,363 $10,381
Total jobs .................... 3,292 3,196 2,999
Average revenue per job ....... $ 7,098 $ 6,547 $ 5,163
Average costs per job ......... $ 4,145 $ 3,868 $ 3,461
Average margin per job ........ $ 2,953 $ 2,679 $ 1,702
</TABLE>

OTHER OPERATIONS

In addition to its operating activities, the Company has invested in
working interests in gas and oil wells from time to time, principally in the
Appalachian and Permian Basins. The net book value of such investments at
December 31, 1998 and December 31, 1997 was $404,000 and $413,000,
respectively.

INDUSTRY CONDITIONS

Demand and prices for the Company's services depend upon the level of
activity in the onshore oil and natural gas exploration and production industry
in the United States, which in turn depends upon numerous factors over which
the Company has no control, including the level of oil and natural gas prices,
expectations about future oil and natural gas prices, the ability of OPEC to
set and maintain production levels and prices, the cost of exploring for,
producing and delivering oil and natural gas, the level and price of foreign
imports of oil and natural gas, the discovery rate of new oil and natural gas
reserves, available pipeline and other oil and natural gas transportation
capacity, worldwide weather conditions, international, political, military,
regulatory and economic conditions and the ability of oil and natural gas
companies to raise capital.

The level of drilling activity in the onshore oil and natural gas
exploration and production industry in the United States has been volatile and
no assurance can be given that recent levels of oil and natural gas exploration
activities in the Company's markets will continue or that demand for the
Company's services will correspond to the level of activity in the industry.
Further, any changes in the demand for or supply of oil and natural gas
materially impacts the demand for and pricing of the Company's services. In this
regard, in 1998 and a portion of 1997, the Company and the United States
contract drilling industry experienced a substantial decline in demand and
pricing for their services. Since December 1997, the worldwide price of oil has
declined and prices for natural gas have weakened significantly. As prices for
oil have declined, exploration and production companies, (including the
Company's customers), have reduced spending budgets. Such reductions have
reduced the demand for drilling services and increased competitive pressures,
leading to lower contract rates for the Company's contract drilling services
than those received during the third and fourth quarters of 1997. In addition,
rig utilization rates during the first quarter of 1999 have decreased from those
experienced during the last quarter of 1998. The Company currently does not
expect contract rates for its services to recover

-6-

<PAGE> 7

until commodity prices for oil and natural gas improve and any prolonged
continuation of depressed oil and natural gas prices, or any further decline in
oil and natural gas prices, could cause demand and contract rates for the
Company's contract drilling services to decline further. Although all of the
Company's operating regions have been affected by the above-mentioned factors,
certain of the Company's operating regions that are more sensitive to changes
in oil prices, particularly the Permian Basin, have and will be more
significantly effected by current market conditions.

COMPETITION

The contract drilling and well servicing industry is a
highly-fragmented, intensely competitive and cyclical business. Since 1982, the
contract drilling business has been severely impacted by the decline and
continued instability in the prices of oil and natural gas. Though these
depressed economic conditions have resulted in a consolidation of the number of
competitors and the reduction of the number of rigs available, the supply of
available rigs, particularly in the domestic land markets, still exceeds the
demand for those rigs. Industry utilization rates decreased as market conditions
deteriorated in 1998, thereby resulting in additional excess capacity. This
excess capacity in the industry has resulted in substantial competition.
Competition for services in a particular market is based on price, location,
type and condition of available equipment and quality of service. Large and
small contractors provide competition for drilling contracts in all areas of the
Company's business. Certain competitors are present in more than one of those
areas. In addition, drilling rigs are mobile and can be moved from one region to
another in response to market conditions.

SEASONALITY

Seasonality is not a significant factor with respect to the overall
operations of the Company, although the Company's pressure pumping services in
Appalachia are subject to slow periods of activity during spring months.

RAW MATERIALS AND SUBCONTRACTORS

The Company uses numerous suppliers of raw materials and services in
its business and such materials and services have been and continue to be
available. Where appropriate, the Company has adopted programs for products to
maximize price discounts through volume purchases. The Company also utilizes
numerous independent subcontractors representing various trades in connection
with its contract drilling operations.

-7-

<PAGE> 8

OPERATING RISKS AND INSURANCE

The Company's drilling operations and fleet are subject to the many
hazards inherent in the onshore drilling industry, such as blowouts,
explosions, cratering, sour gas, well fires and spills. These hazards can
result in personal injury and loss of life, severe damage to or destruction of
property and equipment, pollution or environmental damage and suspension of
operations. The Company maintains insurance protection as management deems
appropriate. Such insurance coverage, however, may not in all situations
provide sufficient funds to protect the Company from all liabilities that could
result from its operations and claims will be subject to various retentions and
deductibles. The Company generally seeks to obtain indemnity agreements
whenever possible from the Company's customers requiring its customers to hold
the Company harmless in the event of loss of production or reservoir damage.
Even when obtained, however, contractual indemnification may not be supported
by adequate insurance maintained by the customer. There can be no assurance
that the Company's insurance or contractual indemnity protection will be
sufficient or effective under all circumstances or against all hazards to which
the Company may be subject. The occurrence of a significant event not fully
insured or indemnified against or the failure of a customer to meet its
indemnification obligations could have a material adverse effect on the
Company's results of operations and financial condition. Moreover, no assurance
can be given that the Company will be able to maintain insurance in the future
at rates it considers reasonable.

ENVIRONMENTAL REGULATION

The Company's activities are subject to existing federal, state and
local laws and regulations governing environmental quality and pollution
control. It is not anticipated that compliance with existing laws and
regulations regulating the release of materials into the environment or
otherwise relating to the protection of the environment will have a material
adverse effect upon the operations, capital expenditures or earnings of the
Company in the foreseeable future, absent the occurrence of an extraordinary
event. The Company cannot predict what effect additional regulation or
legislation, enforcement policies thereunder and claims for damages to property
and the environment could have on its activities.

The Company's operations routinely involve the handling of various
materials, some of which are classified as hazardous materials. The Company's
operations and facilities are subject to numerous state and federal
environmental laws, rules and regulations, including but not limited to, laws
concerning the containment and disposal of hazardous materials, oilfield waste,
other waste materials and acids and the use of underground storage tanks. Laws
protecting the environment have generally become more restrictive in recent
years. In addition, environmental laws and regulations may impose strict
liability whereby the Company could be liable for clean-up costs, even if the
situation resulted from previous conduct of the Company that was lawful at the
time conducted or from improper conduct of or conditions caused by previous
property owners or other persons not associated with the Company. From time to
time, claims may be made and litigation might be brought against the Company
under these laws. Such clean-up costs or costs associated with changes in
environmental laws and regulations could be substantial and could have a
material adverse effect on the Company's financial condition. However, the cost
of environmental compliance has not had any material adverse effect on the
Company's financial condition in the past. The Company is unable to predict the
effect of new regulations and amendments to existing regulations governing its
operations and therefore is unable to determine the ultimate costs of complying
with environmental laws and regulations.

-8-

<PAGE> 9

The Oil Pollution Act of 1990 ("OPA") amends certain provisions of the
federal Water Pollution Control Act of 1972, commonly referred to as the Clean
Water Act ("CWA") and other statutes as they pertain to the prevention of and
response to oil spills into navigable waters. The OPA subjects owners of
facilities to strict, joint and several liability for all containment and
cleanup costs and certain other damages arising from a spill, including but not
limited to, the costs of responding to a release of oil to surface waters. The
CWA provides penalties for any discharges of petroleum products in reportable
quantities and imposes substantial liability for the costs of removing a spill.
State laws for the control of water pollution also provide varying civil and
criminal penalties and liabilities in the case of releases of petroleum or its
derivatives into surface waters or into the ground. The Environmental
Protection Agency ("EPA") is also authorized to seek preliminary and permanent
injunctive relief and in certain cases, criminal penalties and fines. In the
event that a discharge occurs at a well site at which the Company is conducting
drilling or pressure pumping operations, the Company may be exposed to claims
that it is liable under the CWA.

Certain of the Company's facilities are also subject to EPA
regulations, including regulations that require the preparation and
implementation of spill prevention control and countermeasure plans relating to
the possible discharge of oil into navigable waters.

The Comprehensive Environmental Response Compensation and Liability
Act, as amended, ("CERCLA") (also known as the "Superfund" Law) imposes
liability, without regard to fault or the legality of the original conduct, on
certain classes of persons with respect to the release of a "hazardous
substance" into the environment. These persons include the owner and operator
of a site and persons that disposed of or arranged for the disposal of the
hazardous substances found at the site. CERCLA currently exempts crude oil and
the Resource Conservation and Recovery Act, as amended, currently exempts
certain drilling materials, such as drilling fluids and produced waters, from
the definitions of hazardous substances. There can be no assurance that such
exemptions will be preserved in future amendments of such acts, if any, or that
more stringent laws and regulations protecting the environment will not be
adopted. In addition, the Company's operations may involve the use or handling
of acids currently classified as hazardous substances and other materials that
may in the future be classified as environmentally hazardous substances.

The operations of the Company are subject to local, state and federal
regulations for the control of emissions and air pollution. Legal and
regulatory requirements in this area are increasing and there can be no
assurance that significant costs and liabilities will not be incurred in the
future as a result of new regulatory developments. In particular, regulations
promulgated under the Clean Air Act Amendments of 1990 may impose additional
compliance requirements that could affect the Company's operations. The Company
may in the future be subject to civil or administrative enforcement actions for
failure to comply strictly with air regulations and permits. These enforcement
actions are generally resolved by payment of monetary fines and correction of
any identified deficiencies. Alternatively, regulatory agencies could require
the Company to forego construction or operation of certain air emission
sources.

Management believes that the Company is in substantial compliance with
environmental laws and regulations.

-9-

<PAGE> 10

EMPLOYEES

As of March 12, 1999, the Company had approximately 1,100 full-time
employees, 990 of which were field personnel and 110 of whom were employed in
selling and administrative capacities.

In addition to the services of its employees, the Company employs the
services of consultants as required. None of the Company's employees are
represented by labor unions. There have been no work stoppages or strikes
during the last three years which have resulted in the loss of production or
production delays. The Company believes its relations with its employees are
good.

ITEM 2. PROPERTIES

Contract drilling operations are conducted from facilities the Company
currently owns in Woodward and Oklahoma City, Oklahoma and Midland, Tyler and
Victoria, Texas. Pressure pumping operations are conducted from four base camps
in the Appalachian Basin: one each in Punxsutawney, Bradford and Meadville,
Pennsylvania; and Wooster, Ohio. These camps typically consist of an office
area, an equipment maintenance facility, a bulk storage facility and a storage
yard for vehicles and other materials. The Punxsutawney and Meadville camps are
owned by the Company and the other camps are leased under leases not exceeding
five years.

The Company does not believe that its executive offices or its other
leased facilities, consisting of sales and administrative offices located in or
near each of the Company's areas of operations and generally held under leases
with terms not exceeding five years, are material to its operations. The
Company believes its properties are suitable and adequate for its operations.

ITEM 3. LEGAL PROCEEDINGS

The Company is involved in several claims arising in the ordinary
course of business. In the opinion of management, all of these claims are
covered by insurance and these matters will not have a material adverse effect
on the Company's financial position.

The Company and its operating subsidiaries are sometimes named as a
defendant in litigation usually relating to personal injuries alleged to result
from negligence. The Company maintains insurance coverage against such claims
to the extent deemed prudent by management.

There can be no assurance that the Company will be able to maintain
adequate insurance in the future at rates it considers reasonable and there can
be no assurance that insurance will continue to be available on terms as
favorable as those that currently exist. The occurrence of an adverse claim in
excess of the coverage limits maintained by the Company could have a material
adverse effect on the Company's financial condition and results of operations.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

No matters were submitted to a vote of security holders during the
quarter ended December 31, 1998.

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<PAGE> 11

PART II

ITEM 5. MARKET FOR THE COMPANY'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS

The Company's Common Stock, constituting the only class of common
equity of the Company currently outstanding, is traded on the American Stock
Exchange under the symbol "UTI". The table below provides price information for
the Common Stock for 1998 and 1997, adjusted for the Company's three-for-one
stock split effected on September 5, 1997.

<TABLE>
<CAPTION>
1998 1997
------------------- -------------------
Quarter Ended High Low High Low
------ ------ ------ ------
<S> <C> <C> <C> <C>
March 31 .......... $26.44 $12.00 $11.96 $ 6.83
June 30 ........... $20.50 $12.50 $15.33 $ 8.46
September 30 ...... $13.38 $ 6.50 $42.50 $15.21
December 31 ....... $12.00 $ 5.75 $48.63 $18.50
</TABLE>

As of March 12, 1999, the closing price for the Company's Common Stock
was $9.00. As of March 12, 1999, the Company's Common Stock was held of record
by approximately 100 persons and in management's estimation, beneficially owned
by more than 500 persons.

The Company has not paid a cash dividend on its Common Stock during
the two most recent fiscal years, and, it is not anticipated that any cash
dividend will be paid on the Common Stock for the foreseeable future.

-11-

<PAGE> 12

ITEM 6. SELECTED FINANCIAL DATA

The following table sets forth selected consolidated financial data of
the Company as of and for each of the periods indicated. The selected financial
data for each of the five years in the period ended December 31, 1998, are
derived from the Company's audited consolidated financial statements. The
information presented below should be read in conjunction with "Management's
Discussion and Analysis of Financial Condition and Results of Operations" and
the "Consolidated Financial Statements" and notes thereto included elsewhere
herein.

