SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
Date of Report (Date of earliest event report): February 11, 1997
DEVON ENERGY CORPORATION
(Exact Name of Registrant as Specified in its Charter)
OKLAHOMA 1-10067 73-1474008
(State or Other Jurisdiction (Commission File (I.R.S. Employer
of Incorporation or Number) Identification Number)
Organization
20 NORTH BROADWAY, SUITE 1500, OKLAHOMA CITY, OK 73102
(Address of Principal Executive Offices) (Zip Code)
Registrant's telephone number, including area code: (405) 235-3611
Page 1 of 6 total pages
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ITEM 5. OTHER EVENTS
1997 Estimates
The forward-looking statements provided in this discussion
are based on management's examination of historical operating
trends, the December 31, 1996 reserve reports of independent
petroleum consultants LaRoche & Associates and AMH Group Ltd.,
data in Devon's files and other data available from third
parties. Devon cautions that its future oil, gas and natural gas
liquids ("NGL") production, revenues and expenses are subject to
all of the risks and uncertainties normally incident to the
exploration for and development and production of oil and gas.
These risks include, but are not limited to, environmental risks,
drilling risks, regulatory changes, the uncertainty inherent in
estimating future oil and gas production or reserves, and other
risks as outlined below. The scope of Devon's operations
increased significantly with the December 31, 1996, acquisition
of Kerr-McGee Corporation's North American onshore oil and gas
exploration and production business and properties (the "KMG-NAOS
Properties") in exchange for 9,954,000 shares of Devon common
stock. This increases the margin of error inherent in estimating
Devon's 1997 production volumes, prices and expenses. Also, the
financial results for Devon's new Canadian operations, obtained
in the KMG-NAOS Properties transaction, are subject to currency
exchange rate risks.
Assumptions and Risks for Price and Production Estimates
Prices for oil, natural gas and NGLs are determined primarily by
prevailing market conditions. Market conditions for these
products are influenced by regional and world-wide economic
growth, weather and other substantially variable factors. These
factors are beyond Devon's control and are difficult to predict.
Over 90% of Devon's revenues are attributable to sales of these
three commodities. Consequently, the company's financial results
and resources are highly influenced by this price volatility.
Estimates for Devon's future production of oil, natural gas
and NGLs are based on the assumption that market demand and
prices for oil and gas will continue at levels that allow for
profitable production of these products. Although Devon's
management believes these assumptions to be reasonable, there can
be no assurance of such stability.
Certain of Devon's individual oil and gas properties are
sufficiently significant as to have a material impact on the
company's overall financial results. With respect to oil
production, these properties include the West Red Lake Field and
the Grayburg-Jackson Unit, both in southeast New Mexico. The
company's interest in the Northeast Blanco Unit ("NEBU") and the
32-9 Unit can have a substantive effect on overall gas
production.
The production, transportation and marketing of oil, natural
gas and NGLs are complex processes which are subject to
disruption due to transportation and processing availability,
mechanical failure, human error, meteorological events and
numerous other factors. The following forward-looking statements
were prepared assuming demand, curtailment, producibility and
general market conditions for Devon's oil, natural gas and NGLs
for 1997 will be substantially similar to those of 1996, unless
otherwise noted. Given the general limitations expressed herein,
Devon's forward-looking statements for 1997 are set forth below.
Oil Production and Relative Prices
Devon expects its oil production in 1997 to total between 5.9 million
barrels and 6.9 million barrels. Devon expects its net oil prices will
average from between $0.05 below to $0.20 above West Texas Intermediate
posted prices in 1997.
Gas Production and Relative Prices
Devon expects its total gas production in 1997 will be between
64.0 billion cubic feet ("Bcf") and 75.0 Bcf. It is expected that
coal seam gas production will be 16.5 Bcf to 19.5 Bcf. Canadian production
in 1997 is estimated to be between 7.0 Bcf and 8.0 Bcf. Devon
expects production from the remainder of its gas properties to
total between 40.5 Bcf and 47.5 Bcf.
