FORM 10-K
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
(Mark One)
[x] Annual report pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934 [Fee Required]
For the fiscal year ended December 31, 1997
OR
[ ] Transition report pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934 [No Fee Required]
For the transition period from to
Commission File Number 33-38511
Southwest Developmental Drilling Fund 92-A, L.P.
(Exact name of registrant as specified in
its limited partnership agreement)
Delaware 75-2387816
(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
407 N. Big Spring, Suite 300, Midland, Texas 79701
(Address of principal executive office) (Zip Code)
Registrant's telephone number, including area code (915) 686-9927
Securities registered pursuant to Section 12(b) of the Act:
None
Securities registered pursuant to Section 12(g) of the Act:
limited and general partner interests
Indicate by check mark whether registrant (1) has filed reports required to
be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934
during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to
such filing requirements for the past 90 days: Yes x No
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K (229.405 of this chapter) is not contained herein,
and will not be contained, to the best of registrant's knowledge, in
definitive proxy or information statements incorporated by reference in
Part III of this Form 10-K or any amendment to this Form 10-K. [x]
The registrant's outstanding securities consist of Units of limited
partnership interests for which there exists no established public market
from which to base a calculation of Aggregate market value.
The total number of pages contained in this report is 40. There is no
exhibit index.
<PAGE>
Table of Contents
Item Page
Part I
1. Business 3
2. Properties 6
3. Legal Proceedings 8
4. Submission of Matters to a Vote of Security Holders 8
Part II
5. Market for Registrant's Common Equity and Related
Stockholder Matters 9
6. Selected Financial Data 10
7. Management's Discussion and Analysis of
Financial Condition and Results of Operations 11
8. Financial Statements and Supplementary Data 18
9. Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure 35
Part III
10. Directors and Executive Officers of the Registrant 36
11. Executive Compensation 39
12. Security Ownership of Certain Beneficial Owners and
Management 39
13. Certain Relationships and Related Transactions 39
Part IV
14. Exhibits, Financial Statement Schedules, and Reports
on Form 8-K 40
Signatures 42
<PAGE>
Part I
Item 1. Business
General
Southwest Developmental Drilling Fund 92-A, L.P. (the "Partnership" or
"Registrant") was organized as a Delaware limited partnership on May 5,
1992. The offering of limited and general partner interests began August
11, 1992 as part of a shelf offering registered under the name Southwest
Developmental Drilling Program 1991-92. Minimum capital requirements for
the Partnership were met on December 28, 1992, with the offering of limited
and general partner interests concluding December 31, 1992, with total
investor partner contributions of $1,407,000. The Managing General Partner
made a contribution to the capital of the Partnership at the conclusion of
the offering period in an amount equal to 1% of its net capital
contributions. The Managing General Partner contribution was $12,030, for
total capital contributions of $1,419,030. The Partnership has no
subsidiaries.
The Partnership has expended its capital and acquired leasehold interests
and completed drilling operations. The Partnership has produced and
marketed the crude oil and natural gas from such properties.
The principal executive offices of the Partnership are located at 407 N.
Big Spring, Suite 300, Midland, Texas, 79701. The Managing General Partner
of the Partnership, Southwest Royalties, Inc. (the "Managing General
Partner") and its staff of 130 individuals, together with certain
independent consultants used on an "as needed" basis, perform various
services on behalf of the Partnership, including the selection of leasehold
interests upon which drilling would be performed, and the marketing of
future anticipated production from such properties. The Partnership has no
employees.
Principal Products, Marketing and Distribution
The Partnership has acquired undeveloped leasehold interests and drilled
oil and gas properties located in Texas and New Mexico. All activities of
the Partnership are confined to the continental United States. All oil and
gas produced from these properties will be sold to unrelated third parties
in the oil and gas business.
The revenues generated from the Partnership's oil and gas activities are
dependent upon the current market for oil and gas. The prices received by
the Partnership for its oil and gas production depend upon numerous factors
beyond the Partnership's control, including competition, economic,
political and regulatory developments and competitive energy sources, and
make it particularly difficult to estimate future prices of oil and natural
gas.
<PAGE>
1997 was another volatile year in the oil market. Prices ranged from a
high of approximately $26 in the first quarter to a low near $18 per
barrel. Two contributing factors that influence the oil industry are the
strength of the economy and activity in the Middle East. Both influenced
the supply and demand of oil, and both played roles in price swings this
year. Economic expansion throughout the world enabled consumption to
surpass 70 million barrels of oil per day. However, early in the year,
producing countries failed to make up the difference in supply, placing
upward pressure on prices. U.S. production fell slightly in 1997 to
average roughly 6.4 million barrels of oil per day. Over the Thanksgiving
weekend, OPEC agreed to increase their crude oil production ceiling by
approximately 10%, but experts have said that many OPEC countries were
already producing beyond their quotas, therefore, capacity is not expected
to expand severely. Then on December 4th, the UN Security Council approved
a renewal of the Iraqi oil-for-food program. The OPEC agreement and the
UN's decision on the oil-for-food program will certainly increase the world
supply of oil and most likely depress prices in the near term. However,
world demand is expected to continue with strong growth in 1998.
The December 31, 1997 NYMEX oil price of $17.64 dropped to $14.32 as of
March 18, 1998. The price decline in the first quarter of 1998 could cause
a material write down in oil and gas properties and a possible reduction in
future distributions to investors.
Overall the 1997 average price of natural gas increased nationwide from the
1996 rates. In some areas the increase was as high as 15%. The 1996 and
1997 average prices are by far the highest realized by the industry since
1985. The 1998 average price is expected to remain above the $2.00 per
MMBTU level, however some early signs indicate that the prices will be
softer in 1998 than they were in 1997. Forecasts for a mild winter and the
lack of gas storage withdrawals are fueling speculation that the U.S. has
an excess supply of gas thus driving the prices down to the early 1996
levels.
Following is a table of the ratios of revenues received from oil and gas
production for the last three years:
Oil Gas
1997 76% 24%
1996 76% 24%
1995 75% 25%
As the table indicates, the majority of the Partnership's revenue is from
its oil production; therefore, Partnership revenues will be highly
dependent upon the future prices and demands of oil.
Seasonality of Business
Although the demand for natural gas is highly seasonal, with higher demand
in the colder winter months and in very hot summer months, the Partnership
anticipates that it will be able to sell all of the expected future
production of natural gas, either through contracts or on the spot market
at the then prevailing spot market price.
<PAGE>
Customer Dependence
No material portion of the Partnership's business is dependent on a single
purchaser, or a very few purchaser, where the loss of one would have a
material adverse impact on the Partnership. Three purchasers accounted for
94% of the Partnership's total oil and gas production during 1997: Scurlock
Permian Corporation 60%, Aquila Southwest Pipeline Corporation 19% and
Navajo Refining Company, Inc. 15%. Three purchasers accounted for 96% of
the partnership's total oil and gas production during 1996: Scurlock
Permian Corporation 60%, Aquila Southwest Pipeline Corporation 19% and
Navajo Refining Company Inc. 17%. Three purchasers, Scurlock Permian
Corporation, Aquila Southwest Pipeline Corporation and Navajo Refining
Company, accounted for 60%, 20% and 17%, respectively, of the Partnership's
total oil and gas production during 1995. All purchasers of the
Partnership's oil and gas production are unrelated third parties. In the
event this purchaser were to discontinue purchasing the Partnership's
production, the Managing General Partner believes that a substitute
purchaser or purchasers could be located without undue delay. No other
purchaser accounted for an amount equal to or greater than 10% of the
Partnership's total oil and gas production.
Competition
Because the Partnership has utilized all of its funds available for the
acquisition of drilling prospects and drilling activities, it is not
subject to competition from other oil and gas property purchasers. See
Item 2, Properties.
Factors that may adversely affect the Partnership include delays in
completing arrangements for the sale of production, availability of a
market for production, rising operating costs of producing oil and gas and
complying with applicable water and air pollution control statutes,
increasing costs and difficulties of transportation, and marketing of
competitive fuels. Moreover, domestic oil and gas must compete with
imported oil and gas and with coal, atomic energy, hydroelectric power and
other forms of energy.
Regulation
Oil and Gas Production - The production and sale of oil and gas is subject
to federal and state governmental regulation in several respects, such as
existing price controls on natural gas and possible price controls on crude
oil, regulation of oil and gas production by state and local governmental
agencies, pollution and environmental controls and various other direct and
indirect regulation. Many jurisdictions have periodically imposed
limitations on oil and gas production by restricting the rate of flow for
oil and gas wells below their actual capacity to produce and by imposing
acreage limitations for the drilling of wells. The federal government has
the power to permit increases in the amount of oil imported from other
countries and to impose pollution control measures.