<TABLE>
<CAPTION>
Years Ended December 31,
-----------------------------------------------------------------------------
1998 1997 1996 1995 1994
--------- --------- --------- --------- ---------
(in thousands, except per share data)
<S> <C> <C> <C> <C> <C>
STATEMENT OF INCOME DATA
Revenues ......................................... $ 186,157 $ 182,437 $ 97,301 $ 40,124 $ 36,275
========= ========= ========= ========= =========

Gross profit ..................................... $ 48,285 $ 46,081 $ 19,044 $ 7,439 $ 8,418

Selling, general and administrative expenses ..... 11,844 11,154 7,627 5,092 4,888
Provisions for bad debts ......................... 1,143 623 141 (10) 70
Other charge ..................................... 785 -- -- -- --
Depreciation and amortization .................... 19,529 11,075 4,292 2,552 2,302
--------- --------- --------- --------- ---------
Operating income (loss) .......................... 14,984 23,229 6,984 (195) 1,158

Other income ..................................... 1,934 1,235 1,341 293 461
Interest expense ................................. (3,815) (4,330) (1,148) (265) (260)
--------- --------- --------- --------- ---------

Income from continuing operations
before income taxes ............................ 13,103 20,134 7,177 (167) 1,359

Income taxes ..................................... 5,235 7,609 2,324 (592) 293
--------- --------- --------- --------- ---------

Income from continuing operations ................ $ 7,868 $ 12,525 $ 4,853 $ 425 $ 1,066
========= ========= ========= ========= =========

Income from continuing operations per common share
Basic ............................................ $ 0.49 $ 0.96 $ 0.46 $ 0.04 $ 0.11
========= ========= ========= ========= =========
Diluted .......................................... $ 0.47 $ 0.83 $ 0.42 $ 0.04 $ 0.11
========= ========= ========= ========= =========
Average common shares outstanding
Basic ............................................ 16,070 13,083 10,448 9,899 9,732
Diluted .......................................... 16,891 15,069 11,439 9,899 9,732

BALANCE SHEET DATA
Working capital................................... $ 20,638 $ 70,452 $ 5,761 $ 5,427 $ 8,179
Total assets ..................................... 232,067 208,987 61,870 33,990 22,474
Long-term debt, including Redeemable Stock ....... 31,721 30,159 14,658 8,701 2,211
Shareholders' equity ............................. 144,146 137,620 22,696 14,990 13,745
</TABLE>

-12-

<PAGE> 13

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS

OVERVIEW

UTI is a leading provider of onshore contract drilling services to
exploration and production companies and operates one of the largest land
drilling rig fleets in the United States. The Company's drilling operations are
currently concentrated in the prolific oil and natural gas producing basins of
Texas, Oklahoma and New Mexico. The Company's rig fleet consists of 104 land
drilling rigs that are well suited to the requirements of its markets. The
Company's contract drilling services are performed through four regional
drilling units and are marketed under the names FWA Drilling Company,
FWA/Peterson Drilling Company, Southland Drilling Company and Triad Drilling
Company. The Company also provides pressure pumping services in the Appalachian
Basin.

Beginning in 1995, the Company made a strategic decision to focus its
efforts on the expansion of its land drilling operations to take advantage of
improving market conditions and the benefits arising from a consolidation in
the land drilling industry. To effect this strategy, the Company disposed of
its oilfield distribution business in September 1995 and immediately embarked
on a directed acquisition program aimed at expanding the Company's presence in
the oil and natural gas producing regions in the United States. Pursuant to this
strategy, the Company acquired 66 rigs in five transactions during 1995, 1996
and 1997. The Company acquired an additional 20 rigs in three transactions
during 1998. As a result of these acquisitions and increased rig utilization
and dayrates caused by favorable market conditions, the Company's revenues grew
substantially during 1996 and 1997. During the latter part of 1997 and during
1998, however, the Company and the United States contract drilling industry, in
general, experienced significant declines in demand and pricing for their
services. As a result of these depressed market conditions, the Company's fleet
utilization decreased to 55% in 1998 from 72% in 1997 and dayrates also
decreased.

In response to these depressed industry conditions, the Company
undertook a series of actions during the third quarter of 1998 designed to
improve efficiency, increase productivity and make the Company more competitive
in the market place. These actions included the streamlining of certain contract
drilling operations, certain personnel changes and changes to the accounting and
administrative functions, including the relocation of certain accounting
functions from Oklahoma City to the Company's corporate headquarters in Houston.
This consolidation of operations reduced the Company's number of regional
operating units from nine to seven and reduced the Company's administrative
staff by twenty individuals. As a result of these actions, the Company recorded
a one-time other charge during 1998 of $.8 million, which included approximately
$.6 million of employee-related expenses. The Company further reduced operating
overhead by consolidating regional operations offices in Oklahoma and the
Permian Basin and by implementing additional staff reductions, which will result
in a charge during the first quarter of 1999 of approximately $.3 million. In
addition, the Company sold certain non-strategic assets of its Appalachian Basin
contract drilling division for $5.6 million, which will result in the Company
recording a one-time gain of approximately $2.7 million during the first quarter
of 1999. As a result of these initiatives, the Company believes that it has
brought its cost and operating structure more in line with current industry
conditions and has strengthened its balance sheet. In this regard, as of March
12, 1999, the Company had $17.0 million in cash and no borrowings under its
$30.0 million credit facility.

-13-

<PAGE> 14

The Company currently does not expect market conditions in the
contract drilling industry to improve until commodity prices for oil and
natural gas increase substantially. In this regard, the Company has continued
to see utilization rates and dayrates decrease during the first quarter of 1999
and expects its average utilization during the first quarter of 1999 to be less
than the 44% average utilization experienced during the fourth quarter of 1998.
Dayrates and contract prices for footage and turnkey wells also have declined
during the first quarter of 1999. Although conditions in the contract drilling
industry have significantly declined over prior periods and further declines
are possible, the Company believes that its strong liquidity position and
balance sheet provide it with the financial flexibility to withstand continued
or additional deterioration in market conditions and react quickly to
opportunities in the contract drilling industry.

RESULTS OF OPERATIONS

The Company views the number of rigs actively drilling in the United
States as a barometer of the overall strength of the domestic oilfield service
industry. Without giving effect to acquisitions, variations in revenues and
gross margins of the Company's core business generally follow the rig count
trend. Subsequent to year end, the United States land rig count has declined
from 519 active rigs as of December 31, 1998 to 413 active rigs as of March 12,
1999.

The following table presents certain results of operations data for
the Company and the average United States rig count as reported by Baker Hughes
Inc.(1) for the periods indicated:

<TABLE>
<CAPTION>
Years Ended December 31,
----------------------------------------
1998 1997 1996
-------- -------- --------
<S> <C> <C> <C>
Operating Data:
---------------
Average U.S. land rig count ....................... 671 801 673
Number of owned rigs (at end of year) ............. 109 89 65
Average number of rigs owned during year .......... 100 82 59

Contract Drilling:
------------------
Operating days (2) ................................ 20,308 21,576 11,912
Utilization rate (3) .............................. 55% 72% 54%

Pressure Pumping:
-----------------
Cementing jobs .................................... 2,296 2,245 2,094
Stimulation jobs .................................. 996 951 905

Financial Data (in thousands):
--------------
Revenues .......................................... $186,157 $182,437 $ 97,301
======== ======== ========
Gross profit ...................................... $ 48,285 $ 46,081 $ 19,044
======== ======== ========
As a percentage of revenue ........................ 25.9% 25.3% 19.6%
======== ======== ========
Operating income .................................. $ 14,984 $ 23,229 $ 6,984
======== ======== ========
</TABLE>

- --------------------
(1) Baker Hughes, Inc. is an international oilfield service and equipment
company which, for more than twenty years, has conducted and published
a weekly census of active drilling rigs. Its active rig count is
generally regarded as an industry standard for measuring industry
activity levels.

-14-

<PAGE> 15

(2) An operating day is defined as a day during which a rig is being
operated, mobilized, assembled or dismantled while under contract.

(3) Utilization rates are based on a 365-day year and are calculated by
dividing the number of rigs utilized by the total number of rigs in
the Company's drilling fleet, including stacked rigs. A rig is
considered utilized when it is being operated, mobilized, assembled or
dismantled while under contract. For the year ended December 31, 1998,
the utilization rate of the Company's rigs, excluding stacked rigs,
was 63%.

COMPARISON OF YEARS ENDED 1998 AND 1997

Revenues by business segment for the years ended December 31, 1998 and
1997 are as follows:

<TABLE>
<CAPTION>
Years
Ended December 31, %
----------------------- Increase
1998 1997 (Decrease)
-------- -------- --------
(in thousands)
<S> <C> <C> <C>
Revenues:
---------
Land Drilling $162,600 $161,265 0.8%
Pressure Pumping 23,365 20,923 11.7%
Other 192 249 (22.9%)
-------- --------
$186,157 $182,437 2.0%
======== ========
</TABLE>

Land drilling revenues remained flat as a result of depressed market
conditions resulting in decreased utilization rates and dayrates and prices
received on footage and turnkey contracts, which was offset by additional
revenues from acquisitions of additional rigs during 1997 and 1998. The
increase in pressure pumping revenue is a result of an increase in pressure
pumping jobs and related rates, which have not been adversely affected by
declining oil and natural gas prices to the same extent as the Company's land
drilling operations.

Gross profit by business segment for the years ended December 31, 1998
and 1997 are as follows:

<TABLE>
<CAPTION>
Years
Ended December 31, %
--------------------- Increase
1998 1997 (Decrease)
------- ------- ----------
(in thousands)
<S> <C> <C> <C>
Gross Profit:
-------------
Land Drilling $38,488 $37,376 3.0%
Pressure Pumping 9,720 8,560 13.6%
Other 77 145 (46.9%)
------- -------
$48,285 $46,081 4.8%
======= =======
</TABLE>

Pressure pumping's gross profit increased due to an increase in gross
profit per job on stimulation jobs for the year ended December 31, 1998 compared
to the same period of 1997.

-15-

<PAGE> 16

Selling, general and administrative expenses increased $.7 million
during the year ended December 31, 1998, compared to the year ended December
31, 1997, primarily due to acquisitions consummated during the third and fourth
quarters of 1997 and during 1998.

Provisions for bad debts increased $.5 million for the year ended
December 31, 1998, compared to the year ended December 31, 1997, primarily due
to existing industry conditions.

The other charge of $.8 million for the year ended December 31, 1998
was the result of the streamlining of certain contract drilling operations and
changes to the accounting and administrative functions.

Depreciation and amortization expense increased $8.5 million during
the year ended December 31, 1998, compared to the year ended December 31, 1997,
primarily due to acquisitions consummated during the third and fourth quarters
of 1997 and during 1998.

Interest expense decreased $.5 million during the year ended December
31, 1998 compared to the year ended December 31, 1997. This decrease was
primarily due to a reduction in outstanding debt for the year ended December
31, 1998 compared to the same period of 1997. Average debt outstanding was
$26.7 million during the year ended December 31, 1998 compared to $35.7 million
for the year ended December 31, 1997. The effective interest rate for the year
ended December 31, 1998 was 14.3% compared to 12.1% for the year ended December
31, 1997.

Income taxes decreased $2.4 million during the year ended December 31,
1998, compared to the year ended December 31, 1997, primarily due to lower
taxable income in 1998. The Company's effective tax rate for the year ended
December 31, 1998 was 40.0% and 37.8% for the year ended December 31, 1997, with
the increase primarily attributable to goodwill amortization associated with
the acquisitions that is nondeductible for tax purposes.

COMPARISON OF YEARS ENDED 1997 AND 1996

Revenues by business segment for the years ended December 31, 1997 and
1996 are as follows:

<TABLE>
<CAPTION>
Years
Ended December 31, %
----------------------- Increase
1997 1996 (Decrease)
-------- -------- --------
(in thousands)
<S> <C> <C> <C>
Revenues:
---------
Land Drilling $161,265 $ 81,534 97.8%
Pressure Pumping 20,923 15,484 35.1%
Other 249 283 (12.0%)
-------- --------
$182,437 $ 97,301 87.5%
======== ========
</TABLE>

-16-

<PAGE> 17

Land drilling revenue increased for the year ended December 31, 1997
from the year ended December 31, 1996, primarily due to the increase in demand
for drilling services combined with growth in the Company's rig fleet as a
result of acquisitions consummated in 1996 and 1997. The Company's rig fleet
was employed for 21,576 days during the year ended December 31, 1997 compared
to 11,912 days in the corresponding period of 1996. The Company completed 3,196
pressure pumping jobs during the year ended December 31, 1997 as compared to
2,999 jobs for the year ended December 31, 1996. Revenue increases also
reflected improvements in average dayrates and prices received for footage and
turnkey contracts.

Gross profit by business segment for the years ended December 31, 1997
and 1996 are as follows:

<TABLE>
<CAPTION>
Years
Ended December 31, %
----------------------- Increase
1997 1996 (Decrease)
-------- -------- --------
(in thousands)
<S> <C> <C> <C>
Gross Profit (Loss):
--------------------
Land Drilling $ 37,376 $ 13,989 167.2%
Pressure Pumping 8,560 5,103 67.7%
Other 145 (48) 402.1%
-------- --------
$ 46,081 $ 19,044 142.0%
======== ========
</TABLE>

Gross profit increased for the year ended December 31, 1997 compared to
the same period in 1996 due to higher revenues, increased prices and
consolidation savings. Contract drilling gross profit as a percentage of revenue
was 23.2% in 1997 and 17.2% for the year ended December 31, 1996. Pressure
pumping gross profit as a percentage of revenue was 40.9% for the year ended
December 31, 1997 and 33.0% for the corresponding period of 1996.

Depreciation and amortization expense increased $6.8 million during
the year ended December 31, 1997, compared to the year ended December 31, 1996,
primarily due to the acquisitions consummated during 1996 and 1997.

