Back to GetFilings.com
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, 1996
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 0-19601
Southwest Royalties Institutional Income Fund X-B, L.P.
(Exact name of registrant as specified in
its limited partnership agreement)
Delaware 75-2332174
(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 partnership 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 42. There is no
exhibit index.
PAGE
Table of Contents
Item Page
Part I
1. Business. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3
2. Properties. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
3. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . 9
4. Submission of Matters to a Vote of Security Holders . . . . . . . . 9
Part II
5. Market for Registrant's Common Equity and Related
Stockholder Matters . . . . . . . . . . . . . . . . . . . . . . . .10
6. Selected Financial Data . . . . . . . . . . . . . . . . . . . . . .11
7. Management's Discussion and Analysis of
Financial Condition and Results of Operations . . . . . . . . . . .12
8. Financial Statements and Supplementary Data . . . . . . . . . . . .19
9. Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure. . . . . . . . . . . . . . .34
Part III
10. Directors and Executive Officers of the Registrant. . . . . . . . .35
11. Executive Compensation. . . . . . . . . . . . . . . . . . . . . . .38
12. Security Ownership of Certain Beneficial Owners and
Management. . . . . . . . . . . . . . . . . . . . . . . . . . . . .38
13. Certain Relationships and Related Transactions. . . . . . . . . . .40
Part IV
14. Exhibits, Financial Statement Schedules, and Reports
on Form 8-K . . . . . . . . . . . . . . . . . . . . . . . . . . . .41
Signatures. . . . . . . . . . . . . . . . . . . . . . . . . . . . .42
Part I
Item 1. Business
General
Southwest Royalties Institutional Income Fund X-B, L.P. (the "Partnership" or
"Registrant") was organized as a Delaware limited partnership on November 27,
1990. The offering of limited partnership interests began December 1, 1990
as part of a shelf offering registered under the name Southwest Royalties
Institutional 1990-91 Income Program (the "Program"). Minimum capital
requirements for the Partnership were met on March 11, 1991, with the
offering of limited partnership interests concluding September 30, 1991, but
continuing for other partnerships within the program. The Partnership has no
subsidiaries.
The Partnership has acquired interests in producing oil and gas properties,
and produced and marketed the crude oil and natural gas produced from such
properties. In most cases, the Partnership purchased royalty or overriding
royalty interests and working interests in oil and gas properties that were
converted into net profits interests or other nonoperating interests. The
Partnership purchased either all or part of the rights and obligations under
various oil and gas leases.
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 245 individuals, together with certain independent
consultants used on an "as needed" basis, perform various services on behalf
of the Partnership, including the selection of oil and gas properties and the
marketing of production from such properties. H. H. Wommack, III, a
stockholder, director, President and Treasurer of the Managing General
Partner, is also a general partner. The Partnership has no employees.
Principal Products, Marketing and Distribution
The Partnership has acquired and holds royalty, overriding royalty and net
profit interests in oil and gas properties located in Arkansas, Louisiana,
Mississippi, New Mexico, Oklahoma and Texas. All activities of the
Partnership are confined to the continental United States. All oil and gas
produced from these properties is 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.
The recent strength in the price of crude oil reflects a continued growth in
demand for energy. The worldwide demand for oil continues to grow. The
United States dependence on foreign oil reached a record 51% in 1996. The
supply of oil is not keeping up with the demand on either a domestic or
worldwide economic basis. Oil production in the United States fell for the
fifth straight year, dropping 1.8% to 6.45 million barrels per day in 1996.
At the same time, economic recovery in the world economy continues to apply
upward pressure on demand. Current oil consumption of over 70 million
barrels per day is growing on an annual basis. This is especially acute in
the lesser developed countries as they move toward industrialization. Supply
and demand for oil has moved very close to being in balance. The lack of
excess capacity in the oil markets has helped push oil prices into the mid-
20's during 1996.
For the last several years, the natural gas industry in the United States has
been affected generally by a surplus in available natural gas and enhanced
delivery capability causing a general deterioration in natural gas prices.