<PAGE>
Various aspects of the Partnership's oil and gas activities are regulated
by administrative agencies under statutory provisions of the states where
such activities are conducted and by certain agencies of the federal
government for operations on Federal leases. Moreover, certain prices at
which the Partnership may sell its future expected natural gas production
are controlled by the Natural Gas Policy Act of 1978, the Natural Gas
Wellhead Decontrol Act of 1989 and the regulations promulgated by the
Federal Energy Regulatory Commission.
Environmental - The Partnership's oil and gas activities are subject to
extensive federal, state and local laws and regulations governing the
generation, storage, handling, emission, transportation and discharge of
materials into the environment. Governmental authorities have the power to
enforce compliance with their regulations, and violations carry substantial
penalties. This regulatory burden on the oil and gas industry increases
its cost of doing business and consequently affects its profitability. The
Managing General Partner is unable to predict what, if any, effect
compliance will have on the Partnership.
Industry Regulations and Guidelines - Certain industry regulations and
guidelines apply to the registration, qualification and operation of oil
and gas programs in the form of limited partnerships. The Partnership is
subject to these guidelines which regulate and restrict transactions
between the Managing General Partner and the Partnership. The Partnership
complies with these guidelines and the Managing General Partner does not
anticipate that continued compliance will have a material adverse effect on
Partnership operations.
Partnership Employees
The Partnership has no employees; however, the Managing General Partner has
a staff of geologists, engineers, accountants, landmen and clerical staff
who engage in Partnership activities and operations and perform additional
services for the Partnership as needed. In addition to the Managing
General Partner's staff, the Partnership engages independent consultants
such as petroleum engineers and geologists as needed. As of December 31,
1997, there were 130 individuals directly employed by the Managing General
Partner in various capacities.
Item 2. Properties
In determining whether an interest in a particular leasehold was to be
acquired, the Managing General Partner considered such criteria as
estimated drilling costs, estimated oil and gas reserves, estimated cash
flow from the sale of future production, present and future prices of oil
and gas, the extent of undeveloped and unproved reserves and the
availability of markets.
As of December 31, 1997, the Partnership possessed an interest in oil and
gas properties located in Ward County of Texas and Lea and Eddy Counties of
New Mexico and Ward County of Texas. These properties consist of various
interests in 10 wells.
Due to the Partnership's objective of maintaining current operations
without engaging in the additional drilling of any developmental or
exploratory wells, or additional acquisitions of producing properties,
there has not been any significant changes in properties during 1997, 1996
and 1995.
<PAGE>
Significant Properties
The following table reflects the properties in which the Partnership has an
interest:
Date
Purchased No. of Proved Reserves*
Name and Location and Interest Wells Oil (bbls) Gas (mcf)
Mobil Fee G #1 12/92 at 1 32,519 65,905
Ward County, 100%
Texas working
interest
Mobil Fee H #1 12/92 at 1 64,839 162,097
Ward County, 100%
Texas working
interest
*The reserve estimates were prepared as of January 1, 1998, by Donald R.
Creamer, P.E., an independent registered petroleum engineer. The reserve
estimates were made in accordance with guidelines established by the
Securities and Exchange Commission pursuant to Rule 4-10(a) of Regulation S-
X. Such guidelines require oil and gas reserve reports be prepared under
existing economic and operating conditions with no provisions for price and
cost escalation except by contractual arrangements.
The New York Mercantile Exchange price at December 31, 1997 of $17.64 was
used as the beginning basis for the oil price. Oil price adjustments from
$17.64 per barrel were made in the individual evaluations to reflect oil
quality, gathering and transportation costs. The results are an average
price received at the lease of $17.23 per barrel in the preparation of the
reserve report as of January 1, 1998.
In the determination of the gas price, the New York Mercantile Exchange
price at December 31, 1997 of $2.26 was used as the beginning basis. Gas
price adjustments from $2.26 per Mcf were made in the individual
evaluations to reflect BTU content, gathering and transportation costs and
gas processing and shrinkage. The results are an average price received at
the lease of $2.69 per Mcf in the preparation of the reserve report as of
January 1, 1998.
As also discussed in Part II, Item 7, Management's Discussion and Analysis
of Financial Condition and Results of Operations, oil and gas prices were
subject to frequent changes in 1997.
<PAGE>
The evaluation of oil and gas properties is not an exact science and
inevitably involves a significant degree of uncertainty, particularly with
respect to the quantity of oil or gas that any given property is capable of
producing. Estimates of oil and gas reserves are based on available
geological and engineering data, the extent and quality of which may vary
in each case and, in certain instances, may prove to be inaccurate.
Consequently, properties may be depleted more rapidly than the geological
and engineering data have indicated.
Unanticipated depletion, if it occurs, will result in lower reserves than
previously estimated; thus an ultimately lower return for the Partnership.
As new data is gathered during the subsequent year, the engineer must
revise his earlier estimates. A year of new information, which is
pertinent to the estimation of future recoverable volumes, is available
during the subsequent year evaluation. In applying industry standards and
procedures, the new data may cause the previous estimates to be revised.
This revision may increase or decrease the earlier estimated volumes.
Pertinent information gathered during the year may include actual
production and decline rates, production from offset wells drilled to the
same geologic formation, increased or decreased water production,
workovers, and changes in lifting costs, among others. Accordingly,
reserve estimates are often different from the quantities of oil and gas
that are ultimately recovered.
The Partnership has reserves which are classified as proved developed
producing and proved undeveloped. All of the proved reserves are included
in the engineering reports which evaluate the Partnership's present
reserves.
Item 3. Legal Proceedings
There are no material pending legal proceedings to which the Partnership is
a party.
Item 4. Submission of Matters to a Vote of Security Holders
No matter was submitted to a vote of security holders during the fourth
quarter of 1997 through the solicitation of proxies or otherwise.
<PAGE>
Part II
Item 5. Market for the Registrant's Common Equity and Related Stockholder
Matters
Market Information
Investor partner interests, or units, in the Partnership were initially
offered and sold for a price of $1,000. Investor partner units are not
traded on any exchange and there is no public or organized trading market
for them. Further, a transferee may not become a substitute limited or
general partner without the consent of the Managing General Partner.
The Managing General Partner has the right, but not the obligation, to
purchase limited partnership units should an investor desire to sell. The
value of the unit is determined by adding the sum of (1) current assets
less liabilities and (2) the present value of the future net revenues
attributable to proved reserves and by discounting the future net revenues
at a rate not in excess of the prime rate charged by Nations Bank, N.A. of
Midland, Texas, plus one percent (1%), which value shall be further reduced
by a risk factor discount of no more than one-third (1/3) to be determined
by the Managing General Partner in its sole and absolute discretion. As of
December 31, 1997, 1996 and 1995, no limited partner units were purchased
by the Managing General Partner.
Number of Limited and General Partner Interest Holders
As of December 31, 1997, there were 104 holders of limited partner units.
Distributions
Pursuant to Article IV, Section 4.01 of the Partnership's Certificate and
Agreement of Limited Partnership "Net Cash Flow" is distributed to the
partners on a monthly basis. "Net Cash Flow" is defined as "the cash
generated by the Partnership's drilling activities, less (i) General and
Administrative Costs, (ii) Operating Costs, and (iii) any reserves
necessary to meet current and anticipated needs of the Partnership,
including, but not limited to drilling cost overruns, as determined in the
sole discretion of the Managing General Partner."
<PAGE>
During 1997, twelve monthly distributions were made totaling $205,500, with
$182,895 distributed to the investor partners and $22,605 to the Managing
General Partners. For the year ended December 31, 1997, distributions of
$129.99 per investor partner unit were made, based upon 1,407 investor
partner units outstanding. During 1996, twelve monthly distributions were
made totaling $250,000, with $222,500 distributed to the investor partners
and $27,500 to the Managing General Partners. For the year ended December
31, 1996, distributions of $158.14 per investor partner unit were made,
based upon 1,407 investor partner units outstanding. For the year ended
December 31, 1995, 12 monthly distributions were made totaling $270,000,
with $240,300 distributed to the investor partners and $29,700 distributed
to the Managing General Partner. For the year ended December 31, 1995,
distributions of $170.79 per investor partner unit were made, based upon
1,407 investor partner units outstanding.