Selling, general and administrative expenses increased $3.5 million
primarily due to the acquisitions consummated during 1996 and 1997 and the
related increase in the average number of rigs operated during the period.
Selling, general and administrative expenses decreased to 6.1% as a percentage
of revenues for the year ended December 31, 1997 compared to 7.8% for the year
ended December 31, 1996.

Interest expense increased $3.2 million during the year ended December
31, 1997, compared to the year ended December 31, 1996, primarily due to
interest on the debt associated with the acquisitions consummated during 1996
and 1997. Average debt outstanding was $35.7 million during the year ended
December 31, 1997 compared to $15.2 million for the year ended December 31,
1996. The Company also incurred a one time prepayment penalty of $132,000
during the second quarter of 1997 in connection with a refinancing of
indebtedness during the quarter.

Interest income increased $.6 million during the year ended December
31, 1997 compared to the year ended December 31, 1996. In October of 1997, the
Company completed a secondary offering of which the excess funds were invested
in short-term, interest-bearing, investment-grade securities.

-17-

<PAGE> 18

Other income decreased $.7 million during the year ended December 31,
1997, compared to the year ended December 31, 1996, primarily because the prior
period included a one-time payment of $.7 million that the Company received as
a result of a favorable resolution of a dispute with the United States
government over mineral rights owned by the Company in Southeastern New Mexico.

Income taxes increased $5.3 million during the year ended December 31,
1997, compared to the year ended December 31, 1996, primarily due to higher
taxable income in 1997. The Company's effective tax rate for the year ended
December 31, 1997 was 37.8% compared to 32.4% for the year ended December 31,
1996. The increase in rates was primarily due to the utilization of net
operating losses in 1996, with no such losses available in 1997 and the Company
subject to a statutory rate of 35.0% in 1997 compared to 34.0% in 1996.

LIQUIDITY AND CAPITAL RESOURCES

Working Capital

The Company's primary cash needs historically have been to fund
working capital requirements, make capital expenditures to replace and expand
its drilling rig fleet and for acquisitions. The Company's ongoing operations
have been funded through available cash, cash provided from operations and
borrowings under the Company's line of credit with Mellon Bank, N.A., as
amended (the "Working Capital Line"). To date, acquisitions have been funded
with available cash, borrowings and issuances of Common Stock and warrants to
purchase Common Stock.

In October 1997, the Company sold in a public offering 1,792,600
shares of Common Stock. Shares of Common Stock held by various shareholders of
the Company were also sold in this offering, including 1,707,000 shares of
Common Stock that were subject to outstanding warrants and options. The net
proceeds from this offering to the Company, including approximately $13.0
million from the exercise of warrants and options to purchase shares of Common
Stock that were sold in the offering, were approximately $80.0 million. The
Company utilized approximately $27.9 million of the net proceeds to repay all
of its outstanding debt other than its 12.0% Senior Subordinated Notes due 2001
(the "Subordinated Notes"). The Company has utilized these available cash
resources, together with its cash flows from operations, to fund acquisitions
during 1998 as well as a stock repurchase program of up to $10.0 million in
Common Stock. As a result, the Company had $10.3 million in cash and cash
equivalents and no borrowings under the Working Capital Line as of December 31,
1998 compared to $58.3 million in cash and cash equivalents and no borrowings
under the Working Capital Line as of December 31, 1997. The Company's working
capital as of December 31, 1998 was $20.6 million compared to $70.5 million as
of December 31, 1997. In addition, in March 1999, the Company sold certain
non-strategic assets located in the Appalachian Basin for $5.6 million in cash.
As a result, the Company had $17.0 million in cash and no borrowings under the
Working Capital Line as of March 12, 1999. The Company intends to utilize these
available cash resources, together with its cash flow from operations, to
continue to fund its operations and to fund its stock repurchase program of up
to $10.0 million.

Net cash provided by operations was $31.6 million and $24.2 million,
for 1998 and 1997, respectively. Such funds were utilized primarily to fund
acquisitions and capital expenditures. Capital expenditures, excluding
acquisitions, for the years ended December 31, 1998 and 1997 were $37.4 million
and $18.4 million, respectively.

-18-

<PAGE> 19

Long Term Debt Facilities

As of December 31, 1998, the Company had outstanding $31.7 million in
debt. Such indebtedness included $25.0 million associated with a 1997 private
placement of debt securities in connection with an acquisition and refinancing
of existing indebtedness and $7.8 million of notes associated with an
acquisition completed in 1998.

Working Capital Line. On June 19, 1998, the Company entered into an
amended Working Capital Line, which now provides for maximum borrowings of up
to $30.0 million. Under the Working Capital Line, up to $1.6 million may be
utilized for letters of credit. Borrowings under the Working Capital Line bear
interest at the lower of the bank's prime rate or a LIBOR-based rate.
Borrowings under the Working Capital Line mature on June 30, 2000 and are
secured by all of the Company's accounts receivable and inventory (excluding
the Company's drilling rigs, drilling equipment or drill pipe). The Working
Capital Line contains covenants and restrictions customary in financial
instruments of this type, including covenants relating to the maintenance of
financial ratios, changes in control of the Company and limits on capital
expenditures. As of December 31, 1998, the Company had no outstanding
borrowings under this facility.

Subordinated Notes. On April 11, 1997, the Company issued $25.0
million principal amount of 12.0% Subordinated Notes due 2001 (the "Subordinated
Notes"). The Subordinated Notes were issued at a 2.0% discount along with
seven-year warrants to purchase 1.2 million shares of Common Stock at an
exercise price of $10.83 per share, of which warrants to purchase 720,000
shares of Common Stock were exercised in connection with the Company's October
1997 public offering. The Subordinated Notes contain various affirmative and
negative covenants customary in such private placements, including restrictions
on additional indebtedness (unless certain pro forma financial coverage ratios
are met), restrictions on dividends, distributions and other restricted
payments.

Promissory Notes. On July 31, 1998, the Company issued $7.8 million
principal amount of unsecured promissory notes. The notes bear interest at 7.0%
and mature on July 31, 2002. The notes were issued in connection with an
acquisition.

Stock Repurchase Program

On February 18, 1998, the Board of Directors of the Company approved a
stock repurchase by the Company of up to $10.0 million of Common Stock pursuant
to transactions effected from time to time in the open market. As of March 12,
1999, the Company has utilized $3.3 million to repurchase 293,900 shares of
Common Stock at an average purchase price of $11.15 per share. The Company
expects to continue this stock repurchase program during 1999.

Future Acquisitions and Capital Needs

Management believes its internally generated cash, availability under
the Working Capital Line and cash balances on hand will be sufficient to meet
its working capital, capital expenditure and debt service requirements for the
next twelve months. The Company believes that its strong liquidity position
also provides it with the financial flexibility to react quickly to
opportunities in the contract drilling industry, including opportunities to
make strategic acquisitions that the Company deems advisable given current
industry conditions.

-19-

<PAGE> 20

INFLATION

Inflation has not had a significant impact on the Company's
comparative results of operations.

YEAR 2000

The Year 2000 Issue is the result of computer programs written using
two digits rather than four to define the applicable year. Any of the Company's
computer programs or hardware that have date-sensitive software or embedded
chips may recognize a date using "00" as the year 1900 rather than the Year
2000. This could result in a system failure or miscalculations causing
disruptions of operations, including among other things, a temporary inability
to process transactions, send invoices or engage in similar normal business
activities.

The Company's plan to resolve the Year 2000 Issue involves the
following four phases: assessment, remediation, testing and implementation. To
date, the Company has fully completed its assessment of all systems that it
believes could be significantly affected by the Year 2000. The completed
assessment indicated that most of the Company's significant information
technology systems could be affected, particularly the general ledger
accounting system. The Company does not believe that the Year 2000 Issue
presents a material exposure as it relates to the Company's services. In
addition, the Company has gathered information about the Year 2000 compliance
status of its significant suppliers and subcontractors and continues to monitor
their compliance.

For its information technology exposures, to date, the Company is 40%
complete on the remediation phase and expects to complete software
reprogramming and replacement no later than July 31, 1999. Once software is
reprogrammed or replaced for a system, the Company begins testing and
implementation. These phases run concurrently for different systems with all
remediated systems expected to be fully tested and implemented by August 31,
1999 with 100% completion targeted for October 31, 1999.

The Company has contacted its significant suppliers and subcontractors
and, to date, the Company is not aware of any third parties with a Year 2000
Issue that would materially impact the Company's results of operations,
liquidity or capital resources. However, the Company has no means of ensuring
that third parties will be Year 2000 ready. The inability of third parties to
complete their Year 2000 resolution process in a timely fashion could
materially impact the Company by causing such third parties to fail to timely
deliver or supply needed material and services to or on behalf of the Company,
thereby materially adversely affecting the Company's ability to deliver its
services in a timely and cost-effective manner in accordance with Company
standards or by causing third party customer's operations to temporarily
shut-down or delay operations, thereby materially affecting demand for the
Company's services. The effect of non-compliance by third parties is not
determinable.

The Company will utilize both internal and external resources to
reprogram or replace, test and implement the software and operating equipment
for Year 2000 modifications. The total cost of the Year 2000 Project is
estimated at $1.0 million and is being funded through operating cash flows. To
date, the Company has incurred approximately $.4 million for new systems
related to all phases of the Year 2000 Project, which has been capitalized. The
total remaining project costs is attributable to the purchase of new software
and operating equipment, which will also be capitalized.

-20-

<PAGE> 21

Management of the Company believes it has an effective program in
place to resolve the Year 2000 Issues in a timely manner. However, the Company
has not yet completed all necessary phases of the Year 2000 Project.
Disruptions in the economy generally resulting from Year 2000 Issues could also
materially adversely affect the Company. The Company could be subject to
litigation for computer systems product failure, including equipment shutdown
or failure to properly date business records. The amount of potential liability
and lost revenue cannot be reasonably estimated at this time.

The Company currently has no contingency plans in place in the event
it does not complete all phases of the Year 2000 Project. The Company plans to
evaluate the status of completion in July 1999 and determine whether such plans
are necessary.

NEW ACCOUNTING PRONOUNCEMENTS

In June 1997, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 130, "Reporting Comprehensive
Income" (SFAS 130). SFAS 130, which is effective for fiscal years beginning
after December 15, 1997, establishes standards for reporting and presentation
of comprehensive income and its components. SFAS 130 requires that all items
that are required to be recognized under accounting standards as components of
comprehensive income be reported in a financial statement that is displayed
with the same prominence as other financial statements. The Company adopted
SFAS 130 effective December 31, 1998. The change did not have a significant
effect on the Company's financial statements.

In June 1997, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 131, "Disclosures about Segments
of an Enterprise and Related Information" (SFAS 131). SFAS 131, which is
effective for fiscal years beginning after December 15, 1997, established
revised guidelines for determining an entity's operating segments, as well as
the type and level of financial information to be disclosed. The Company
adopted SFAS 131 effective December 31, 1998. The change did not have a
significant effect on the Company's financial statements.

In March 1998, the Accounting Standards Executive Committee issued
Statement of Position 98-1, "Accounting for the Cost of Computer Software
Developed or Obtained for Internal Use." This statement provides guidance on
accounting for the cost of software developed or obtained for internal use and
is effective for fiscal years beginning after December 15, 1998. The Company
will adopt this standard in the first quarter of 1999. Management does not
believe its adoption will have a significant effect on the Company's financial
statements.

In June 1998, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 133, "Accounting for Derivative
Instruments and Hedging Activities" (SFAS 133). SFAS 133, which is effective for
fiscal years beginning after June 15, 1999, requires all derivatives to be
recognized at fair value on the balance sheet. The Company plans to adopt SFAS
133 no later than January 1, 2000. The change is not expected to have a
significant effect on the Company's financial statements.

-21-

<PAGE> 22

RISKS ASSOCIATED WITH FORWARD-LOOKING STATEMENTS

From time to time, the Company may make certain statements that
contain "forward-looking" information (as defined in the Private Securities
Litigation Reform Act of 1995). Words such as "anticipate", "believe",
"expect", "estimate", "project" and similar expressions are intended to
identify such forward-looking statements. Forward-looking statements may be
made by management orally or in writing, including but not limited to, in press
releases, as part of the "Business", "Properties" and "Management's Discussion
and Analysis of Financial Conditions and Results of Operations" contained in
this report and in the Company's other filings with the Securities and Exchange
Commission under the Securities Act of 1933 and the Securities Exchange Act of
1934.

Although the Company believes that the expectations reflected in such
forward-looking statements are reasonable, it can give no assurance that such
expectations will prove to have been correct. Such forward-looking statements
are subject to certain risks, uncertainties and assumptions, including without
limitation those identified below. Should one or more of these risks or
uncertainties materialize or should any of the underlying assumptions prove
incorrect, actual results of current and future operations may vary materially
from those anticipated, estimated or projected. Readers are cautioned not to
place undue reliance on these forward-looking statements, which speak only as
of their dates.

Among the factors that will have a direct bearing on the Company's
results of operations and the contract drilling service industry in which it
operates are changes in the prices of oil and natural gas and the volatility of
the contract drilling service industry in general, including the effects of
recent downturns in prices for oil and natural gas; and risks that a
continuation of current industry conditions or further decline in industry
conditions will adversely effect the demand for and pricing of the Company's
services; any difficulties associated with the Company's ability to
successfully integrate recent acquisitions; contractual risk associated with
turnkey and footage contracts; the presence of competitors with greater
financial resources; labor shortages; operating risks inherent in the contract
drilling service industry, such as blowouts, explosions, cratering, sour gas,
well fires and spills; labor shortages; domestic and world-wide political
stability and economic growth; risks associated with the Year 2000 Issue and
other risks associated with the Company's successful execution of internal
operating plans as well as regulatory uncertainties and legal proceedings.