Devon expects its 1997 coal seam average price will be
between $0.25 and $0.55 less than Texas Gulf Coast spot averages.
This includes an expected $0.55 per thousand cubic feet ("Mcf")
from the 1995 transaction covering substantially all of its San
Juan Basin coal seam gas properties (the "San Juan Basin
Transaction"). Devon's Canadian gas production is expected to
average from between $0.85 to $1.20 less than Texas Gulf Coast
spot prices. (These Canadian differentials are expressed in U.S.
dollars, using the year-end 1996 exchange rate of $0.73 U.S.
dollar to $1.00 Canadian dollar.) Devon's remaining gas
production is expected to average $0.05 to $0.25 less than Texas
Gulf Coast spot prices during 1997.
NGL Production
Devon expects its production of NGLs in 1997 to total between
1.1 million barrels and 1.3 million barrels.
Production and Operating Expenses
Devon's production and operating expenses vary in response
to several factors. Among the most significant of these factors are
additions or deletions to the company's property base, changes in
production taxes, general changes in the prices of services and materials
that are used in the operation of the company's properties and the amount of
repair and workover activity required on the company's properties.
The addition of the KMG-NAOS Properties is expected to be
the largest contributor to an increase in recurring lease
operating expenses in 1997. The additional revenues contributed
by these properties should also cause production taxes to rise.
In addition, well workover expenses are anticipated to increase
in 1997.
Oil, gas and NGL prices will have a direct effect on
production taxes to be incurred in 1997. Future prices could
also have an effect on whether proposed workover projects are
economically feasible. These factors, coupled with the
uncertainty of future oil, gas and NGL prices, increase the
margin of error inherent in estimating future production and
operating costs. Given these uncertainties, Devon estimates that
1997's total production and operating costs will be between $75
million and $87 million.
Depreciation, Depletion and Amortization ("DD&A")
The 1997 DD&A rate will depend on various factors. Most notable among
such factors are the amount of proved reserves that could be
added from drilling or acquisition efforts in 1997 compared to
the costs incurred for such efforts, and the revisions to Devon's
year-end 1996 reserve estimates which will be made during 1997.
The DD&A rate as of the beginning of 1997 was $3.76 per
barrel of oil equivalent ("Boe"). This rate includes the effect
of the December 31, 1996, acquisition of the KMG-NAOS Properties.
Conversely, the 1996 yearly rate of $3.88 per Boe did not reflect
the effect of these properties. Assuming a 1997 rate of between
$3.80 per Boe and $4.20 per Boe, 1997 DD&A expense (including
approximately $2.5 million of non-oil and gas property related
DD&A) is expected to be $76 million to $84 million.
General and Administrative Expenses ("G&A")
Devon's general and administrative expenses include the costs
of many different goods and services used in support of the company's
business. These goods and services are subject to general price level
increases or decreases. In addition, Devon's G&A expenses vary
with the company's level of activity and the related staffing
needs as well as with the amount of professional services
required during any given period. The addition of the KMG-NAOS
Properties will increase Devon's general level of activity as
well as its staffing requirements during 1997. Should the
company's anticipated needs or the prices of the required goods
and services differ significantly from the company's
expectations, actual G&A expenses could vary materially from the
estimate. Given these limitations, G&A expenses are expected to
be between $12 million and $14 million in 1997.
Interest Expense
Devon's management expects to fund substantially all of its
anticipated expenditures during 1997 with working capital and
internally generated cash flow. Should Devon's actual capital expenditures
or internally generated cash flow vary significantly from expectations,
interest expense could differ materially from the following estimate.
Given this limitation, interest expense is expected to be less than $1
million in 1997.