Item 6. Selected Financial Data
The following selected financial data for the year ended December 31, 1997,
1996, 1995, 1994 and 1993 should be read in conjunction with the financial
statements included in Item 8:
Year ended December 31,
------------------------------------------------
1997 1996 1995 1994 1993
---- ---- ---- ---- ----
Revenues $ 335,791 425,671 455,640 405,099 364,420
Net income (loss) 93,437 178,706 165,968 103,054(141,690)
Partners' share of net
income (loss):
Managing General
Partner 19,601 28,208 29,338 22,747 23,058
Investor partners 73,836 150,498 136,630 80,307(164,748)
Investor partners' net
income (loss) per unit 52.48 106.96 97.11 57.08
(117.09)
Investor partners' cash
distributions per unit 129.99 158.14 170.79 63.21
95.33
Total assets $ 682,573 794,538 865,832 969,949 967,110
<PAGE>
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
Southwest Developmental Drilling Fund 92-A, L.P. (the "Partnership" or
"Registrant") was organized as a Delaware limited partnership on May 5,
1992. The offering of limited and general partner interests began August
11, 1992 as part of a shelf offering registered under the name Southwest
Developmental Drilling Program 1991-92. Minimum capital requirements for
the Partnership were met on December 28, 1992, with the offering of limited
and general partner interests concluding December 31, 1992, with total
investor partner contributions of $1,407,000. The Managing General Partner
made a contribution to the capital of the Partnership at the conclusion of
the offering period in an amount equal to 1% of its net capital
contributions. The Managing General Partner contribution was $12,030.
The Partnership was formed to engage primarily in the business of drilling
developmental and exploratory wells, to produce and market crude oil and
natural gas produced from such properties, to distribute any net proceeds
from operations to the general and limited partners and to the extent
necessary, acquire leases which contain drilling prospects. Net revenues
will not be reinvested in other revenue producing assets except to the
extent that performance of remedial work is needed to improve a well's
producing capabilities. The economic life of the Partnership thus depends
on the period over which the Partnership's oil and gas reserves are
economically recoverable.
Based on current conditions, management anticipates the Partnership could
possibly experience a normal decline of 5% to 7% a year. There are no
current plans to perform any workovers in the future.
<PAGE>
Results of Operations
A. General Comparison of the Years Ended December 31, 1997 and 1996
The following table provides certain information regarding performance
factors for the years ended December 31, 1997 and 1996:
Year Ended Percentage
December 31, Increase
1997 1996 (Decrease)
---- ---- ---------
Average price per barrel of oil $ 20.06 20.64 (3%)
Average price per mcf of gas $ 2.65 2.99 (11%)
Oil production in barrels 12,700 15,600 (19%)
Gas production in mcf 30,000 34,300 (13%)
Gross oil and gas revenue $ 334,355 424,676 (21%)
Net oil and gas revenue $ 195,115 274,432 (29%)
Partnership distributions $ 205,500 250,000 (18%)
Limited partner distributions $ 182,895 222,500 (18%)
Per unit distribution to limited partners $ 129.99 158.14 (18%)
Number of limited partner units 1,407 1,407
Revenues
The Partnership's oil and gas revenues decreased to $334,355 from $424,676
for the years ended December 31, 1997 and 1996, respectively, a decrease of
21%. The principal factors affecting the comparison of the years ended
December 31, 1997 and 1996 are as follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the year ended December 31, 1997 as compared to the
year ended December 31, 1996 by 3%, or $.58 per barrel, resulting in a
decrease of approximately $9,000 in revenues. Oil sales represented
76% of total oil and gas sales during the year ended December 31, 1997
as compared to 76% during the year ended December 31, 1996.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 11%, or $.34 per mcf, resulting in
a decrease of approximately $11,700 in revenues.
The total decrease in revenues due to the change in prices received
from oil and gas production is approximately $20,700. The market price
for oil and gas has been extremely volatile over the past decade and
management expects a certain amount of volatility to continue in the
foreseeable future.
<PAGE>
2. Oil production decreased approximately 2,900 barrels or 19% during the
year ended December 31, 1997 as compared to the year ended December 31,
1996, resulting in a decrease of approximately $58,200 in revenues.
Gas production decreased approximately 4,300 mcf or 13% during the same
period, resulting in a decrease of approximately $11,400 in revenues.
The total decrease in revenues due to the change in production is
approximately $69,600. The decrease is attributable to normal decline.
Costs and Expenses
Total costs and expenses decreased to $242,354 from $246,965 for the years
ended December 31, 1997 and 1996, respectively, a decrease of 2%. The
decrease is the result of lower lease operating costs and general and
administrative expense, partially offset by depletion expense.
1. Lease operating costs and production taxes were 7% lower, or
approximately $11,000 less during the year ended December 31, 1997 as
compared to the year ended December 31, 1996.
2. General and administrative costs consist of independent accounting and
engineering fees, computer services, postage, and Managing General
Partner personnel costs. General and administrative costs decreased
3% or approximately $600 during the year ended December 31, 1997 as
compared to the year ended December 31, 1996.
3. Depletion expense increased to $76,000 for the year ended December 31,
1997 from $69,000 for the same period in 1996. This represents an
increase of 10%. Depletion is calculated using the units of revenue
method of amortization based on a percentage of current period gross
revenues to total future gross oil and gas revenues, as estimated by
the Partnership's independent petroleum consultants.
A contributing factor to the increase in depletion expense between the
comparative periods was the decrease in the price of oil and gas used
to determine the Partnership's reserves for January 1, 1998 as compared
to 1997. Another contributing factor was due to the impact of
revisions of previous estimates on reserves. Revisions of previous
estimates can be attributed to the changes in production performance,
oil and gas price and production costs. The impact of the revision
would have increased depletion expense approximately $13,000 as of
December 31, 1996.
<PAGE>
Results of Operations
B. General Comparison of the Years Ended December 31, 1996 and 1995
The following table provides certain information regarding performance
factors for the years ended December 31, 1996 and 1995:
Year Ended Percentage
December 31, Increase
1996 1995 (Decrease)
---- ---- --------
Average price per barrel of oil $ 20.64 17.56 18%
Average price per mcf of gas $ 2.99 2.68 12%
Oil production in barrels 15,600 19,500 (20%)
Gas production in mcf 34,300 41,600 (18%)
Gross oil and gas revenue $ 424,676 454,587 (7%)
Net oil and gas revenue $ 274,432 284,771 (4%)
Partnership distributions $ 250,000 270,000 (7%)
Limited partner distributions $ 222,500 240,300 (7%)
Per unit distribution to limited partners $ 158.14 170.79 (7%)
Number of limited partner units 1,407 1,407
Revenues
The Partnership's oil and gas revenues decreased to $424,676 from $454,587
for the years ended December 31, 1996 and 1995, respectively, a decrease of
7%. The principal factors affecting the comparison of the years ended
December 31, 1996 and 1995 are as follows:
1. The average price for a barrel of oil received by the Partnership
increased during the year ended December 31, 1996 as compared to the
year ended December 31, 1995 by 18%, or $3.08 per barrel, resulting in
an increase of approximately $60,100 in revenues. Oil sales
represented 76% of total oil and gas sales during the year ended
December 31, 1996 as compared to 75% during the year ended December 31,
1995.
The average price for an mcf of gas received by the Partnership
increased during the same period by 12%, or $.31 per mcf, resulting in
an increase of approximately $12,900 in revenues.
The total increase in revenues due to the change in prices received
from oil and gas production is approximately $73,000. The market price
for oil and gas has been extremely volatile over the past decade and
management expects a certain amount of volatility to continue in the
foreseeable future.
<PAGE>
2. Oil production decreased approximately 3,900 barrels or 20% during the
year ended December 31, 1996 as compared to the year ended December 31,
1995, resulting in a decrease of approximately $80,500 in revenues.
Gas production decreased approximately 7,300 mcf or 18% during the same
period, resulting in a decrease of approximately $21,800 in revenues.
The total decrease in revenues due to the change in production is
approximately $102,300. The decrease is primarily a result of an
anticipated sharp decline on one well following a successful workover.
Costs and Expenses
Total costs and expenses decreased to $246,965 from $289,672 for the years
ended December 31, 1996 and 1995, respectively, an increase of 15%. The
decrease is the result of higher lease operating costs, general and
administrative expense and depletion expense.
1. Lease operating costs and production taxes were 12% lower, or
approximately $19,600 less during the year ended December 31, 1996 as
compared to the year ended December 31, 1995. The decrease is a result of
workover costs incurred in 1995.
2. General and administrative costs consist of independent accounting and
engineering fees, computer services, postage, and Managing General
Partner personnel costs. General and administrative costs decreased 1%
or approximately $100 during the year ended December 31, 1996 as
compared to the year ended December 31, 1995.