The risks related to the Year 2000 Issue and the dates on which the
Company believes its Year 2000 Project will be completed are based on
management's best estimates, which were derived utilizing numerous assumptions
of future events, including the continued availability of certain resources,
third-party modification plans and other factors. However, there can be no
guarantee that these estimates will be achieved, or that there will not be a
delay in, or increased costs associated with the implementation of the
Company's Year 2000 Project. Specific factors that might cause differences
between the estimates and actual results, include but are not limited to, the
availability and cost of personnel trained in these areas, the ability to
locate and correct all relevant computer codes, timely responses to and
corrections by third parties and suppliers, the ability to implement interfaces
between the new systems and the systems not being replaced and similar
uncertainties. Due to the general uncertainty inherent in the Year 2000
Project, resulting in part from uncertainty of the Year 2000 readiness of third
parties and the interconnection of global businesses, the Company cannot ensure
its ability to timely and cost effectively resolve problems associated with the
Year 2000 Issue that may affect its operations and business or expose it to
third-party liability.

-22-

<PAGE> 23

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company's exposure to market risk for changes in interest rates
relates primarily to the Company's long-term debt obligations. The tables below
provide information about the Company's financial instruments that are
sensitive to changes in interest rates.

For debt obligations, the tables below present expected cash flows and
related weighted-average interest rates expected by maturity dates. The fair
value of fixed rate debt is based on the estimated yield to maturity for each
debt issue as of December 31, 1998 and 1997.

<TABLE>
<CAPTION>
Fair
Expected Maturity Date Value
1999 2000 2001 2002 Total 12/31/98
------ ------ ------ ------ ----- --------
(in millions, except interest rate percentages)

<S> <C> <C> <C> <C> <C> <C>
Long Term Debt
- --------------
Debt service (a) ..... $ 3.5 $ 3.5 $27.0 $ 8.1 $42.1 $33.0
Average effective
interest rate ..... 12.3% 12.3% 10.4% 7.0% 11.7%

<CAPTION>
Fair
Expected Maturity Date Value
1999 2000 2001 2002 Total 12/31/98
------ ------ ------ ------ ----- --------
(in millions, except interest rate percentages)

<S> <C> <C> <C> <C> <C> <C>
Long Term Debt
- --------------
Debt service (a) ..... $ 3.0 $ 3.0 $ 3.0 $26.5 $35.5 $26.4
Average effective
interest rate ..... 14.0% 14.0% 14.0% 14.0% 14.0%
</TABLE>
- -------------
(a) Assumes scheduled maturities are funded with available resources.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Financial Statements of the Company meeting the requirements of
Regulation S-X (except Section 210.3-05 and Article 11 thereof) are included
herein on pages F-1 through F-24 hereof.

Other financial statements and schedules required under Regulation
S-X, if any, are filed pursuant to Item 14, Exhibits, Financial Statement
Schedules and Reports on Form 8-K, of this Annual Report on Form 10-K.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE

None.

-23-

<PAGE> 24

PART III

The information required by Part III, Items 10 through 13, inclusive,
of Form 10-K is hereby incorporated by reference from the Company's Definitive
Proxy Statement for the 1999 Annual Meeting of Shareholders, which shall be
filed with the Securities and Exchange Commission not later than 120 days after
the end of the fiscal year to which this Annual Report on Form 10-K relates.

PART IV

ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K

(a) The following documents are filed as part of this Annual Report
on Form 10-K:

<TABLE>
<CAPTION>
Page
<S> <C>
(1) Financial Statements of UTI Energy Corp:

Index..................................................................................... F-1

Report of Independent Auditors............................................................ F-2

Consolidated Balance Sheets at December 31, 1998 and 1997................................. F-3

Consolidated Statements of Income for the Years Ended
December 31, 1998, 1997 and 1996....................................................... F-4

Consolidated Statements of Changes in Shareholders' Equity for the
Years Ended December 31, 1998, 1997 and 1996........................................... F-5

Consolidated Statements of Cash Flows for the Years Ended
December 31, 1998, 1997 and 1996....................................................... F-6

Notes to Consolidated Financial Statements................................................ F-7

(2) Financial Statement Schedule:

Schedule II - Valuation and Qualifying Accounts........................................... S-1
</TABLE>

All other schedules for which provision is made in the applicable
accounting regulation of the Securities and Exchange Commission
are not required under the related instructions or are inapplicable
and therefore have been omitted.

-24-

<PAGE> 25

(3) The following Exhibits are filed as part of this Annual Report on Form
10-K.

<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
3.1 - Restated Certificate of Incorporation of the Company (incorporated by reference to
Amendment No. 1 to the Company's Registration Statement on Form S-1 (No. 33-69726)).

3.2 - Amendment to Restated Certificate of Incorporation (incorporated by reference to Amendment
No. 1 to the Company's Registration Statement on Form S-1 (No. 33-69726)).

3.3 - Amendment to Restated Certificate of Incorporation (incorporated by reference to the
Company's Annual Report on Form 10-K for the year ended December 31, 1994).

3.4 - Amendment to Restated Certificate of Incorporation, dated August 28, 1997, (incorporated
by reference to Exhibit 3.4 to the Company's Registration Statement on Form S-3 (No.
333-35109)).

3.5 - By-laws of the Company, as amended (incorporated by reference to Exhibit 3.3 to the
Company's Annual Report on Form 10-K for the year ended December 31, 1993).

3.6 - Rights Agreement, dated February 26, 1999, between UTI Energy Corp. and ChaseMellon
Shareholder Services, L.L.C. as Rights Agent (incorporated by reference to Exhibit 4.1 to
the Company's Current Report on Form 8-K, dated February 26, 1999, filed with the
Securities and Exchange Commission on March 4, 1999).

3.7 - Certificate of Designation, Powers, Preferences and Rights of Series I Preferred Stock,
dated February 26, 1999, (incorporated by reference to Exhibit 4.2 to the Company's
Current Report on Form 8-K, dated February 26, 1999, filed with the Securities and
Exchange Commission on March 4, 1999).

3.8 - Form of Right Certificate (incorporated by reference to Exhibit 4.3 to the Company's
Current Report on Form 8-K, dated February 26, 1999, filed with the Securities and
Exchange Commission on March 4, 1999).
</TABLE>

-25-

<PAGE> 26
<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
4.1 - See Exhibit No. 3.1 through 3.8 for provisions of the Restated Certificate of
Incorporation and amended By-laws of the Company defining the rights of the holders of
Common Stock.

4.2 - Form of Common Stock Certificate (incorporated by reference to Amendment No. 1 to the
Company's Registration Statement on Form S-1 (No. 33-69726)).

4.3 - Registration Rights Agreement with Bear Stearns & Co. Inc., dated March 25, 1994, as
assigned to Remy Capital Partners III, L.P. (incorporated by reference to Exhibit 10.17
to the Company's Annual Report on Form 10-K for the year ended December 31, 1993).

4.4 - Stock Option Agreement, dated December 19, 1995, between the Company and Remy Consultants
Incorporated (incorporated by reference to Exhibit 2 to the Company's Amendment No. 1 to
Schedule 13D, dated August 8, 1996).

4.5 - Amended and Restated UTI Energy Corp. 1996 Employee Stock Option Plan (incorporated by
reference to Exhibit 4.6 to the Company's Annual Report on Form 10-K for the year ended
December 31, 1997).

4.6 - Warrant Agreement, dated April 11, 1997, by and between UTI Energy Corp. and Southland
Drilling Company, Ltd. (incorporated by reference to Exhibit 10.1 to the Company's Current
Report on Form 8-K dated April 11, 1997).

4.7 - Note Purchase Agreement, dated April 11, 1997, by and among FWA Drilling Company, Inc.,
International Petroleum Service Company, Triad Drilling Company, Universal Well Services,
Inc., USC, Incorporated, Panther Drilling, Inc. and Canpartners Investments IV, LLC
(incorporated by reference to Schedule 13D relating to the Company filed on April 22, 1997
by Canpartners Investments IV, LLC, Canpartners Incorporated, Mitchell R. Julis,
Joshua S. Friedman and R. Christian B. Evensen).

4.8 - Note, dated April 11, 1997, payable by FWA Drilling Company, Inc., International Petroleum
Service Company, Triad Drilling Company, Universal Well Services, Inc., USC, Incorporated
and Panther Drilling, Inc. to Canpartners Investments IV, LLC. (incorporated by reference
to Exhibit 10.5 to the Company's Current Report on Form 8-K dated April 11, 1997).
</TABLE>

-26-

<PAGE> 27
<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
4.9 - Warrant Agreement, dated April 11, 1997, by and between UTI Energy Corp. and Canpartners
Investments IV, LLC. (incorporated by reference to Exhibit 10.6 to the Company's Current
Report on Form 8-K dated April 11, 1997).

4.10 - Warrant, dated April 11, 1997, by and between UTI Energy Corp. and Canpartners Investments
IV, LLC. (incorporated by reference to Exhibit 10.7 to the Company's Current Report on
Form 8-K dated April 11, 1997).

4.11 - Registration Rights Agreement, dated April 11, 1997, by and between UTI Energy Corp. and
Canpartners Investments IV, LLC. (incorporated by reference to Exhibit 10.8 to the
Company's Current Report on Form 8-K dated April 11, 1997).

4.12 - 1993 Restricted Stock Plan (incorporated by reference to Amendment No. 1 to the Company's
Registration Statement on Form S-1 (No. 33-69726)).

4.13 - Amended and Restated UTI Energy Corp. Non-Employee Director Stock Option Plan (incorporated
by reference to Exhibit 4.18 to the Company's Annual Report on Form 10-K for the year ended
December 31, 1997).

4.14 - 1993 Non-Qualified Incentive Stock Option Plan (incorporated by reference to Amendment
No. 3 to the Company's Registration Statement on Form S-1 (No. 33-69726)).

4.15 - Amended and Restated 1997 Long-Term Incentive Plan (incorporated by reference to Exhibit
4.2 to the Company's Annual Report on Form 10-K for the year ended December 31, 1997).

4.16 - Form of Warrant to purchase an aggregate of 75,000 shares of Common Stock at $26.50 per
share, which was issued to the former shareholders of Suits Enterprises, Inc. listed on
such exhibit in the amounts set forth opposite such former shareholder's name on such
exhibit (incorporated by reference from the Company's Quarterly Report on Form 10-Q for the
six months ended June 30, 1998).

4.17 - Form of Warrant to purchase an aggregate of 25,000 shares of Common Stock at $35.00 per
share, which was issued to the former shareholders of Suits Enterprises, Inc. listed on
such exhibit in the amounts set forth opposite such former shareholder's name on such
exhibit (incorporated by reference from the Company's Quarterly Report on Form 10-Q for the
six months ended June 30, 1998).
</TABLE>

-27-

<PAGE> 28

<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
4.18 - Form of Note Payable, in the aggregate amount of $7.79 million, which was issued to the
former shareholders of Suits Enterprises, Inc. listed on such exhibit in the amounts set
forth opposite such former shareholder's name on such exhibit (incorporated by reference
from the Company's Quarterly Report on Form 10-Q for the six months ended June 30, 1998).

4.19 - Amended and Restated Loan and Security Agreement, dated June 19, 1998, by and among FWA
Drilling Company, Inc., International Petroleum Service Company, Triad Drilling Company,
Universal Well Services, Inc., USC, Incorporated, UTI Energy Corp., UTICO, Inc., Panther
Drilling, Inc., J.S.M. & Associates, Inc., Peterson Drilling Company and Mellon Bank, N.A.
(incorporated by reference from the Company's Quarterly Report on Form 10-Q for the six
months ended June 30, 1998).

4.20 - Amended and Restated Note, dated June 19, 1998, by and among FWA Drilling Company, Inc.,
International Petroleum Service Company, Triad Drilling Company, Universal Well Services,
Inc., USC, Incorporated, UTI Energy Corp., UTICO, Inc., Panther Drilling, Inc., J.S.M. &
Associates, Inc., Peterson Drilling Company and Mellon Bank, N.A. (incorporated by
reference from the Company's Quarterly Report on Form 10-Q for the six months ended
June 30, 1998).

4.21 - Amended and Restated Subordination Agreement, dated June 19, 1998, by and among FWA
Drilling Company, Inc., International Petroleum Service Company, Triad Drilling Company,
Universal Well Services, Inc., USC, Incorporated, UTI Energy Corp., UTICO, Inc., Panther
Drilling, Inc., J.S.M. & Associates, Inc., Peterson Drilling Company and Mellon Bank, N.A.
(incorporated by reference from the Company's Quarterly Report on Form 10-Q for the six
months ended June 30, 1998).

4.22 - Amended and Restated Contribution Agreement, dated June 19, 1998, by and among FWA Drilling
Company, Inc., International Petroleum Service Company, Triad Drilling Company, Universal
Well Services, Inc., USC, Incorporated, UTI Energy Corp., UTICO, Inc., Panther Drilling,
Inc., J.S.M. & Associates, Inc., Peterson Drilling Company and Mellon Bank, N.A.
(incorporated by reference from the Company's Quarterly Report on Form 10-Q for the six
months ended June 30, 1998).

10.1 - For additional material contracts see Exhibits 4.3 through 4.22.
</TABLE>

-28-

<PAGE> 29

<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
10.2 - Amended and Restated Employment Agreement with Vaughn E. Drum, dated December 19, 1996
(incorporated by reference to Exhibit 10.4 to the Company's Current Report on Form 8-K
dated January 27, 1997).

*21.1 - List of subsidiaries of the Company.

*23.1 - Consent of Ernst & Young LLP.

*27 - Financial Data Schedule.
</TABLE>

*Filed herewith.

As permitted by Item 601(b)(4)(iii)(A) of Regulation S-K, the Company
has not filed with this Form 10-K certain instruments defining the right of
holders of long-term debt of the Company and its subsidiaries because the total
amount of securities authorized under any of such instruments does not exceed
10% of the total assets of the Company and its subsidiaries on a consolidated
basis. The Company agrees to furnish a copy of any such agreement to the
Commission upon request.