In 1996, natural gas prices recovered significantly after having been
adversely affected for many years by the chronic oversupply. A colder than
normal 1995 and 1996 winter for most of the nation and a cold start for the
1996 and 1997 heating season has increased demand, while supplies have
declined creating a guarded optimism within the industry in regards to the
1997 gas price. January 1997's gas price is the highest the industry has
seen since deregulation in 1985.
Following is a table of the ratios of revenues received from oil and gas
production for the last three years:
Oil Gas
1996 80% 20%
1995 83% 17%
1994 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 for 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 has
been able to sell all of its natural gas, either through contracts in place
or on the spot market at the then prevailing spot market price. As a result,
the volumes sold by the Partnership have not fluctuated materially with the
change of season.
Customer Dependence
No material portion of the Partnership's business is dependent on a single
purchaser, or a very few purchasers, where the loss of one would have a
material adverse impact on the Partnership. Three purchasers accounted for
60% of the Partnership's total oil and gas production during 1996: Mobil
Corporation 33%, Scurlock Permian Corporation 15% and Marathon Petroleum
Company 12%. Three purchasers accounted for 55% of the Partnership's total
oil and gas production during 1995: Mobil Corporation, Scurlock Permian
Corporation and Marathon Petroleum Company purchased 32%, 13% and 10%,
respectively. Two purchasers accounted for 39% of the Partnership's total
oil and gas production during 1994: Mobil Corporation and Scurlock Permian
Corporation purchased 28% and 11%, respectively.
All purchasers of the Partnership's oil and gas production are unrelated
third parties. In the event any of these purchasers 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 sales of oil and gas production.
Competition
Because the Partnership has utilized all of its funds available for the
acquisition of net profits or royalty interests in producing oil and gas
properties, 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.
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 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, 1996, there
were 245 individuals directly employed by the Managing General Partner in
various capacities.
Item 2. Properties
In determining whether an interest in a particular producing property was to
be acquired, the Managing General Partner considered such criteria as
estimated oil and gas reserves, estimated cash flow from the sale of
production, present and future prices of oil and gas, the extent of
undeveloped and unproved reserves, the potential for secondary, tertiary and
other enhanced recovery projects and the availability of markets.
As of December 31, 1996, the Partnership possessed an interest in oil and gas
properties located in Columbia County of Arkansas; Cameron and Calcasieu
Parishes of Louisiana; Walthall County of Mississippi; Beckham and Grady
Counties of Oklahoma; Eddy and Lea Counties of New Mexico; and Andrews,
Borden, Colorado, Crane, Crockett, Duval, Gaines, Howard, Midland,
Nacogdoches, Panola, Schleicher, Scurry, Sterling, Sutton, Upton, Ward,
Winkler and Yoakum Counties of Texas. These properties consist of various
interests in approximately 343 wells and units.
Due to the Partnership's objective of maintaining current operations without
engaging in the drilling of any developmental or exploratory wells, or
additional acquisitions of producing properties, there have not been any
significant changes in properties during 1996, 1995 and 1994.
Upon a determination by Management that they were either not profitable to
own or Management received an offer that exceeded the leases reserves, the
following leases were sold.
During 1996, four leases were sold for approximately $227,100. The Jay
Little Escambia Creek was sold effective July 1995, Todd was sold effective
March 1996 and Fair-Wendt and CW Hahl were sold effective December 1996.
During 1995, nine leases were sold for approximately $271,700. The Kloh D
was sold effective September 1995, the Robinson E was sold effective October
1995 and the Percy Jones, Percy Jones B, Ares State, B. Davis, State 157-G,
McGee Heirs #1 and Grayburg were sold effective November 1995.
During 1994, three leases were sold for approximately $65,100. The Litz #1
was sold effective January 1994 and the Tony Quinn #1 and Tony Quinn #2 were
sold effective August 1994.