3. Depletion expense decreased to $69,000 for the year ended December 31,
1996 from $92,000 for the same period in 1995. This represents a
decrease of 25%. Depletion is calculated using the units of revenue
method of amortization based on a percentage of current period gross
revenues to total future gross oil and gas revenues, as estimated by
the Partnership's independent petroleum consultants.
A contributing factor to the decline in depletion expense between the
comparative periods was the increase in the price of oil and gas used
to determine the Partnership's reserves for January 1, 1997 as compared
to 1996. Another contributing factor was due to the impact of
revisions of previous estimates on reserves. Revisions of previous
estimates can be attributed to the changes in production performance,
oil and gas price and production cost. The impact of the revision
would have decreased depletion expense approximately $14,000 as of
December 31, 1995. Also contributing to the decline in depletion
expense was the decrease in oil and gas revenues between the
comparative periods.
<PAGE>
C. Revenue and Distribution Comparison
Partnership net income for the years ended December 31, 1997, 1996 and 1995
was $93,437, $178,706 and $165,968, respectively. Excluding the effects of
depreciation, depletion and amortization, net income for the years ended
December 31, 1997, 1996 and 1995, would have been $178,193, $256,442 and
$266,704, respectively. Correspondingly, Partnership distributions for the
years ended December 31, 1997, 1996 and 1995 were $205,500, $250,000
$270,000, respectively. These differences are indicative of the changes in
oil and gas prices, production and property during 1997, 1996 and 1995.
The sources for the 1997 distributions of $205,500 were oil and gas
operations of approximately $195,400 and the change in oil and gas
properties of approximately $200, with the balance from available cash on
hand at the beginning of the period. The source for the 1996 distributions
of $250,000 were oil and gas operations of approximately $260,100 resulting
in excess cash of contingencies or subsequent distributions. The sources
for the 1995 distributions of $270,000 were oil and gas operations of
approximately $278,100 and property sales of $1,500, offset by additions to
oil and gas properties of approximately $12,500, with the balance from
available cash on hand at the beginning of the period.
Total distributions during the year ended December 31, 1997 were $205,500
of which $182,895 was distributed to the investor partners and $22,605 to
the Managing General Partners. The per unit distribution to investor
partners during the same period was $129.99. Total distributions during
the year ended December 31, 1996 were $250,000 of which $222,500 was
distributed to the investor partners and $27,500 to the Managing General
Partners. The per unit distribution to investor partners during the same
period was $158.14. Total distributions during the year ended 1995 were
$270,000 of which $240,300 was distributed to the investor partners and
$29,700 to the Managing General Partner. The per unit distribution to
investor partners during the year ended 1995 was $170.79.
Since inception of the Partnership, cumulative monthly cash distributions
of $975,715 have been made to the partners. As of December 31, 1997,
$868,762 or $617.46 per investor partner unit, has been distributed to the
investor partners, representing a 62% return of the capital contributed.
<PAGE>
Liquidity and Capital Resources
The primary source of cash is from operations, the receipt of income from
oil and gas properties. The Partnership anticipates the primary source of
cash to continue being from the oil and gas operations.
The December 31, 1997 NYMEX oil price of $17.64 dropped to $14.32 as of
March 18, 1998. The price decline in the first quarter of 1998 could cause
a material write down in oil and gas properties and a possible reduction in
future distributions to investors.
Cash flows provided by operating activities were approximately $195,400 in
1997, $260,100 in 1996 and $278,100 in 1995. The primary source of the
1997 cash flow from operating activities was profitable operations.
Cash flows provided by or (used in) investing activities were approximately
$200 in 1997. There were no cash flows from investing activities during
1996. Cash flows used in investing activities were approximately $11,000
in 1995. The principal source of the 1997 cash flow from investing
activities was sale of oil and gas properties.
Cash flows used in financing activities were approximately $205,400 in
1997, $250,000 in 1996 and $270,000 in 1995. The only use in the 1997
financing activities was the distributions to partners.
As of December 31, 1997, the Partnership had $44,100 in working capital.
The Managing General Partner knows of no unusual contractual commitments
and believes the revenue generated from operations are adequate to meet the
needs of the Partnership.
Information Systems for the Year 2000
The Managing General Partner provides all data processing needs of the
Partnership. The Managing General Partner has reviewed and evaluated its
information systems to determine if its systems accurately process data
referencing the year 2000. Primarily all necessary programming
modifications to correct year 2000 referencing in the Managing General
Partners internal accounting and operating systems have been made to-date.
However the Managing General Partner has not completed its evaluation of
its vendors and suppliers systems to determine the effect, if any, the non-
compliance of such systems would have on the operation of the Managing
General Partnership or the operations of the Partnership.
<PAGE>
Item 8. Financial Statements and Supplementary Data
Index to Financial Statements
Page
Independent Auditors Reports 19
Balance Sheets 21
Statement of Operations 22
Statement of Changes in Partners' Equity 23
Statements of Cash Flows 24
Notes to Financial Statements 26
<PAGE>
INDEPENDENT AUDITORS REPORT
The Partners
Southwest Developmental Drilling
Fund 92-A
(A Delaware Limited Partnership):
We have audited the accompanying balance sheet of Southwest Developmental
Drilling Fund 92-A (the "Partnership") as of December 31, 1997, and the
related statement of operations, changes in partners' equity and cash flows
for the year then ended. These financial statements are the responsibility
of the Partnership's management. Our responsibility is to express an
opinion on these financial statements based on our audit.
We conducted our audit in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to
obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles
used and significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that our audit
provides reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Southwest Developmental
Drilling Fund 92-A as of December 31, 1997 and the results of its
operations and its cash flows for the year then ended in conformity with
generally accepted accounting principles.
KPMG Peat Marwick LLP
Midland, Texas
March 18, 1998
<PAGE>
REPORT OF INDEPENDENT ACCOUNTANTS
To the Partners
Southwest Developmental Drilling
Fund 92-A, L.P.
Midland, Texas
We have audited the accompanying balance sheet of Southwest Developmental
Drilling Fund 92-A, L.P. as of December 31, 1996 and the related statements
of operations, changes in partners' equity and cash flows for the years
ended December 31, 1996 and 1995. These financial statements are the
responsibility of the partnership's management. Our responsibility is to
express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to
obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles
used and significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Southwest Developmental
Drilling Fund 92-A, L.P. as of December 31, 1996 and the results of its
operations and its cash flows for the years ended December 31, 1996 and
1995, in conformity with generally accepted accounting principles.