-29-

<PAGE> 30

UTI ENERGY CORP.
CONSOLIDATED FINANCIAL STATEMENTS

CONTENTS

AUDITED CONSOLIDATED FINANCIAL STATEMENTS

<TABLE>
<S> <C>
Report of Independent Auditors................................................................. F-2

Consolidated Balance Sheets.................................................................... F-3

Consolidated Statements of Income.............................................................. F-4

Consolidated Statements of Changes in Shareholders' Equity..................................... F-5

Consolidated Statements of Cash Flows.......................................................... F-6

Notes to Consolidated Financial Statements..................................................... F-7
</TABLE>

F-1

<PAGE> 31

REPORT OF INDEPENDENT AUDITORS

To the Board of Directors
UTI Energy Corp.

We have audited the accompanying consolidated balance sheets of UTI Energy
Corp. as of December 31, 1998 and 1997, and the related consolidated statements
of income, changes in shareholders' equity, and cash flows for each of the
three years in the period ended December 31, 1998. Our audits also included the
financial statement schedule listed in the index at item 14(a). These financial
statements and schedule are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements and
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 also includes assessing the accounting
principles used and significant estimates made by management, as well as
evaluating the overall financial statement presentation. We believe that our
audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present
fairly, in all material respects, the consolidated financial position of UTI
Energy Corp. at December 31, 1998 and 1997, and the consolidated results of its
operations and its cash flows for each of the three years in the period ended
December 31, 1998, in conformity with generally accepted accounting principles.
Also, in our opinion, the related financial statement schedule, when considered
in relation to the basic financial statements taken as a whole, presents fairly
in all material respects the information set forth therein.

/s/ Ernst & Young LLP

Houston, Texas
February 18, 1999

F-2

<PAGE> 32
UTI ENERGY CORP.
CONSOLIDATED BALANCE SHEETS
(in thousands)

<TABLE>
<CAPTION>
DECEMBER 31,
--------------------------
1998 1997
---------- ----------

<S> <C> <C>
ASSETS
CURRENT ASSETS
Cash and cash equivalents....................................................................... $ 10,337 $ 58,347
Accounts receivable, net of allowance for doubtful accounts of $1,919 in 1998 and $815 in 1997 . 25,485 34,359
Other receivables .............................................................................. 3,250 1,230
Materials and supplies ......................................................................... 887 1,363
Prepaid expenses ............................................................................... 4,598 749
---------- ----------
44,557 96,048
PROPERTY AND EQUIPMENT
Land ........................................................................................... 1,224 1,149
Buildings and improvements ..................................................................... 3,324 2,819
Machinery and equipment ........................................................................ 202,698 116,357
Oil and gas working interests .................................................................. 1,943 1,893
Construction in process ........................................................................ 2,729 4,305
---------- ----------
211,918 126,523
Less accumulated depreciation and amortization ................................................. 47,070 31,508
---------- ----------
164,848 95,015

GOODWILL, less accumulated amortization of $2,086 in 1998 and $652 in 1997 ..................... 20,791 17,758
OTHER ASSETS ................................................................................... 1,871 166
---------- ----------

$ 232,067 $ 208,987
========== ==========

LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable................................................................................ $ 17,649 $ 14,087
Accrued payroll costs .......................................................................... 2,387 5,048
Accrued health insurance ....................................................................... 1,284 764
Accrued income taxes ........................................................................... -- 3,375
Current portion of long-term debt .............................................................. -- 50
Other accrued expenses ......................................................................... 2,599 2,272
---------- ----------
23,919 25,596

LONG-TERM DEBT, less current portion ........................................................... 31,721 23,458
DEFERRED INCOME TAXES .......................................................................... 31,625 15,256
OTHER LIABILITIES .............................................................................. 656 356

COMMITMENTS AND CONTINGENCIES
REDEEMABLE STOCK
Common Stock, $.001 par value, 309 shares issued and 0 outstanding
in 1998, 309 shares issued and outstanding in 1997 .......................................... -- 6,701
SHAREHOLDERS' EQUITY
Preferred Stock $.01 par value, 5,000 shares authorized,
0 shares issued or outstanding in 1998 and 1997 .............................................. -- --
Common Stock, $.001 par value, 50,000 shares authorized, 16,612 shares issued
and 16,009 outstanding in 1998, 16,147 shares issued and outstanding in 1997 ................. 17 16
Additional capital ............................................................................. 128,825 120,208
Retained earnings .............................................................................. 25,309 17,441
Restricted stock plan unearned compensation .................................................... -- (45)
Treasury Stock, 603 shares in 1998, 0 in 1997, at cost ......................................... (10,005) --
---------- ----------
144,146 137,620
---------- ----------

$ 232,067 $ 208,987
========== ==========
</TABLE>

See accompanying notes.

F-3

<PAGE> 33

UTI ENERGY CORP.
CONSOLIDATED STATEMENTS OF INCOME
(in thousands, except per share amounts)

<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
--------------------------------------------
1998 1997 1996
--------- ---------- ---------

<S> <C> <C> <C>
REVENUES ......................................... $ 186,157 $ 182,437 $ 97,301

COST OF REVENUES.................................. 137,872 136,356 78,257
--------- ---------- --------

GROSS PROFIT...................................... 48,285 46,081 19,044

OTHER COSTS AND EXPENSES
Selling, general and administrative............... 11,844 11,154 7,627
Provisions for bad debts.......................... 1,143 623 141
Other charge...................................... 785 -- --
Depreciation and amortization..................... 19,529 11,075 4,292
--------- ---------- --------
33,301 22,852 12,060
--------- ---------- --------

OPERATING INCOME.................................. 14,984 23,229 6,984

OTHER INCOME (EXPENSE)
Interest expense.................................. (3,815) (4,330) (1,148)
Interest income................................... 1,084 689 83
Other, net........................................ 850 546 1,258
--------- ---------- --------
(1,881) (3,095) 193
--------- ---------- --------

INCOME BEFORE INCOME TAXES........................ 13,103 20,134 7,177

INCOME TAXES...................................... 5,235 7,609 2,324
--------- ---------- --------

NET INCOME........................................ $ 7,868 $ 12,525 $ 4,853
========= ========== ========

BASIC EARNINGS PER COMMON SHARE................... $ 0.49 $ 0.96 $ 0.46
========= ========== ========

DILUTED EARNINGS PER COMMON SHARE................. $ 0.47 $ 0.83 $ 0.42
========= ========== ========

AVERAGE COMMON SHARES OUTSTANDING
Basic ............................................ 16,070 13,083 10,448
Diluted .......................................... 16,891 15,069 11,439
</TABLE>

See accompanying notes.

F-4

<PAGE> 34

UTI ENERGY CORP.
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY
(in thousands)

<TABLE>
<CAPTION>
COMMON STOCK RESTRICTED
----------------------- RETAINED STOCK PLAN
NUMBER PAR ADDITIONAL EARNINGS UNEARNED TREASURY
OF SHARES $.001 CAPITAL DEFICIT COMPENSATION STOCK TOTAL
--------- --------- ---------- ---------- ------------ ---------- ---------

<S> <C> <C> <C> <C> <C> <C> <C>
Balance at December 31, 1995 ...... 10,399 $ 10 $ 15,088 $ 63 $ (171) $ -- $ 14,990

Net income ........................ -- -- -- 4,853 -- -- 4,853
Warrants issued ................... -- -- 710 -- -- -- 710
Exercise of options ............... 408 1 1,838 -- -- -- 1,839
Vesting of restricted stock plan .. -- -- 234 -- 70 -- 304
------ --------- --------- --------- ---------- --------- ---------
Balance at December 31, 1996 ...... 10,807 11 17,870 4,916 (101) -- 22,696

Net income ........................ -- -- -- 12,525 -- -- 12,525
Issuance of Common Stock .......... 2,836 3 84,528 -- -- -- 84,531
Warrants issued ................... -- -- 1,410 -- -- -- 1,410
Exercise of warrants .............. 2,193 2 14,308 -- -- -- 14,310
Exercise of options ............... 311 -- 2,092 -- -- -- 2,092
Vesting of restricted stock plan .. -- -- -- -- 56 -- 56
------ --------- --------- --------- ---------- --------- ---------
Balance at December 31, 1997 ...... 16,147 16 120,208 17,441 (45) -- 137,620

Net income ........................ -- -- -- 7,868 -- -- 7,868
Redemption of Redeemable Stock .... -- 1 6,701 -- -- (6,702) --
Warrants issued ................... -- -- 411 -- -- -- 411
Exercise of options ............... 156 -- 1,505 -- -- -- 1,505
Purchase of Treasury Stock ........ (294) -- -- -- -- (3,303) (3,303)
Vesting of restricted stock plan .. -- -- -- -- 45 -- 45
------ --------- --------- --------- ---------- --------- ---------
Balance at December 31, 1998 ...... 16,009 $ 17 $ 128,825 $ 25,309 $ -- $ (10,005) $ 144,146
====== ========= ========= ========= ========== ========= =========
</TABLE>

See accompanying notes.

F-5

<PAGE> 35

UTI ENERGY CORP.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)

<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
------------------------------------
1998 1997 1996
-------- -------- --------

<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income ................................................... $ 7,868 $ 12,525 $ 4,853
Adjustments to reconcile net income to net cash
provided by operations
Depreciation ............................................. 17,630 10,410 4,236
Amortization ............................................. 1,899 665 56
Deferred income taxes .................................... 2,549 1,012 799
Amortization of debt discount ............................ 475 402 68
Stock compensation expense ............................... 45 56 304
Provisions for bad debts ................................. 1,104 510 112
Gain on disposal of fixed assets ......................... (579) (774) (517)
Change in operating assets and liabilities, net of
effect of businesses acquired
Receivables and prepaids ............................. 5,445 (16,670) (7,990)
Materials and supplies ............................... 477 (489) (71)
Accounts payable and accruals ........................ (2,622) 16,357 4,647
Other ................................................ (2,723) 217 (174)
-------- -------- --------
Net cash provided by operating activities ......... 31,568 24,221 6,323

CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures ......................................... (37,429) (18,356) (4,311)
Acquisitions of businesses, net of cash ...................... (34,300) (36,847) (6,000)
Proceeds from sale of property and equipment ................. 1,530 1,373 1,113
-------- -------- --------
Net cash used by investing activities ............. (70,199) (53,830) (9,198)

CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of long-term debt ..................... -- 58,900 2,600
Repayments of long-term debt ................................. (52) (52,559) (2,467)
Repurchased stock ............................................ (10,005) -- --
Proceeds from issuance of Common Stock ....................... 678 81,045 1,039
-------- -------- --------
Net cash provided (used) by financing activities .. (9,379) 87,386 1,172
-------- -------- --------

NET INCREASE (DECREASE) IN CASH AND
CASH EQUIVALENTS ........................................... (48,010) 57,777 (1,703)

CASH AND CASH EQUIVALENTS AT BEGINNING
OF YEAR .................................................... 58,347 570 2,273
-------- -------- --------
CASH AND CASH EQUIVALENTS AT END OF YEAR ..................... $ 10,337 $ 58,347 $ 570
======== ======== ========
</TABLE>

See accompanying notes.

F-6

<PAGE> 36

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of Business

UTI Energy Corp. (the "Company") is a leading provider of onshore
contract drilling services to exploration and production companies and
operates one of the largest land drilling rig fleets in the United
States. The Company's drilling operations currently are concentrated
in the prolific oil and natural gas producing basins of Texas,
Oklahoma and New Mexico. As of December 31, 1998, the Company's rig
fleet consisted of 109 land drilling rigs that were well suited to the
requirements of its markets. The Company also provides pressure
pumping services in the Appalachian Basin.

Principles of Consolidation

The consolidated financial statements include the accounts of the
Company and its subsidiaries, all of which are wholly owned.
Intercompany accounts and transactions have been eliminated in
consolidation.

Use of Estimates

The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates
and assumptions that affect the amounts reported in the financial
statements and accompanying notes. Actual results could differ from
those estimates.

Cash and Cash Equivalents

The Company considers all highly liquid investments with a maturity of
three months or less when purchased to be cash equivalents.

Materials and Supplies

Materials and supplies are composed of replacement parts and supplies
held for use in the operations of the Company and are stated at the
lower of cost (first-in, first-out method) or market.

Property and Equipment

Property and equipment are stated at cost. Improvements are capitalized
and depreciated over the period of benefit. The Company periodically
reviews its long-lived assets for impairment. Provisions for impairment
are charged to income when indicators of impairment are present and
when it is considered probable that the carrying values of producing
asset groups may not be recovered over their remaining service lives
based on estimates of future net cash flows on an undiscounted basis.
Upon retirement or other disposal of fixed assets, the cost and related
accumulated depreciation are removed from the respective accounts and
any gains or losses are included in results of operations. Depreciation
is determined by the straight-line method over the estimated useful
lives of the related assets which are as follows: buildings--30 years,
building improvements--7-10 years, machinery and equipment--2-15 years.

F-7

<PAGE> 37

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Goodwill

Excess of cost over the fair value of net assets acquired (or goodwill)
is amortized on a straight-line basis over 15 years. The Company
periodically assesses goodwill for impairment. Goodwill associated with
assets acquired in a purchase business combination is included in
impairment evaluations when events or changes in circumstances indicate
that the carrying amount of those assets may not be recoverable. If
this review indicates that goodwill will not be recoverable, as
determined based on the estimated undiscounted cash flows of the entity
acquired over the remaining amortization period, the carrying amount of
the goodwill is reduced by the estimated shortfall of cash flows.