Distributions on 6.5% Trust Convertible Preferred Securities
("TCP Securities")
TCP Securities are convertible into common shares of Devon at the
option of the holder. Should any of the holders of the TCP Securities
elect to convert during 1997, it would reduce the amount of required
distributions. Assuming all $149.5 million of TCP Securities are
outstanding for the entire year, Devon will make $9.7 million of
distributions in 1997.
Income Taxes
Devon expects its financial income tax rate in
1997 to be between 38% and 42%. Regardless of the level of pre-
tax earnings reported for financial purposes, Devon will have a
minimum of approximately $2.5 million of financial income tax
expense due to various aspects of the May, 1994 acquisition of
Alta Energy Corporation, the San Juan Basin Transaction and the
KMG-NAOS Properties acquisition. Therefore, if the actual amount
of 1997 pre-tax earnings differs materially from what Devon
currently expects, the actual financial income tax rate for 1997
could fall outside of the expected rate of 38% to 42%. Also,
based on its current expectations of 1997 taxable income, Devon
anticipates its current portion of 1997 income taxes will be
between $9 million and $13 million. However, revenue and
earnings fluctuations could easily make these tax estimates
obsolete.
Capital Expenditures
Devon's capital expenditures budget is based on an expected
range of future oil, natural gas and NGL prices as well as the expected
costs of the capital additions. Should the company's price expectations
for its future production change significantly, the company may accelerate
or defer some projects. Thus, Devon would increase or decrease total 1997
capital expenditures. In addition, if the actual cost of the
budgeted items varies significantly from the amount anticipated,
actual capital expenditures could vary materially from Devon's
estimate.
Though Devon has completed at least one major acquisition in
each of the last several years, these transactions are
opportunity driven. Thus, Devon does not "budget", nor can it
reasonably predict, the timing or size of such possible
acquisitions, if any.
Given these limitations, Devon expects its 1997 capital
expenditures for drilling and development efforts to total
between $120 million and $135 million. This range includes $8
million to $11 million of capital expenditures in Canada.
(Canadian amounts are expressed in U.S. dollars, using the year-
end 1996 exchange rate of $0.73 U.S. dollar to $1.00 Canadian
dollar.) Devon expects to spend $50 million to $65 million in
1997 for drilling, facilities and waterflood costs related to
reserves classified as proved as of year-end 1996. Devon also
plans to spend another $15 million to $20 million on new, higher
risk/reward projects.
Other Cash Uses
Devon's management expects the policy of paying a quarterly
dividend to continue. With the current $0.05 per share quarterly
dividend rate and 32.1 million shares of common stock outstanding,
1997 dividends are expected to approximate $6.4 million.
Capital Resources and Liquidity
The estimated future drilling and development activities are
expected to be funded through a combination of working capital and
net cash provided by operations. The amount of net cash to be provided
by operating activities in 1997 is uncertain due to the factors affecting
revenues and expenses cited above. However, Devon considers its
capital resources to be more than adequate to fund its
anticipated capital expenditures.
Based on the expected level of 1997's capital expenditures
and net cash provided by operations, Devon does not expect to
rely on its credit lines to fund a material portion of its
capital expenditures. However, if significant acquisitions or
other unplanned capital requirements arise during the year, Devon
could utilize its credit lines. The unused portion of these
credit lines at the end of 1996 consisted of $252 million of long-
term credit facilities, and a $12.5 million (Canadian dollars)
demand facility for Devon's new Canadian operations. If so
desired, Devon believes that its lenders would increase its
credit lines to at least $450 to $500 million. However, the
company does not desire nor anticipate a need to increase its
credit lines above their current levels. In fact, to lower its
borrowing costs, Devon may reduce its credit lines in 1997 until
a need for significant capital arises.
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SIGNATURES
Pursuant to the requirements of the Securities and Exchange
Act of 1934, the registrant has duly caused this report to be
signed on its behalf by the undersigned hereto duly authorized.
Devon Energy Corporation
By: Danny J. Heatly
Danny J. Heatly
Controller
Date: February 11, 1997