JOSEPH DECOSIMO AND COMPANY
A Tennessee Registered Limited Liability
Partnership
Chattanooga, Tennessee
March 14, 1997
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Balance Sheets
December 31, 1997 and 1996
1997 1996
---- ----
Assets
Current assets:
Cash and cash equivalents $ 7,887 17,730
Receivable from Managing General Partner 36,334 53,520
- --------- ---------
Total current assets
44,221 71,250
- --------- ---------
Oil and gas properties - using the full-
cost method of accounting 1,315,352 1,315,532
Less accumulated depreciation,
depletion and amortization
677,000 601,000
- --------- ---------
Net oil and gas properties
638,352 714,532
- --------- ---------
Organization costs, net of amortization
of $0 and $34,944 for 1997 and 1996 - 8,756
- --------- ---------
$
682,573 794,538
========= =========
Liabilities and Partners' Equity
Current liability - Distribution payable $ 98 -
- --------- ---------
Partners' equity:
Investor partners 654,446 763,505
Managing General Partner 28,029 31,033
- --------- ---------
Total partners' equity
682,475 794,538
- --------- ---------
$
682,573 794,538
========= =========
The accompanying notes are an integral
part of these financial statements.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Statements of Operations
For the years ended December 31, 1997, 1996 and 1995
1997 1996 1995
---- ---- ----
Revenues
Oil and gas sales $ 334,355 424,676 454,587
Interest income from operations 1,436 995 1,053
-------
- ------- -------
335,791
425,671 455,640
-------
- ------- -------
Expenses
Production 139,240 150,244 169,816
General and administrative 18,358 18,985 19,120
Depreciation, depletion and amortization 84,756 77,736 100,736
-------
- ------- -------
242,354
246,965 289,672
-------
- ------- -------
Net income $ 93,437 178,706 165,968
=======
======= =======
Net income allocated to:
Managing General Partner $ 19,601 28,208 29,338
=======
======= =======
Investor partners $ 73,836 150,498 136,630
=======
======= =======
Per investor partner unit $ 52.48 106.96 97.11
=======
======= =======
The accompanying notes are an integral
part of these financial statements.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Statement of Changes in Partners' Equity
Years ended December 31, 1997, 1996 and 1995
Managing
General Investor
Partner Partners Total
-------- -------- -----
Balance at December 31, 1994 $ 30,687 939,177 969,864
Net income 29,338 136,630 165,968
Distributions (29,700) (240,300)(270,000)
------
- --------- ---------
Balance at December 31, 1995 30,325 835,507 865,832
Net income 28,208 150,498 178,706
Distributions (27,500) (222,500)(250,000)
------
- --------- ---------
Balance at December 31, 1996 31,033 763,505 794,538
Net income 19,601 73,836 93,437
Distributions (22,605) (182,895)(205,500)
------
- --------- --------
Balance at December 31, 1997 $ 28,029 654,446 682,475
======
========= ==========
The accompanying notes are an integral
part of these financial statements.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Statements of Cash Flows
Years ended December 31, 1997, 1996 and 1995
1997 1996 1995
---- ---- ----
Cash flows from operating activities:
Cash received from oil and gas sales $ 355,046 429,745 467,205
Cash paid to Managing General Partner
for administrative fees and general
and administrative overhead
(161,103) (170,624)(190,117)
Interest received 1,436 995 1,053
-------
- ------- -------
Net cash provided by operating activities 195,379 260,116
278,141
-------
- ------- -------
Cash flows from investing activities:
Additions to oil and gas properties - - (12,475)
Sale of oil and gas properties 180 - 1,500
-------
- ------- -------
Net cash used in investing activities 180 - (10,975)
-------
- ------- -------
Cash flows used in financing activities:
Distributions to partners (205,402) (250,000)(270,000)
-------
- ------- -------
Net increase (decrease) in cash and cash
equivalents (9,843) 10,116 (2,834)
Beginning of period 17,730 7,614 10,448
-------
- ------- -------
End of period $ 7,887 17,730 7614
=======
======= =======
(continued)
The accompanying notes are an integral
part of these financial statements.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Statements of Cash Flows, continued
Years ended December 31, 1997, 1996 and 1995
1997 1996 1995
---- ---- ----
Reconciliation of net income to net cash
provided by operating activities:
Net income $ 93,437 178,706 165,968
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation, depletion and amortization 84,756 77,736
100,736
Decrease in receivables 20,691 5,069 12,618
Decrease in payables (3,505) (1,395) (1,181)
-------
- ------- -------
Net cash provided by operating activities $ 195,379 260,116 278,141
=======
======= =======
The accompanying notes are an integral
part of these financial statements.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
1. Organization
Southwest Developmental Drilling Fund 92-A, L.P. was organized under
the laws of the state of Delaware on May 5, 1992, for the purpose of
engaging primarily in the business of drilling developmental and
exploratory wells, to produce and market crude oil and natural gas
produced from such properties, and acquire leases which contain
drilling prospects. The activities of the Partnership should continue
for a term of 50 years, unless terminated at an earlier date as
provided for in the Partnership Agreement. The Partnership
anticipates selling its oil and gas production to a variety of
purchasers with the prices it receives being dependent upon the oil
and gas economy. Southwest Royalties, Inc. serves as the Managing
General Partner. Revenues, costs and expenses are allocated as
follows:
Managing
General General
Partner Partners
-------- --------
Interest income on capital contributions - 100%
Oil and gas sales* 11% 89%
All other revenues* 11% 89%
Organization and offering costs (1) - 100%
Syndication costs - 100%
Amortization of organization costs - 100%
Lease acquisition costs 1% 99%
Gain/loss on property disposition* 11% 89%
Operating and administrative costs*(2) 11% 89%
Depreciation, depletion and amortization
of oil and gas properties - 100%
Intangible drilling and development costs - 100%
All other costs* 11% 89%
*After the Investor Partners have received distributions totaling 150%
of their capital contributions, the allocation will change to 15%
Managing General Partner and 85% Investor Partners.
(1) All organization costs in excess of 4% of initial capital
contributions will be paid by the Managing General Partner and
will be treated as a capital contribution. The Partnership paid
the Managing General Partner an amount equal to 4% of initial
capital contributions for such organization costs.
(2) Administrative costs in any year which exceed 2% of capital
contributions shall be paid by the Managing General Partner and
will be treated as a capital contribution.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
2. Summary of Significant Accounting Policies
Oil and Gas Properties
Oil and gas properties are accounted for at cost under the full-cost
method. Under this method, all productive and nonproductive costs
incurred in connection with the acquisition, exploration and
development of oil and gas reserves are capitalized. Gain or loss on
the sale of oil and gas properties is not recognized unless
significant oil and gas reserves are involved.
The Partnership's policy for depreciation, depletion and amortization
of oil and gas properties is computed under the units of revenue
method. Under the units of revenue method, depreciation, depletion
and amortization is computed on the basis of current gross revenues
from production in relation to future gross revenues, based on current
prices, from estimated production of proved oil and gas reserves.
Under the future gross revenue method, the Partnership computes the
provision by multiplying the total unamortized cost of oil and gas
properties by an overall rate determined by dividing (a) oil and gas
revenues during the period by (b) the total future gross oil and gas
revenues as estimated by the Partnership's independent petroleum
consultants. It is reasonably possible that those estimates of
anticipated future gross revenues, the remaining estimated economic
life of the product, or both could be changed significantly in the
near term due to the potential fluctuation of oil and gas prices or
production. The depletion estimate would also be affected by this
change.
Should the net capitalized costs exceed the estimated present value of
oil and gas reserves, discounted at 10%, such excess costs would be
charged to current expense. As of December 31, 1997, 1996 and 1995,
the net capitalized costs did not exceed the estimated present value
of oil and gas reserves.
Estimates and Uncertainties
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates
and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the
date of the financial statements and the reported amounts of revenues
and expenses during the reporting period. Actual results could differ
from those estimates.
Organization Costs
Organization costs are stated at cost and are amortized over sixty
months using the straight-line method.
Syndication Costs
Syndication costs are accounted for as a reduction of partnership
equity.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
2. Summary of Significant Accounting Policies - continued
Environmental Costs
The Partnership is subject to extensive federal, state and local
environmental laws and regulations. These laws, which are constantly
changing, regulate the discharge of materials into the environment and
may require the Partnership to remove or mitigate the environmental
effects of the disposal or release of petroleum or chemical substances
at various sites. Environmental expenditures are expensed or
capitalized depending on their future economic benefit. Costs which
improve a property as compared with the condition of the property when
originally constructed or acquired and costs which prevent future
environmental contamination are capitalized. Expenditures that relate
to an existing condition caused by past operations and that have no
future economic benefits are expensed. Liabilities for expenditures
of a non-capital nature are recorded when environmental assessment
and/or remediation is probable, and the costs can be reasonably
estimated.
Gas Balancing
The Partnership utilizes the sales method of accounting for over or
under deliveries of gas. Under this method, the Partnership records
revenues based on the payments it has received for sales from
purchasers. As of December 31, 1997, 1996 and 1995, the Partnership
was not over or under produced.
Income Taxes
No provision for income taxes is reflected in these financial
statements, since the tax effects of the Partnership's income or loss
are passed through to the individual partners.
In accordance with the requirements of Statement of Financial
Accounting Standards No. 109, "Accounting for Income Taxes," the
Partnership's tax basis in its assets at December 31, 1997 and 1996
was $531,228 and $572,137, respectively, less than that shown on the
accompanying Balance Sheets in accordance with generally accepted
accounting principles.
Cash and Cash Equivalents
For purposes of the statement of cash flows, the Partnership considers
all highly liquid debt instruments purchased with a maturity of three
months or less to be cash equivalents. The Partnership maintains its
cash at one financial institution.
Investor Partner Units
As of December 31, 1997, 1996 and 1995, there were 1,407 investor
units outstanding held by 104 partners.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
2. Summary of Significant Accounting Policies - continued
Concentrations of Credit Risk
The Partnership is subject to credit risk through trade receivables.
Although a substantial portion of its debtors' ability to pay is
dependent upon the oil and gas industry, credit risk is minimized due
to a large customer base. All partnership revenues are received by
the Managing General Partner and subsequently remitted to the
partnership and all expenses are paid by the Managing General Partner
and subsequently reimbursed by the partnership.
Fair Value of Financial Instruments
The carrying amount of cash and accounts receivable approximates fair
value due to the short maturity of these instruments.
Recent Accounting Pronouncements
In June 1997, the FASB issued "Reporting Comprehensive Income," SFAS
No. 130, which establishes standards for reporting and display of
comprehensive income and its components in a full set of general-
purpose financial statements. Specifically, this statements requires
that an enterprise (i) classify items of other comprehensive income by
their nature in a financial statement and (ii) display the accumulated
balance of other comprehensive income separately from retained
earnings and additional paid-in capital in the equity section of a
statement of financial position. This statement is effective for
fiscal years beginning after December 15, 1997. The Partnership
anticipates adoption of SFAS No. 130 in its year ended December 31,
1998 financial statements.