Revenue Recognition

Revenues are recognized when services have been performed. Revenues
from footage and turnkey drilling contracts are recognized using the
percentage of completion method of accounting. Losses, if any, are
provided for in the period in which the loss is determinable.

Earnings Per Share

In February 1997, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 128, "Earnings per
Share" (SFAS 128). SFAS 128 replaced the calculation of primary and
fully diluted earnings per share with basic and diluted earnings per
share. Unlike primary earnings per share, basic earnings per share
excludes any dilutive effects of options, warrants and convertible
securities. Diluted earnings per share is very similar to the
previously reported fully diluted earnings per share. All earnings per
share amounts for all periods have been presented and where
appropriate, restated to conform to the SFAS 128 requirements.

Stock Split

The Company's Common Stock split 3:1 on September 5, 1997. In
conjunction with the split, the authorized number of $.001 par Common
Stock was increased from 10 million to 50 million shares. All
references in the financial statements to number of shares, per share
amounts and market prices of the Company's Common Stock have been
retroactively restated to reflect the increased number of shares as a
result of the split.

Stock-Based Compensation

The Company follows the method of accounting for employee stock
compensation plans prescribed by APB No. 25, which is permitted by
Statement of Financial Accounting Standards No. 123, "Accounting for
Stock-Based Compensation" (SFAS 123). In accordance with APB No. 25,
the Company has not recognized compensation expense for stock options
because the exercise price of the options equals the market price of
the underlying stock on the date of grant, which is the measurement
date.

F-8

<PAGE> 38

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

New Accounting Pronouncements

In June 1997, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 130, "Reporting
Comprehensive Income" (SFAS 130). SFAS 130, which is effective for
fiscal years beginning after December 15, 1997, establishes standards
for reporting and presentation of comprehensive income and its
components. SFAS 130 requires that all items that are required to be
recognized under accounting standards as components of comprehensive
income be reported in a financial statement that is displayed with the
same prominence as other financial statements. The Company adopted
SFAS 130 effective December 31, 1998. The change did not have a
significant effect on the Company's financial statements.

In June 1997, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 131, "Disclosures about
Segments of an Enterprise and Related Information" (SFAS 131). SFAS
131, which is effective for fiscal years beginning after December 15,
1997, established revised guidelines for determining an entity's
operating segments, as well as the type and level of financial
information to be disclosed. The Company adopted SFAS 131 effective
December 31, 1998. The change did not have a significant effect on the
Company's financial statements.

In March 1998, the Accounting Standards Executive Committee issued
Statement of Position 98-1, "Accounting for the Cost of Computer
Software Developed or Obtained for Internal Use." This statement
provides guidance on accounting for the cost of software developed or
obtained for internal use and is effective for fiscal years beginning
after December 15, 1998. The Company will adopt the standard in the
first quarter of 1999. Management does not believe its adoption will
have a significant effect on the Company's financial statements.

In June 1998, the Financial Accounting Standards Board issued Statement
of Financial Accounting Standards No. 133, "Accounting for Derivative
Instruments and Hedging Activities." The Statement requires the Company
to recognize all derivatives on the balance sheet at fair value. The
Company plans to adopt the new Statement no later than January 1, 2000.
This change is not expected to have a significant effect on the
Company's financial statements.

Reclassifications

Certain items in the prior years' financial statements have been
reclassified to conform with the presentation in the current year.

F-9

<PAGE> 39

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

2. ACQUISITIONS

On August 14, 1996, the Company purchased all of the capital stock of
Viersen & Cochran Drilling Company ("Viersen"). Prior to that date,
Viersen had been engaged in contract drilling in Oklahoma but had
suspended its operations. The consideration paid for Viersen consisted
of (i) $6.0 million in cash; (ii) a two-year $8.0 million promissory
note executed by the Company in favor of the Seller; and (iii) stock
warrants with a two-year term to purchase 600,000 shares of the
Company's Common Stock at $5.00 per share. On April 11, 1997, the
Company prepaid the Promissory Note at a contractually agreed upon
discounted balance of $7.6 million plus accrued interest. The
acquisition of Viersen was accounted for using the purchase method,
and Viersen's operating results since August 14, 1996, have been
consolidated with the operating results of the Company. No goodwill
was recorded because the estimated fair market value of the assets
acquired exceeded the purchase price.

On January 27, 1997, the Company acquired the contract drilling assets
of Quarles Drilling Corporation ("Quarles") for $16.2 million,
consisting of $8.1 million in cash and 733,779 shares of Common Stock
(after adjustment pursuant to the purchase agreement). The acquired
assets consisted of nine land drilling rigs, various equipment, rig
components and other equipment used in Quarles' contract drilling
business. The acquisition was accounted for using the purchase method
and Quarles' operating results since January 27, 1997 have been
consolidated with the operating results of the Company. No goodwill
was recorded because the estimated fair market value of the assets
acquired exceeded the purchase price.

On April 11, 1997, the Company acquired the land drilling operations
of Southland Drilling Company Ltd. ("Southland") for approximately
$27.1 million in cash and a five-year warrant to purchase 300,000
shares of Common Stock at an exercise price of $16.00 per share. The
acquired assets consisted of nine land drilling rigs, various
equipment, components and other equipment used in Southland's contract
drilling business. The acquisition was accounted for using the
purchase method and Southland's operating results since April 11, 1997
have been consolidated with the operating results of the Company.
Goodwill of $10.1 million have been recorded related to this
acquisition.

On September 11, 1997, the Company acquired all of the capital stock
of J.S.M. & Associates, Inc. ("JSM") for 618,748 shares of Common
Stock and $2.6 million in cash. Prior to this date, JSM was an
independent contract land driller in the Permian Basin. JSM's assets
at the time of acquisition included seven land drilling rigs, an
office and warehouse in Odessa, Texas and approximately $1.0 million
in networking capital. The acquisition was accounted for using the
purchase method of accounting and JSM's operating results since
September 11, 1997 have been consolidated with the operating results
of the Company. Goodwill of $9.1 million has been recorded related to
this acquisition.

F-10

<PAGE> 40

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

2. ACQUISITIONS (Continued)

On April 9, 1998, the Company acquired Peterson Drilling Company
("Peterson"), for a total purchase price of $20.4 million in cash,
which the Company funded from cash on hand following the public
offering in October 1997. Peterson's assets included eight drilling
rigs, as well as related drilling equipment, office facilities in
Midland, Texas and approximately $4.5 million in net working capital.
The acquisition has been accounted for under the purchase method of
accounting. Goodwill of $3.6 million has been recorded related to this
acquisition.

On June 24, 1998, the Company acquired the land drilling assets of
LaMunyon Drilling Corporation ("LaMunyon") for $12.2 million in cash,
which the Company funded from cash on hand following the Company's
public offering in October 1997. The acquired assets consisted of five
land drilling rigs, related spare parts, office equipment and rolling
stock. The acquisition has been accounted for using the purchase
method of accounting. No goodwill was recorded because the estimated
fair market value of the assets acquired exceeded the purchase price.

On July 31, 1998, the Company acquired Suits Enterprises, Inc.
("Suits") for a total of approximately $11.1 million, comprised of
$2.9 million in cash, $7.8 million in 7% four-year notes and 100,000
five-year warrants of Common Stock. Warrants to purchase 75,000 shares
of Common Stock are exercisable at $26.50 per share and warrants to
purchase 25,000 shares of Common Stock are exercisable at $35.00 per
share. Included in the acquisition are Suits' seven complete drilling
rigs plus assorted spare parts and drilling equipment and a fleet of
rolling stock. The acquisition has been accounted for using the
purchase method of accounting. No goodwill was recorded because the
estimated fair market value of the assets acquired exceeded the
purchase price.

The following pro forma operating results reflect the inclusion of
Quarles and Southland for all of 1997 and Peterson for all of 1998 and
1997 (such pro forma operating results, however, exclude the
operations of JSM prior to September 11, 1997, the LaMunyon assets
prior to June 24, 1998 and Suits prior to July 31, 1998, as these
acquisitions were not significant to the Company's operations):

<TABLE>
<CAPTION>
Years Ended December 31,
-----------------------------------------
1998 1997
---------- -----------
(in thousands, except per share amounts)

<S> <C> <C>
Revenues ............................... $ 192,306 $ 213,863
========== ==========

Net income ............................. $ 8,526 $ 13,114
========== ==========

Diluted earnings per common share ...... $ 0.50 $ 0.87
========== ==========
</TABLE>

F-11

<PAGE> 41

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

3. LONG-TERM DEBT

The Company's long-term debt at December 31, 1998 and 1997 consisted
of the following:

<TABLE>
<CAPTION>
December 31,
-------------------
1998 1997
------- -------
(in thousands)

<S> <C> <C>
Subordinated notes .......... $25,000 $25,000
Promissory notes ............ 7,790 --
Other ....................... -- 52
------- -------
32,790 25,052
Less: unamortized discount .. 1,069 1,544
Less: current portion ....... -- 50
------- -------

$31,721 $23,458
======= =======
</TABLE>

Subordinated Notes

On April 11, 1997, the Company issued $25.0 million principal amount
of subordinated notes at a 2% discount and 1.2 million seven-year
warrants for shares of Common Stock with an exercise price of $10.83
per share. The Company assigned a value of $1.4 million to the
warrants issued and is amortizing this cost to interest expense over
the life of the borrowing. The subordinated notes bear interest at
12%, payable quarterly until the notes mature on April 11, 2001. Early
retirement of this debt is not permitted under the terms of the
agreement prior to April 11, 1999. The notes contain various
affirmative and negative covenants customary in such private
placements, including restrictions on additional indebtedness (unless
certain pro forma financial coverage ratios are met), restrictions on
dividends, distributions and other restricted payments.

Promissory Notes

On July 31, 1998, in conjunction with the acquisition of Suits, the
Company executed four-year $7.8 million unsecured promissory notes to
the sellers. The notes bear interest at a fixed rate of 7.0% and
mature on July 31, 2002.

Working Capital Line

The Company maintains a revolving credit agreement ("Working Capital
Line") with a certain financial institution. Total borrowings and
letters of credit available under this agreement were increased in
1998 from $12.4 million to $30.0 million. Borrowings under the
agreement bear interest at the lower of the bank's prime rate or other
rate options available at the time of borrowing (7.75% at December 31,
1998 and 8.5% at December 31, 1997). The Working

F-12

<PAGE> 42

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

3. LONG-TERM DEBT (Continued)

Capital Line, which is to be used for working capital and general
corporate purposes, is secured by the pledge of the Company's accounts
receivable and inventory. The Working Capital Line contains covenants
and restrictions customary in financial instruments of this type,
including covenants relating to the maintenance of financial ratios,
changes in control of the Company and limits on capital expenditures.
There were no borrowings under this facility in 1998. The Company
incurs a commitment fee of .25% of unused borrowings. A $1.6 million
standby letter of credit is issued under this agreement.

4. LEASES

Future minimum payments, for each year and in the aggregate, under
noncancellable operating leases with initial or remaining terms of one
year or more consist of the following at December 31, 1998 (in
thousands):

<TABLE>
<S> <C>
1999............................................ $ 486
2000............................................ 413
2001............................................ 341
2002............................................ 240
2003 and thereafter............................. 63
-----------
Total minimum lease payments.................... $ 1,543
===========
</TABLE>

Rental expense for all operating leases was approximately $511,000,
$472,000 and $448,000 for the years ended December 31, 1998, 1997 and
1996, respectively.

5. CONTINGENCIES

The Company is involved in several claims arising in the ordinary
course of business. In the opinion of management, all of these claims
are covered by insurance and these matters will not have a material
adverse effect on the Company's financial position.

The Company is partially self-insured for employee health insurance
claims and for workers' compensation. The Company incurs a maximum of
$100,000 per employee under medical claims and a maximum of $250,000
per event for workers' compensation claims. Although the Company
believes that adequate reserves have been provided for expected
liabilities arising from its self-insured obligations, it is
reasonably possible that management's estimates of these liabilities
will change over the near term as circumstances develop.

6. REDEEMABLE STOCK

As part of the JSM acquisition, the former shareholders of JSM
obtained the contractual right to put back to the Company, at $21.66
per share, one half of the shares issued by the Company in the
business combination (309,374 shares). On January 6, 1998, the former
shareholders of JSM exercised these puts. The Company has treated this
repurchase as a 1998 treasury stock purchase and has assigned a value
of $21.66 per share.

F-13

<PAGE> 43

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

7. WARRANTS

The Company issued warrants to purchase 75,000 and 25,000 shares of
Common Stock at an exercise price of $26.50 and $35.00 per share,
respectively, as part of the consideration paid to acquire Suits. The
warrants are exercisable, in whole or in part, for five years
beginning July 31, 1998.

The Company issued warrants to purchase 1.2 million shares of Common
Stock at an exercise price of $10.83 per share to an investment
company as consideration for financing obtained in April 1997. From
this issuance of warrants, 720,000 shares of Common Stock were
exercised in 1997. The remaining warrants are exercisable, in whole or
in part, for seven years beginning April 11, 1997.

The Company issued warrants to purchase up to 300,000 shares of Common
Stock at an exercise price of $16.00 per share as part of the
consideration paid to acquire the land drilling operations of
Southland. From this issuance, warrants for 105,000 shares of Common
Stock were exercised in 1997. The remaining warrants are exercisable,
in whole or in part, for five years beginning April 11, 1997.

8. OTHER CHARGE

During 1998, the Company incurred a $.8 million charge related to a
series of actions taken to improve efficiency, increase productivity
and make the Company more competitive in the market place. The actions
included the relocation of certain accounting functions and the
reduction of regional operating offices from nine to seven.

9. INCOME TAXES

Deferred income taxes reflect the tax effects of temporary differences
between the carrying amounts of assets and liabilities for financial
reporting purposes and the amounts for income tax purposes.
Significant components of the Company's deferred tax assets and
liabilities as of December 31, 1998 and 1997, are as follows:

<TABLE>
<CAPTION>
December 31,
----------------------
1998 1997
-------- --------
(in thousands)
<S> <C> <C>
Deferred tax assets
Alternative minimum tax credits ...... $ 36 $ 272
Investment tax credits ............... 184 232
Accrued expenses ..................... 1,845 1,591
-------- --------
Total deferred tax asset ... 2,065 2,095

Deferred tax liabilities
Depreciation ......................... (33,690) (17,351)
-------- --------

Net deferred tax liability ...... $(31,625) $(15,256)
======== ========
</TABLE>

F-14

<PAGE> 44

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

9. INCOME TAXES (Continued)

Management assesses the realizability of the Company's deferred tax
assets on a continuous basis and adjusts the valuation allowance in
the event that circumstances change affecting the realization of the
deferred tax assets.

During 1997, the Company reduced its valuation allowance related to
investment tax credit carryforwards to zero since management believed
that it was more likely than not that the deferred tax asset would be
realized primarily from future taxable income produced through certain
tax planning strategies. These credits expire by 2001. The Company
utilizes the flow-through method for recognizing investment tax
credits.

The components of the provision for income taxes are as follows:

<TABLE>
<CAPTION>
Years Ended December 31,
----------------------------
1998 1997 1996
------ ------ ------
(in thousands)
<S> <C> <C> <C>
Income taxes:
-------------
Current:
Federal .......................... $2,372 $5,681 $1,372
State ............................ 314 916 153
------ ------ ------
2,686 6,597 1,525

Deferred:
Federal .......................... 2,540 1,005 740
State ............................ 9 7 59
------ ------ ------
2,549 1,012 799
------ ------ ------
$5,235 $7,609 $2,324
====== ====== ======
</TABLE>

The difference between tax expense computed at the federal income tax
rate of 35% for 1998 and 1997 and 34% for 1996 and actual tax expense
is as follows:

<TABLE>
<CAPTION>
Years Ended December 31,
-------------------------------
1998 1997 1996
-------- -------- ------
(in thousands)

<S> <C> <C> <C>
Taxes applied to pre-tax income ... $ 4,586 $ 7,047 $ 2,440
State income tax .................. 204 595 141
Change in statutory tax rate ...... -- 435 --
Permanent differences, principally
nondeductible expenses ........... 588 38 123
Change in valuation allowance ..... -- (232) (404)
Other ............................. (143) (274) 24
------- ------- -------
$ 5,235 $ 7,609 $ 2,324
======= ======= =======
</TABLE>

F-15

<PAGE> 45

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

10. EARNINGS PER SHARE

The following table sets forth the computation of basic and diluted
earnings per share:

<TABLE>
<CAPTION>
Years Ended December 31,
-------------------------------
1998 1997 1996
------- ------- -------
(in thousands, except per share amounts)
<S> <C> <C> <C>
Numerator:
Net income ........................................... $ 7,868 $12,525 $ 4,853
======= ======= =======
Denominator:
Denominator for basic earnings per
share - weighted-average shares .................... 16,070 13,083 10,448
Effect of dilutive securities:
Stock options ................................... 745 1,286 756
Warrants ........................................ 76 676 235
Other ........................................... -- 24 --
------- ------- -------
Dilutive potential common shares ................ 821 1,986 991
------- ------- -------

Denominator for diluted earnings per
share-adjusted weighted-average
shares and assumed conversions ................ 16,891 15,069 11,439
======= ======= =======

Basic earnings per share ............................. $ 0.49 $ 0.96 $ 0.46
======= ======= =======

Diluted earnings per share ........................... $ 0.47 $ 0.83 $ 0.42
======= ======= =======
</TABLE>

F-16

<PAGE> 46

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

11. SUPPLEMENTAL CASH FLOW INFORMATION

<TABLE>
<CAPTION>
Years Ended December 31,
----------------------------
1998 1997
----------- -----------
(in thousands)
<S> <C> <C>
Noncash Investing and Financing Activities:
Quarles acquisition with Common Stock
issuance ..................................... $ -- $ 8,100
Southland acquisition with warrants granted ..... -- 10
JSM acquisition with Common Stock and
Redeemable Stock ............................. -- 16,086
JSM acquisition, deferred tax liability
recorded ..................................... -- 5,183
Tax benefit of exercised stock options
reflected in additional capital .............. 828 1,403
Debt retired in conjunction with warrant
conversion to Common Stock .................. -- 1,000
Peterson acquisition, deferred tax liability
recorded .................................... 7,360 --
Suits acquisition with long-term debt
issued ...................................... 7,790 --
Suits acquisition with warrants granted ......... 411 --
Suits acquisition, deferred tax liability
recorded .................................... 6,460 --

<CAPTION>
Years Ended December 31,
----------------------------
1998 1997 1996
------ ------ ------
(in thousands)
<S> <C> <C> <C>
Cash Paid During the Period for:
Interest ........................................ $3,239 $3,523 $ 893
Income taxes .................................... 7,996 1,624 1,389
</TABLE>

12. STOCK PLANS

In December 1993, the Company established a Restricted Stock Plan and a
Non-Qualified Stock Option Plan. Under the Restricted Stock Plan,
150,000 shares of Common Stock were awarded to certain full-time
employees of the Company. Common Stock awarded under the Restricted
Stock Plan vests in five equal annual installments contingent upon the
beneficiaries' continued employment by the Company. As of December 31,
1998 all shares were vested.

Under the Non-Qualified Stock Option Plan, the Company awarded options
to senior management to purchase 1,459,800 shares of Common Stock with
an exercise price of $2.67 per share. The options vest in five equal
annual installments contingent upon continued employment by the
Company. On December 15, 1995, the options were repriced from $2.67 to
prices ranging from $1.77 (the fair market value on December 15, 1995)
to $2.13, depending upon the individual as well as the vesting date of
the option. In addition, the term of each option was reduced from ten
years from the original date of grant to five years from date of
repricing. As of December 31, 1998 options to purchase 530,920 shares
were exercisable and all option shares were vested.

F-17

<PAGE> 47

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12. STOCK PLANS (Continued)

In July 1996, the Company's shareholders approved the award of options
to purchase 360,000 shares of the Company's Common Stock at a price
equal to the fair market value of the stock at the date of grant to
REMY Investors and Consultants, Inc. ("Remy"). Remy is the general
partner of REMY Capital Partners III, L.P. which is an owner of 21.9%
of the Company's Common Stock. These options were vested at the grant
date and expire five years from the date of grant. The options were
awarded as a result of the services Remy rendered in connection with
the acquisition and related financing of FWA Drilling Company, Inc. and
the Company's sale of the assets of Union Supply Company. As of
December 31, 1998, options to purchase 78,000 shares were exercisable
and there were no unvested options.

In July 1996, the Company's shareholders approved the Non-Employee
Director Stock Option Plan (Director Plan), a non-qualified stock
option plan. Under the Director Plan, options to purchase up to an
aggregate of 300,000 shares of Common Stock of the Company may be
granted to non-employee directors of the Company. The Director Plan
provides for the grant of an option to purchase 7,500 shares of Common
Stock to each non-employee director as of December 19, 1995 and to each
future non-employee director as of the date he or she is first elected.
Options granted pursuant to the Director Plan stipulate that the
purchase price per share be equal to the fair market value of the
Common Stock as of the date of grant. Commencing on December 31, 1996,
each non-employee director who has served for a period of at least one
year will automatically be granted on each December 31 an option to
purchase 3,750 shares of Common Stock at a purchase price equal to the
fair market value of the Common Stock as of the date of grant. As of
December 31, 1998, options to purchase 52,500 shares of Common Stock
were exercisable and options to purchase 15,000 shares of Common Stock
were unvested. No options under this plan will be granted after
December 18, 2005. All options issued expire five years from the date
of grant with exercise prices ranging from $1.88 to $25.88.

In July 1996, the Company's shareholders approved the UTI Energy Corp.
1996 Employee Stock Option Plan. Under the plan, the Company can award
options of up to 900,000 shares of Common Stock to certain full-time
employees at a price equal to the fair market value of the stock at the
date the option is granted. Options to purchase 813,700 shares of
Common Stock have been awarded. On August 12, 1998, certain of the
options were repriced from $20.00 and $11.38 to $9.88 (the fair market
value on the date of repricing). As of December 31, 1998, options to
purchase 581,200 shares of Common Stock were exercisable and options to
purchase 125,000 shares of Common Stock were unvested. The options vest
from immediately to five years with exercise prices ranging from $4.58
to $9.88.

F-18

<PAGE> 48

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12. STOCK PLANS (Continued)

In August 1997, the Company's shareholders approved the UTI Energy
Corp. 1997 Long-Term Incentive Plan. Under the plan, the Company can
award options of up to 600,000 shares of Common Stock to certain
full-time employees at a price equal to the fair market value of the
stock at the date the option is granted. Under the plan, the Company
can also issue stock appreciation rights, restricted stock or
performance awards. On August 12, 1998, certain of the options were
repriced from $13.94, $16.25 and $31.63 to $9.88 (the fair market value
on the date of repricing). As of December 31, 1998, options to purchase
60,000 shares of Common Stock were exercisable and options to purchase
474,625 shares of Common Stock were unvested. The options vest from
immediately to five years with exercise prices ranging from $9.88 to
$16.25.

SFAS 123 requires that pro forma information regarding net income and
earnings per share be presented as if the Company had accounted for its
employee stock options under the fair value method as defined in that
Statement for options granted or modified after December 31, 1994. The
fair value for applicable options was estimated at the date of grant
using a Black-Scholes option pricing model with the following
weighted-average assumptions for 1998, 1997 and 1996, respectively:
risk-free interest rates of 4.91%, 5.11%, and 6.70%; dividend yield of
0%; volatility factors of the expected market price of the Company's
Common Stock of .669, .529 and .438 and a weighted average expected
life of the option of 3.20, 2.60 and 3.52 years.

The Black-Scholes option valuation model was developed for use in
estimating the fair value of traded options which have no vesting
restrictions and are fully transferable. In addition, option valuation
models require the input of highly subjective assumptions including the
expected stock price volatility. Because the Company's employee stock
options have characteristics significantly different from those of
traded options and because changes in the subjective input assumptions
can materially affect the fair value estimate, in management's opinion,
the existing models do not necessarily provide a reliable single
measure of the fair value of its employee stock options.

F-19

<PAGE> 49

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12. STOCK PLANS (Continued)

For purposes of pro forma disclosures, the estimated fair value of the
options is amortized to expense over the options' vesting period. The
Company's pro forma information follows:

<TABLE>
<CAPTION>
Years Ended December 31,
----------------------------------------
1998 1997 1996
---------- ---------- ----------
(in thousands, except per share amounts)

<S> <C> <C> <C>
Pro forma net income ............. $ 5,105 $ 10,359 $ 4,739

Pro forma earnings per share:
Basic ............................ $ 0.32 $ 0.79 $ 0.45
Diluted .......................... $ 0.30 $ 0.69 $ 0.41
</TABLE>

A summary of the Company's stock option activity and related
information for the years ended December 31 follows:

Shares Under Weighted-Average
Option Exercise Price
------------ ----------------
<S> <C> <C>
Outstanding, December 31, 1995 ... 1,842,300 $ 2.09
Granted .......................... 296,250 4.86
Exercised ........................ (408,342) 2.54
Canceled ......................... (160,578) 2.67
---------

Outstanding, December 31, 1996 ... 1,569,630 2.43
Granted .......................... 997,825 21.22
Exercised ........................ (592,980) 2.02
---------

Outstanding, December 31, 1997 ... 1,974,475 12.05
Granted .......................... 1,006,375 10.51
Exercised ........................ (156,480) 4.33
Canceled ......................... (907,125) 22.17
---------

Outstanding, December 31, 1998 ... 1,917,245 $ 7.05
=========

Exercisable, December 31,
1995 ....................... 1,133,700 $ 2.12
1996 ....................... 923,040 $ 1.88
1997 ....................... 1,123,172 $ 7.85
1998 ....................... 1,302,620 $ 5.45
</TABLE>

F-20

<PAGE> 50

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

12. STOCK PLANS (Continued)

Weighted-average fair value of options granted during 1998, 1997 and
1996 were $5.12, $8.72 and $1.86 per share, respectively.

Exercise price for options outstanding as of December 31, 1998, ranged
from $1.77 per share to $25.88 per share. The weighted-average
remaining contractual life of those options is 3.34 years.

13. DEFINED CONTRIBUTION PLANS

The Company maintained two defined contribution plans which were
merged January 1, 1997. Employees who have completed one year of
service (1,000 active work hours) and are age 21 or older are eligible
to participate. The Company matches $.50 for each dollar contributed
by the employee up to 4% of the employee's total annual compensation.
The Company may make an additional discretionary contribution. For the
years ended December 31, 1998, 1997 and 1996, the Company made
matching contributions totaling approximately $298,000, $396,000 and
$406,000, respectively.

14. FINANCIAL INSTRUMENTS

Financial instruments that potentially subject the Company to
significant concentrations of credit risk consist principally of cash
and cash equivalents and trade accounts receivable. The Company
performs ongoing credit evaluations of its customers and generally
does not require material collateral. The Company provides allowances
for potential credit losses when necessary.

The Company maintains cash balances with various financial
institutions. These financial institutions are located throughout the
country and Company policy is designed to limit exposure to any one
institution. However, at December 31, 1998, the Company had 64% of its
cash and cash equivalents in one institution. The Company performs
periodic evaluations of the relative credit standing of those
financial institutions that are considered in the Company's investment
strategy to ensure high credit quality.

Cash and cash equivalents, accounts receivable and accounts payable:
The carrying amounts reported in the balance sheets approximate fair
value.