Comprehensive income consists of the change in equity of a business
enterprise during a period from transactions and other events and
circumstances from nonowner sources. Specifically, this includes net
income and other comprehensive income, which is made up of certain
changes in assets and liabilities that are not reported in a statement
of operations but are included in the balances within a separate
component of equity in a statement of financial position. Such
changes include, but are not limited to, unrealized gains for
marketable securities and futures contracts, foreign currency
translation adjustments and minimum pension liability adjustments.
Net Income (loss) per limited partnership unit
The net income (loss) per limited partnership unit is calculated by
using the number of outstanding limited partnership units.
3. Commitments and Contingent Liabilities
The Managing General Partner has the right, but not the obligation, to
purchase limited partnership units should an investor desire to sell.
The value of the unit is determined by adding the sum of (1) current
assets less liabilities and (2) the present value of the future net
revenues attributable to proved reserves and by discounting the future
net revenues at a rate not in excess of the prime rate charged by
Nations Bank, N.A. of Midland, Texas, plus one percent (1%), which
value shall be further reduced by a risk factor discount of no more
than one-third (1/3) to be determined by the Managing General Partner
in its sole and absolute discretion.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
3. Commitments and Contingent Liabilities - continued
The Partnership is subject to various federal, state and local
environmental laws and regulations which establish standards and
requirements for protection of the environment. The Partnership
cannot predict the future impact of such standards and requirements,
which are subject to change and can have retroactive effectiveness.
The Partnership continues to monitor the status of these laws and
regulations.
As of December 31, 1997, the Partnership has not been fined, cited or
notified of any environmental violations and management is not aware
of any unasserted violations which would have a material adverse
effect upon capital expenditures, earnings or the competitive position
in the oil and gas industry.
However, the Managing General Partner does recognize by the very
nature of its business, material costs could be incurred in the near
term to bring the Partnership into total compliance. The amount of
such future expenditures is not reliably determinable due to several
factors, including the unknown magnitude of possible contaminations,
the unknown timing and extent of the corrective actions which may be
required, the determination of the Partnership's liability in
proportion to other responsible parties and the extent to which such
expenditures are recoverable from insurance or indemnifications from
prior owners of Partnership's properties.
4. Related Party Transactions
A significant portion of the oil and gas properties in which the
Partnership has an interest are operated by and purchased from the
Managing General Partner. As is usual in the industry and as provided
for in the operating agreement for each respective oil and gas
property in which the Partnership has an interest, the operator is
paid an amount for administrative overhead attributable to operating
such properties, with such amounts to Southwest Royalties, Inc. as
operator approximating $19,000, $19,000 and $17,000 for the years
ended December 31, 1997, 1996 and 1995, respectively. In addition,
the Managing General Partner and certain officers and employees may
have an interest in some of the properties that the Partnership also
participates.
Certain subsidiaries or affiliates of the Managing General Partner
perform various oilfield services for properties in which the
Partnership owns an interest. Such services aggregated approximately
$1,400, $400 and $5,000 for the years ended December 31, 1997, 1996
and 1995, respectively, and the Managing General Partner believes that
these costs are comparable to similar charges paid by the Partnership
to unrelated third parties.
Southwest Royalties, Inc., the Managing General Partner, was paid an
administrative fee of $12,000 during 1997, 1996 and 1995 for
reimbursement of indirect general and administrative overhead
expenses.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
4. Related Party Transactions - continued
In addition, a director and officer of the Managing General Partner is
a partner in a law firm, with such firm providing legal services to
the Partnership approximating none during 1997, $50 during 1996 and
none during 1995.
Receivables from Southwest Royalties, Inc., the Managing General
Partner, of approximately $36,300 and $53,500 are from oil and gas
production, net of lease operating costs and production taxes, as of
December 31, 1997 and 1996, respectively.
5. Major Customers
No material portion of the Partnership's business is dependent on a
single purchaser, or a very few purchaser, where the loss of one would
have a material adverse impact on the Partnership. Three purchasers
accounted for 94% of the Partnership's total oil and gas production
during 1997: Scurlock Permian Corporation 60%, Aquila Southwest
Pipeline Corporation 19% and Navajo Refining Company, Inc. 15%.
Three purchasers accounted for 96% of the partnership's total oil and
gas production during 1996: Scurlock Permian Corporation 60%, Aquila
Southwest Pipeline Corporation 19% and Navajo Refining Company Inc.
17%. Three purchasers, Scurlock Permian Corporation, Aquila Southwest
Pipeline Corporation and Navajo Refining Company, accounted for 60%,
20% and 17%, respectively, of the Partnership's total oil and gas
production during 1995. All purchasers of the Partnership's oil and
gas production are unrelated third parties. In the event this
purchaser were to discontinue purchasing the Partnership's production,
the Managing General Partner believes that a substitute purchaser or
purchasers could be located without undue delay. No other purchaser
accounted for an amount equal to or greater than 10% of the
Partnership's total oil and gas production.
6. Estimated Oil and Gas Reserves (unaudited)
The Partnership's interest in proved oil and gas reserves is as
follows:
Oil (bbls) Gas (mcf)
---------- ---------
Proved developed and undeveloped reserves -
January 1, 1995 188,000 339,000
Production (20,000) (42,000)
Revisions of estimates in place (17,000) 20,000
------- -------
December 31, 1995 151,000 317,000
Production (16,000) (34,000)
Revisions of estimates in place 29,000 53,000
------- -------
December 31, 1996 164,000 336,000
Production (13,000) (30,000)
Revisions of estimates in place (33,000) (18,000)
------- -------
December 31, 1997 118,000 288,000
======= =======
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
6. Estimated Oil and Gas Reserves (unaudited) - continued
Oil (bbls) Gas (mcf)
---------- ---------
Proved developed reserves -
December 31, 1995 151,000 316,000
======= =======
December 31, 1996 163,000 335,000
======= =======
December 31, 1997 117,000 288,000
======= =======
All of the Partnership's reserves are located within the continental
United States.
*The reserve estimates were prepared as of January 1, 1998, by Donald
R. Creamer, P.E., an independent registered petroleum engineer. The
reserve estimates were made in accordance with guidelines established
by the Securities and Exchange Commission pursuant to Rule 4-10(a) of
Regulation S-X. Such guidelines require oil and gas reserve reports
be prepared under existing economic and operating conditions with no
provisions for price and cost escalation except by contractual
arrangements.
The New York Mercantile Exchange price at December 31, 1997 of $17.64
was used as the beginning basis for the oil price. Oil price
adjustments from $17.64 per barrel were made in the individual
evaluations to reflect oil quality, gathering and transportation
costs. The results are an average price received at the lease of
$17.23 per barrel in the preparation of the reserve report as of
January 1, 1998.
In the determination of the gas price, the New York Mercantile
Exchange price at December 31, 1997 of $2.26 was used as the beginning
basis. Gas price adjustments from $2.26 per Mcf were made in the
individual evaluations to reflect BTU content, gathering and
transportation costs and gas processing and shrinkage. The results
are an average price received at the lease of $2.69 per Mcf in the
preparation of the reserve report as of January 1, 1998.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
6. Estimated Oil and Gas Reserves (unaudited) - continued
The evaluation of oil and gas properties is not an exact science and
inevitably involves a significant degree of uncertainty, particularly
with respect to the quantity of oil or gas that any given property is
capable of producing. Estimates of oil and gas reserves are based on
available geological and engineering data, the extent and quality of
which may vary in each case and, in certain instances, may prove to be
inaccurate. Consequently, properties may be depleted more rapidly
than the geological and engineering data have indicated.
Unanticipated depletion, if it occurs, will result in lower reserves
than previously estimated; thus an ultimately lower return for the
Partnership. As new data is gathered during the subsequent year, the
engineer must revise his earlier estimates. A year of new
information, which is pertinent to the estimation of future
recoverable volumes, is available during the subsequent year
evaluation. In applying industry standards and procedures, the new
data may cause the previous estimates to be revised. This revision
may increase or decrease the earlier estimated volumes. Pertinent
information gathered during the year may include actual production and
decline rates, production from offset wells drilled to the same
geologic formation, increased or decreased water production,
workovers, and changes in lifting costs, among others. Accordingly,
reserve estimates are often different from the quantities of oil and
gas that are ultimately recovered.
The Partnership has reserves which are classified as proved developed
producing and proved undeveloped. All of the proved reserves are
included in the engineering reports which evaluate the Partnership's
present reserves.
<PAGE>
Southwest Developmental Drilling Fund 92-A, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
6. Estimated Oil & Gas Reserves (unaudited) - continued
The standardized measure of discounted future net cash flows relating
to proved oil and gas reserves at December 31, 1997, 1996 and 1995 is
presented below:
1997 1996 1995
---- ---- ----
Future cash inflows $ 2,801,000 5,563,000 3,865,000
Production and development costs 1,637,000 2,738,000 2,248,000
--------- --------- ---------
Future net cash flows 1,164,000 2,825,000 1,617,000
10% annual discount for estimated
timing of cash flows 430,000 1,186,000 563,000
--------- --------- ---------
Standardized measure of discounted
future net cash flows $ 734,000 1,639,000 1,054,000
========= ========= =========
The principal sources of change in the standardized measure of
discounted future net cash flows for the years ended December 31,
1997, 1996 and 1995 are as follows:
1997 1996 1995
---- ---- ----
Sales of oil and gas produced,
net of production costs $ (195,000) (364,000) (359,000)
Changes in prices and production costs (754,000) 692,000
486,000
Changes of production rates
(timing) and others 41,000 74,000 (138,000)
Revisions of previous
quantities estimates (161,000) 44,000 (248,000)
Accretion of discount 164,000 139,000 128,000
Discounted future net
cash flows -
Beginning of year 1,639,000 1,054,000 1,185,000
--------- -------- --------
End of year $ 734,000 1,639,000 1,054,000
========= ======== ========
Future net cash flows were computed using year-end prices and costs
that related to existing proved oil and gas reserves in which the
Partnership has mineral interests.
<PAGE>
Item 9. Changes in and Disagreements With Accountants on Accounting and
Financial Disclosure
On June 9, 1997 Southwest Royalties, Inc. the Partnership's Managing
General Partner (Southwest Royalties, Inc.) dismissed Joseph Decosimo and
Company as the Partnership's independent accountants. The Managing General
Partner's Board of Directors approved the decision to change the
Partnership's independent accountants.
The reports of Joseph Decosimo and Company on the financial statements for
the past two fiscal years contained no adverse opinion or disclaimer of
opinion and were not qualified or modified as to uncertainty, audit scope
or accounting principle.
In connection with its audits for the two most recent fiscal years and
through June 9, 1997, there have been no disagreements with Joseph Decosimo
and Company on any matter of accounting principles or practices, financial
statements disclosure, or auditing scope or procedure, which disagreements
if not resolved to the satisfaction of Joseph Decosimo and Company would
have caused them to make reference thereto in their report on the financial
statements for such years.
The Registrant has requested that Joseph Decosimo and Company furnish it
with a letter addressed to the SEC stating whether or not is agrees with
the above statements. A copy of that letter is included as Exhibit 16 and
has been filed with the Securities and Exchange Commission.
<PAGE>
Part III
Item 10. Directors and Executive Officers of the Registrant
Management of the Partnership is provided by Southwest Royalties, Inc., as
Managing General Partner. The names, ages, offices, positions and length
of service of the directors and executive officers of Southwest Royalties,
Inc. are set forth below. Each director and executive officer serves for a
term of one year. The present directors of the Managing General Partner
have served in their capacity since the Company's formation in 1983.
Name Age Position
- -------------------- --- -----------------------------------
- -------
H. H. Wommack, III 42 Chairman of the Board,
President,
Chief Executive Officer, Treasurer
and Director
H. Allen Corey 43 Secretary and Director
Bill E. Coggin 44 Vice President and Chief
Financial Officer
Phillip F. Hock, Jr. 54 Vice President, Exploration
Jon P. Tate 40 Vice President, Land and
Assistant Secretary
Joel D. Talley 36 Vice President, Acquisitions and
Exploitation Manager
R. Douglas Keathley 42 Vice President, Operations
J. Steven Person 39 Vice President, Marketing
H. H. Wommack, III, is Chairman of the Board, President, Chief Executive
Officer, Treasurer, principal stockholder and a director of the Managing
General Partner, and has served as its President since the Company's
organization in August, 1983. Prior to the formation of the Company, Mr.
Wommack was a self-employed independent oil producer engaged in the
purchase and sale of royalty and working interests in oil and gas leases,
and the drilling of exploratory and developmental oil and gas wells. Mr.
Wommack holds a J.D. degree from the University of Texas from which he
graduated in 1980, and a B.A. from the University of North Carolina in
1977.
H. Allen Corey, a founder of the Managing General Partner, has served as
the Managing General Partner's secretary and a director since its
inception. Mr. Corey is President of Trolley Barn Brewery, Inc., a brew
pub restaurant chain based in the Southeast. Prior to his involvement with
Trolley Barn, Mr. Corey was a partner at the law firm of Miller & Martin in
Chattanooga, Tennessee. He is currently of counsel to the law firm of
Baker, Donelson, Bearman & Caldwell, with the offices in Chattanooga,
Tennessee. Mr. Corey received a J.D. degree from the Vanderbilt University
Law School and B.A. degree from the University of North Carolina at Chapel
Hill.
<PAGE>
Bill E. Coggin, Vice President and Chief Financial Officer, has been with
the Managing General Partner since 1985. Mr. Coggin was Controller for Rod
Ric Corporation of Midland, Texas, an oil and gas drilling company, during
the latter part of 1984. He was Controller for C.F. Lawrence & Associates,
Inc., an independent oil and gas operator also of Midland, Texas during the
early part of 1984. Mr. Coggin taught public school for four years prior
to his business experience. Mr. Coggin received a B.S. in Education and a
B.B.A. in Accounting from Angelo State University.
Phillip F. Hock, Jr., Vice President, Exploration, assumed his
responsibilities with the Managing General Partner as a geologist in
November 1993. Prior to joining the Managing General Partner, Mr. Hock was
employed four (4) years by Ramco Oil and Gas as Exploitation Manager (1989-
1993), Robinson Brothers Drilling Company as Exploration Manager (1980-
1984), and as petroleum geologist by several companies throughout his
career, Magic Circle Oil and Gas (1988-1989), Reading and Bates Petroleum
Company (1984-1988), and Exxon (1971-1980). Mr. Hock received a B. S. in
Geology from Morehead State University and a M. S. in Geology form the
University of New Mexico.
Jon P. Tate, Vice President, Land and Assistant Secretary, assumed his
responsibilities with the Managing General Partner in 1989. Prior to
joining the Managing General Partner, Mr. Tate was employed by C.F.
Lawrence & Associates, Inc., an independent oil and gas company, as Land
Manager from 1981 through 1989. Mr. Tate is a member of the Permian Basin
Landman's Association and received his B.B.S. degree from Hardin-Simmons
University.
Joel D. Talley, Vice President, Acquisitions and Exploitation Manager,
assumed his responsibilities with the Managing General Partner on July 15,
1996. Prior to joining the Managing General Partner, Mr. Talley was
employed for four (4) years by Merit Energy Company as Acquisitions Manager
and then as Region Manager over West Texas, New Mexico and Wyoming (1992-
1996) and eight (8) years by ARCO Oil & Gas Company in various engineering
positions (1984-1992). Mr. Talley received his B.S. in Mechanical
Engineering in 1984 from Texas A&M University.
R. Douglas Keathley, Vice President, Operations, assumed his
responsibilities with the Managing General Partner as a Production Engineer
in October, 1992. Prior to joining the Managing General Partner, Mr.
Keathley was employed for four (4) years by ARCO Oil & Gas Company as
senior drilling engineer working in all phases of well production (1988-
1992), eight (8) years by Reading & Bates Petroleum Company as senior
petroleum engineer responsible for drilling (1980-1988) and two (2) years
by Tenneco Oil Company as drilling engineer responsible for all phases of
drilling (1978-1980). Mr. Keathley received his B.S. in Petroleum
Engineering in 1977 from the University of Oklahoma.
J. Steven Person, Vice President, Marketing, assumed his responsibilities
with the Managing General Partner as National Marketing Director in 1989.
Prior to joining the Managing General Partner, Mr. Person served as Vice
President of Marketing for CRI, Inc., and was associated with Capital
Financial Group and Dean Witter (1983). He received a B.B.A. from Baylor
University in 1982 and an M.D.A. from Houston Baptist University in 1987.
<PAGE>
Key Employees
Accounting and Administrative Officer - Debbie A. Brock, age 45, assumed
her position with the Managing General Partner in 1991. Prior to joining
the Managing General Partner, Ms. Brock was employed with Western Container
Corporation as Accounting Manager (1982-1990), Synthetic Industries
(Texas), Inc. as Accounting Manager (1976-1982) and held various accounting
positions in the manufacturing industry (1971-1975). Ms. Brock received a
B.B.A. from the University of Houston.