Long-term debt: The carrying amounts included in the balance sheets of
the Company's borrowings under its revolving bank credit arrangements
and promissory notes approximate fair value. The fair value of the
subordinated notes are estimated to be $33.0 million versus its
carrying value of $31.7 million. The fair value was estimated by
management based upon estimates of current interest rates available to
the Company at the balance sheet date for similar issues.

F-21

<PAGE> 51

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

15. INDUSTRY SEGMENT INFORMATION

The Company has two reportable segments: land drilling and pressure
pumping. The Company's reportable segments are business units that
offer different services.

The Company evaluates performance and allocates resources based on
profit or loss from operations before other income (expense) and
income taxes. The accounting policies of the reportable segments are
the same as those described in the summary of significant accounting
policies.

The other category in the segment breakdown is attributable to
investments in oil and gas properties. This segment has not met the
quantitative thresholds for determining reportable segments. There are
no intersegment sales and transfers.

<TABLE>
<CAPTION>
Years Ended
December 31,
--------------------------------------
1998 1997 1996
--------- --------- --------
(in thousands)
<S> <C> <C> <C>
Revenues
--------
Land Drilling.................... $ 162,600 $ 161,265 $ 81,534
Pressure Pumping................. 23,365 20,923 15,484
Other............................ 192 249 283
--------- --------- --------
$ 186,157 $ 182,437 $ 97,301
========= ========= ========

Selling, General and Administrative
-----------------------------------
Land Drilling ................... $ 5,048 $ 5,097 $ 2,846
Pressure Pumping................. 3,611 3,197 2,874
Other ........................... -- -- --
--------- --------- --------
8,659 8,294 5,720
Corporate ....................... 3,185 2,860 1,907
--------- --------- --------
$ 11,844 $ 11,154 $ 7,627
========= ========= ========

Operating Income (Loss)
-----------------------
Land Drilling (1) ............... $ 13,915 $ 21,499 $ 7,483
Pressure Pumping (1)............. 5,098 4,540 1,539
Other (1) ....................... 19 91 (99)
--------- --------- --------
19,032 26,130 8,923
Other Charge .................... (785) -- --
Corporate ....................... (3,263) (2,901) (1,939)
--------- --------- --------
$ 14,984 $ 23,229 $ 6,984
========= ========= ========

Depreciation and Amortization
-----------------------------
Land Drilling ................... $ 18,350 $ 10,252 $ 3,519
Pressure Pumping ................ 1,043 728 690
Other ........................... 58 54 51
--------- --------- --------
19,451 11,034 4,260
Corporate ....................... 78 41 32
--------- --------- --------
$ 19,529 $ 11,075 $ 4,292
========= ========= ========
</TABLE>

F-22

<PAGE> 52

UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

15. INDUSTRY SEGMENT INFORMATION (Continued)

<TABLE>
<CAPTION>
Years Ended
December 31,
------------------------------
1998 1997 1996
------- ------- ------
(in thousands)
<S> <C> <C> <C>
Capital Expenditures
--------------------
Land Drilling..................... $32,912 $16,282 $3,383
Pressure Pumping.................. 3,895 1,676 724
Other............................. 50 136 138
------- ------- ------
36,857 18,094 4,245
Corporate......................... 572 262 66
------- ------- ------
$37,429 $18,356 $4,311
======= ======= ======

<CAPTION>
December 31, December 31,
1998 1997
-------- --------
(in thousands)
<S> <C> <C>
Segment Assets
--------------
Land Drilling..................... $204,283 $142,903
Pressure Pumping.................. 14,799 11,553
Other............................. 404 413
-------- --------
219,846 154,869
Corporate 12,581 54,118
-------- --------
$232,067 $208,987
======== ========
</TABLE>

- ---------------------
(1) Operating income is total operating revenues less operating expenses,
depreciation and amortization and does not include general corporate
expenses, other charge, interest or income taxes.

In 1998, revenues from one customer of the Company's land drilling
segment (Anadarko Petroleum Corp.) represented approximately 11% of
consolidated revenue and approximately 10% of total accounts
receivable at December 31, 1998. In 1997, revenues from one customer
of the Company's land drilling segment (Pioneer Natural Resources)
accounted for approximately 18% of consolidated revenue.

F-23

<PAGE> 53
UTI ENERGY CORP.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

16. SELECTED QUARTERLY FINANCIAL RESULTS (UNAUDITED)

Quarterly financial information for the years ended December 31, 1998,
1997 and 1996 is as follows:

<TABLE>
<CAPTION>
1st Qtr 2nd Qtr 3rd Qtr 4th Qtr Total
--------- --------- --------- --------- ---------
(in thousands, except per share amounts)

<S> <C> <C> <C> <C> <C>
1998
----
Revenues ........................... $ 48,317 $ 48,403 $ 48,690 $ 40,747 $186,157
Gross Profit ....................... 13,364 13,391 12,977 8,553 48,285
Net Income (Loss) .................. 3,547 3,102 1,624 (405) 7,868

Earnings (Deficit) Per Share
Basic .............................. 0.22 0.19 0.10 (0.03) 0.49
Diluted ............................ 0.21 0.18 0.10 (0.02) 0.47

1997
----
Revenues ........................... $ 34,368 $ 42,440 $ 50,310 $ 55,319 $182,437
Gross Profit ....................... 7,006 9,340 13,502 16,233 46,081
Net Income ......................... 1,844 1,777 3,894 5,010 12,525

Earnings Per Share
Basic .............................. $ 0.16 $ 0.15 $ 0.31 $ 0.30 $ 0.96
Diluted ............................ $ 0.14 $ 0.13 $ 0.26 $ 0.28 $ 0.83

1996
----
Revenues ........................... $ 20,406 $ 19,659 $ 26,269 $ 30,967 $ 97,301
Gross Profit ....................... 3,837 3,526 5,425 6,256 19,044
Net Income ......................... 1,200 481 1,610 1,562 4,853

Earnings Per Share
Basic .............................. 0.12 0.05 0.15 0.15 0.46
Diluted ............................ 0.12 0.04 0.14 0.13 0.42
</TABLE>

17. SUBSEQUENT EVENT

During March 1999, the Company sold the drilling assets of its
Pennsylvania-based subsidiary for $5.6 million in cash resulting in a
net gain of approximately $2.7 million. Included in the transaction
were five drilling rigs as well as related support equipment, including
rolling stock, spare parts, tools and inventory.

F-24

<PAGE> 54

UTI ENERGY CORP.
SCHEDULE II--VALUATION AND QUALIFYING ACCOUNTS

<TABLE>
<CAPTION>
Balance at Balance
Beginning at End
Description of Period Additions(1) Deductions of Period
- ----------- --------- ------------ ---------- ---------
(in thousands)
<S> <C> <C> <C> <C>
Year Ended December 31, 1998
Deducted from asset accounts:
Allowance for doubtful
accounts ..................... $ 815 $1,143 $ 39(2) $1,919
====== ====== ====== ======

Year Ended December 31, 1997
Deducted from asset accounts:
Allowance for doubtful
accounts ..................... $ 305 $ 623 $ 113(2) $ 815
====== ====== ====== ======

Year Ended December 31, 1996
Deducted from asset accounts:
Allowance for doubtful
accounts ..................... $ 193 $ 141 $ 29(2) $ 305
====== ====== ====== ======
</TABLE>

(1) Net of recoveries.
(2) Uncollectible accounts written off.

S-1

<PAGE> 55

SIGNATURES

Pursuant to the requirements of Section 13 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.

UTI ENERGY CORP.

By: /s/ VAUGHN E. DRUM
------------------------------
Vaughn E. Drum, President,
Chief Executive Officer and Director

Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following persons on behalf of the registrant and
in the capacities and on the dates indicated.

<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
--------- ----- ----

/s/ MARK S. SIEGEL Chairman and Director March 30, 1999
- ----------------------------------- --------------
Mark S. Siegel

/s/ VAUGHN E. DRUM President, Chief Executive Officer March 29, 1999
- ----------------------------------- and Director --------------
Vaughn E. Drum

/s/ JOHN E. VOLLMER III Vice President, Treasurer and March 30, 1999
- ----------------------------------- Chief Financial Officer --------------
John E. Vollmer III

/s/ BRUCE SAUERS Vice President and March 30, 1999
- ----------------------------------- Chief Accounting Officer --------------
Bruce Sauers

/s/ KENNETH N. BERNS Director March 29, 1999
- ----------------------------------- --------------
Kenneth N. Berns

/s/ CURTIS W. HUFF Director March 30, 1999
- ----------------------------------- --------------
Curtis W. Huff

/s/ TERRY H. HUNT Director March 29, 1999
- ----------------------------------- --------------
Terry H. Hunt

/s/ NADINE C. SMITH Director March 30, 1999
- ----------------------------------- --------------
Nadine C. Smith

/s/ ROBERT B. SPEARS Director March 29, 1999
- ----------------------------------- --------------
Robert B. Spears
</TABLE>

<PAGE> 56
EXHIBIT INDEX

<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
3.1 - Restated Certificate of Incorporation of the Company (incorporated by reference to
Amendment No. 1 to the Company's Registration Statement on Form S-1 (No. 33-69726)).

3.2 - Amendment to Restated Certificate of Incorporation (incorporated by reference to Amendment
No. 1 to the Company's Registration Statement on Form S-1 (No. 33-69726)).

3.3 - Amendment to Restated Certificate of Incorporation (incorporated by reference to the
Company's Annual Report on Form 10-K for the year ended December 31, 1994).

3.4 - Amendment to Restated Certificate of Incorporation, dated August 28, 1997, (incorporated
by reference to Exhibit 3.4 to the Company's Registration Statement on Form S-3 (No.
333-35109)).

3.5 - By-laws of the Company, as amended (incorporated by reference to Exhibit 3.3 to the
Company's Annual Report on Form 10-K for the year ended December 31, 1993).

<PAGE> 57
<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

<S> <C>
4.1 - See Exhibit No. 3.1 through 3.8 for provisions of the Restated Certificate of
Incorporation and amended By-laws of the Company defining the rights of the holders of
Common Stock.

4.2 - Form of Common Stock Certificate (incorporated by reference to Amendment No. 1 to the
Company's Registration Statement on Form S-1 (No. 33-69726)).

<PAGE> 58
<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

4.12 - 1993 Restricted Stock Plan (incorporated by reference to Amendment No. 1 to the Company's
Registration Statement on Form S-1 (No. 33-69726)).

4.14 - 1993 Non-Qualified Incentive Stock Option Plan (incorporated by reference to Amendment No.
3 to the Company's Registration Statement on Form S-1 (No. 33-69726)).

4.15 - Amended and Restated 1997 Long-Term Incentive Plan (incorporated by reference to Exhibit
4.2 to the Company's Annual Report on Form 10-K for the year ended December 31, 1997).

<PAGE> 59

<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

10.1 - For additional material contracts see Exhibits 4.3 through 4.22.
</TABLE>

<PAGE> 60

<TABLE>
<CAPTION>
EXHIBIT
NUMBER TITLE OR DESCRIPTION
------ --------------------

*21.1 - List of subsidiaries of the Company.

*23.1 - Consent of Ernst & Young LLP.

*27 - Financial Data Schedule.
</TABLE>

*Filed herewith.

<PAGE> 1

EXHIBIT 21.1

UTI ENERGY CORP.

LIST OF SUBSIDIARIES

UTICO, Inc. Delaware Corporation
SUITS Drilling Company Oklahoma Corporation
UTI Management Services, L.P. Texas Limited Partnership
UTI Drilling, L.P. Texas Limited Partnership
UTICO Hard Rock Boring, Inc. Delaware Corporation
International Petroleum Service Company Pennsylvania Corporation
Universal Well Services, Inc. Delaware Corporation

<PAGE> 1

EXHIBIT 23.1

CONSENT OF INDEPENDENT AUDITORS

We consent to the incorporation by reference in the Registration Statement (Form
S-8 No. 333-62853) pertaining to the UTI Energy Corp. Amended and Restated 1997
Long-Term Incentive Plan and to the incorporation by reference in the
Registration Statement (Form S-8 No. 333-13261) pertaining to the UTI Energy
Corp. 1993 Non-Qualified Stock Option Plan, the First Amendment to Termination
Agreement and Release, the UTI Energy Corp. 1996 Employee Stock Option Plan and
the UTI Energy Corp. Non-Employee Director Stock Option Plan of our report dated
February 18, 1999, with respect to consolidated financial statements and
schedule of UTI Energy Corp. included in the Annual Report (Form 10-K) for the
year ended December 31, 1998.

Ernst & Young LLP

Houston, Texas
March 29, 1999

<ARTICLE> 5
<MULTIPLIER> 1,000

<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-START> JAN-01-1998
<PERIOD-END> DEC-31-1998
<CASH> 10,337
<SECURITIES> 0
<RECEIVABLES> 27,404
<ALLOWANCES> 1,919
<INVENTORY> 887
<CURRENT-ASSETS> 44,557
<PP&E> 211,918
<DEPRECIATION> 47,070
<TOTAL-ASSETS> 232,067
<CURRENT-LIABILITIES> 23,919
<BONDS> 31,721
0
0
<COMMON> 17
<OTHER-SE> 144,129
<TOTAL-LIABILITY-AND-EQUITY> 232,067
<SALES> 0
<TOTAL-REVENUES> 186,157
<CGS> 0
<TOTAL-COSTS> 137,872
<OTHER-EXPENSES> 19,529
<LOSS-PROVISION> 1,143
<INTEREST-EXPENSE> 3,815
<INCOME-PRETAX> 13,103
<INCOME-TAX> 5,235
<INCOME-CONTINUING> 7,868
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 7,868
<EPS-PRIMARY> 0.49
<EPS-DILUTED> 0.47

</TABLE>