Controller - Robert A. Langford, age 48, assumed his responsibilities with
the Managing General Partner in 1992. Mr. Langford received his B.B.A.
degree in Accounting in 1975 from the University of Central Arkansas.
Prior to joining the Managing General Partner, Mr. Langford was employed
with Forest Oil Corporation as Corporate Coordinator, Regional Coordinator,
Accounting Manager. He held various other positions from 1982-1992 and
1976-1980 and was Assistant Controller of National Oil Company from 1980-
1982.
Financial Reporting Manager - Bryan Dixon, C.P.A., age 31, assumed his
responsibilities with the Managing General Partner in 1992. Mr. Dixon
received his B.B.A. degree in Accounting in 1988 from Texas Tech University
in Lubbock, Texas. Prior to joining the Managing General Partner, Mr.
Dixon was employed as a Senior Auditor with Johnson, Miller & Company from
1991-1992 and Audit Supervisor for Texas Tech University and the Texas Tech
University Health Sciences Center from 1988-1991.
Production Superintendent - Steve C. Garner, age 56, assumed his
responsibilities with the Managing General Partner as Production
Superintendent in July, 1989. Prior to joining the Managing General
Partner, Mr. Garner was employed 16 years by Shell Oil Company working in
all phases of oil field production as operations foreman, one and one-half
years with Petroleum Corporation of Delaware as Production Superintendent,
six years as an independent engineering consultant, and one year with
Citation Oil & Gas Corp. as a workover, completion and production foreman.
Mr. Garner has worked extensively in the Permian Basin oil field for the
last 25 years.
Tax Manager - Carolyn Cookson, age 41, assumed her position with the
Managing General Partner in April, 1989. Prior to joining the Managing
General Partner, Ms. Cookson was employed as Director of Taxes at C.F.
Lawrence & Associates, Inc. from 1983 to 1989, and worked in public
accounting at McCleskey, Cook & Green, P.C. from 1981 to 1983 and Deanna
Brady, C.P.A. from 1980 to 1981. She is a member of the Permian Basin
Chapter of the Petroleum Accountants' Society, and serves on its Board of
Directors and is liaison to the Tax Committee. Ms. Cookson received a
B.B.A. in accounting from New Mexico State University.
<PAGE>
Investor Relations Manager - Sandra K. Flournoy, age 51, came to Southwest
Royalties, Inc. in 1988 from Parker & Parsley Petroleum, where she was
Assistant Manager of Investor Services and Broker/Dealer Relations for two
years. Prior to that, Ms. Flournoy was Administrative Assistant to the
Superintendent at Greenwood ISD for four years.
In certain instances, the Managing General Partner will engage professional
petroleum consultants and other independent contractors, including
engineers and geologists in connection with property acquisitions,
geological and geophysical analysis, and reservoir engineering. The
Managing General Partner believes that, in addition to its own "in-house"
staff, the utilization of such consultants and independent contractors in
specific instances and on an "as-needed" basis allows for greater
flexibility and greater opportunity to perform its oil and gas activities
more economically and effectively.
Item 11. Executive Compensation
The Partnership does not have any directors or executive officers. The
executive officers of the Managing General Partner do not receive any cash
compensation, bonuses, deferred compensation or compensation pursuant to
any type of plan, from the Partnership. The Managing General Partner
received $12,000 during 1997, 1996 and 1995 as an administrative fee for
reimbursement of indirect general and administrative expenses.
Item 12. Security Ownership of Certain Beneficial Owners and Management
There are no investor partners who own of record, or are known by the
Managing General Partner to beneficially own, more than five percent of the
Partnership's investor partner interests.
The Managing General Partner owns an eleven percent interest as a general
partner.
No officer or director of the Managing General Partner owns Units in the
Partnership. There are no arrangements known to the Managing General
Partner which may at a subsequent date result in a change of control of the
Partnership.
Item 13. Certain Relationships and Related Transactions
In 1997, the Managing General Partner received $12,000 as an administrative
fee. This amount is part of the general and administrative expenses
incurred by the Partnership.
In some instances the Managing General Partner and certain officers and
employees may be working interest owners in an oil and gas property in
which the Partnership also has a working interest. Certain properties in
which the Partnership has an interest are operated by the Managing General
Partner, who was paid approximately $19,000 for administrative overhead
attributable to operating such properties during 1997.
Certain subsidiaries or affiliates of the Managing General Partner perform
various oilfield services for properties in which the Partnership owns an
interest. Such services aggregated approximately $1,400 for the period
ended December 31, 1997.
In the opinion of management, the terms of the above transactions are
similar to ones with unaffiliated third parties.
<PAGE>
Part IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K
(a)(1) Financial Statements:
Included in Part II of this report --
Reports of Independent Accountants
Balance Sheet
Statement of Changes in Partners' Equity
Statement of Cash Flows
Notes to Financial Statements
(2) Schedules I through XIII are omitted
because they are not applicable, or because the required
information is shown in the financial statements or the
notes thereto.
(3) Exhibits:
Exhibit 4(a): Certificate of Limited
Partnership of Southwest Developmental
Drilling Fund 92-A, L.P., dated May 5,
1992 (Incorporated by reference from
Partnership's Form 10-K for the fiscal
year ended December 31, 1992).
Exhibit 4(b): Agreement of Limited
Partnership of Southwest Developmental
Drilling Fund 92-A, L.P. dated May 5, 1992
(Incorporated by reference from
Partnership's Form 10-K for the fiscal
year ended December 31, 1992).
Exhibit 4(c): First Amendment to
Amended and Restated Certificate of
Limited Partnership of Southwest
Developmental Drilling Fund 92-A. L.P.,
dated as of February 22, 1993
(Incorporated by reference from Partner
ship's Form 10-K for the fiscal year ended
December 31, 1993).
Exhibit 4(d): Second Amendment to
Amended and Restated Certificate of
Limited Partnership of Southwest
Developmental Drilling Fund 92-A. L.P.,
dated as of March 26, 1993 (Incorporated
by reference from Partnership's Form 10-K
for the fiscal year ended December 31,
1993).
<PAGE>
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K -
continued
Exhibit 4(e): Second Amended and
Restated Certificate of Limited
Partnership of Southwest Developmental
Drilling Fund 92-A. L.P., dated as of
January 12, 1994. (Incorporated by
reference from Partnership's Form 10-K for
the fiscal year ended December 31, 1993).
16 Letter on Changes in Certifying
Accountant (Incorporated by reference from
Partnership's Form 8-K dated June 9, 1997.)
27 Financial Data Schedule
Reports on Form 8-K
(b) No report on Form 8-K was filed during the
quarter ended December 31, 1997.
<PAGE>
Signatures
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Partnership has duly caused this report to be
signed on its behalf by the undersigned, thereunto duly authorized.
Southwest Developmental Drilling Fund 92-A, L.P.,
a Delaware limited partnership
By: Southwest Royalties, Inc.,
Managing
General Partner
By: /s/ H. H. Wommack, III
-----------------------------
H. H. Wommack, III,
President
Date: March 31, 1998
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
Partnership and in the capacities and on the dates indicated.
By: /s/ H. H. Wommack, III
-----------------------------------
H. H. Wommack, III, Chairman of the
Board, President, Chief Executive
Officer, Treasurer and Director
Date: March 31, 1998
By: /s/ H. Allen Corey
-----------------------------
H. Allen Corey, Secretary and
Director
Date: March 31, 1998
<PAGE>
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
This schedule contains summary financial information extracted from the
Balance Sheet at December 31, 1997 and the Statement of Operations for
the Year Ended December 31, 1997 and is qualified in its entirety by
reference to such financial statements.
</LEGEND>
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-END> DEC-31-1997
<CASH> 7,887
<SECURITIES> 0
<RECEIVABLES> 36,334
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 44,221
<PP&E> 1,315,352
<DEPRECIATION> 677,000
<TOTAL-ASSETS> 682,573
<CURRENT-LIABILITIES> 98
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 682,475
<TOTAL-LIABILITY-AND-EQUITY> 682,573
<SALES> 334,355
<TOTAL-REVENUES> 335,791
<CGS> 139,240
<TOTAL-COSTS> 139,240
<OTHER-EXPENSES> 103,114
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 93,437
<INCOME-TAX> 0
<INCOME-CONTINUING> 93,437
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 93,437
<EPS-PRIMARY> 52.48
<EPS-DILUTED> 52.48
</TABLE>