Significant Properties
The following table reflects the significant properties in which the
Partnership has an interest:
Date
Purchased No. of Proved Reserves*
Name and Location and Interest Wells Oil (bbls) Gas (mcf)
Freer Acquisition 9/91 at .2% 26 366,578 241,826
Duval County, to 43.5% net
Texas profits interest
NE Vacuum ABO 9/91 at 25% 7 108,195 104,544
Acquisition to 50% net
Lea County, profits interest
New Mexico
TXL Beach 3/92 at 37.5% 7 85,142 -
Acquisition, to 50% net
Sterling County, profits interest
Texas
*The reserve estimates were prepared as of January 1, 1997, 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 operation conditions, price and costs, as of the date
the estimation is made. Prices may include consideration of changes in
existing price provided only by contractual arrangements, but not on
escalations based upon future conditions.
An oil price of $24.01 per barrel was used in the preparation of the reserve
report as of January 1, 1997. The West Texas Intermediate posted price at
December 31, 1996 of $24.25 was used as the beginning basis for the oil
price. Oil price adjustments from $24.25 per barrel were made in the
individual evaluations to allow for the average difference between recent
prices actually received (current prices) and the West Texas Intermediate
posted price on the sales date. This effectively adjusts for temperature,
gravity, transportation and impurities on an individual property basis to
arrive at a fair value for the selling price.
A gas price of $3.67 per mcf was used in the preparation of the reserve
report as of January 1, 1997. The El Paso Permian Basin Index posted price
at December 31, 1996 of $3.59 was used as the beginning basis for the gas
price. Gas price adjustments from $3.59 per mcf were made in the individual
evaluations to allow for the average difference between recent prices
actually received (current prices) and the El Paso Permian Basin Index posted
price on the sales date. This effectively adjusts for temperature, gravity,
transportation and impurities on an individual property basis to arrive at a
fair value for the selling price.
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 1996.
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. Basic changes in past reserve estimates occur
annually. 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 the industry audit
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, proved developed non-producing and proved undeveloped. All of the
proved reserves are included in the engineering reports which evaluate the
Partnership's present reserves.
Because the Partnership does not engage in drilling activities, the
development of proved undeveloped reserves is conducted pursuant to farm-out
arrangements with the Managing General Partner or unrelated third parties.
Generally, the Partnership retains a carried interest such as an overriding
royalty interest under the terms of a farm-out, or receives cash. The
Partnership or the owners of properties in which the Partnership owns an
interest can engage in workover projects or supplementary recovery projects,
for example, to extract behind the pipe reserves which qualify as proved
developed non-producing reserves. See Part II, Item 7, Management's
Discussion and Analysis of Financial Condition and Results of Operations.
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 1996 through the solicitation of proxies or otherwise.
Part II
Item 5. Market for the Registrant's Common Equity and Related Stockholder
Matters
Market Information
Limited partnership interests, or units, in the Partnership were initially
offered and sold for a price of $500. Limited partner units are not traded
on any exchange and there is no public or organized trading market for them.
The Managing General Partner has become aware of certain limited and sporadic
transfers of units between limited partners and third parties, but has no
verifiable information regarding the prices at which such units have been
transferred. Further, a transferee may not become a substitute limited
partner without the consent of the Managing General Partner.
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 NationsBank, 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. In 1996, 208 limited
partner units were tendered to and purchased by the Managing General Partner
at an average base price of $207.91 per unit. As of December 31, 1995 and
1994, no limited partner units were purchased by the Managing General
Partner.
Number of Limited Partner Interest Holders
As of December 31, 1996, there were 615 holders of limited partner units in
the Partnership.
Distributions
Pursuant to Article III, Section 3.05 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 investments in producing oil and gas
properties, less (i) General and Administrative Costs, (ii) Operating Costs,
and (iii) any reserves necessary to meet current and anticipated needs of the
Partnership, as determined in the sole discretion of the Managing General
Partner."
During 1996, twelve monthly distributions were made totaling $846,613, with
$769,213 distributed to the limited partners and $77,400 to the general
partners. For the year ended December 31, 1996, distributions of $68.80 per
limited partner unit were made, based upon 11,181 limited partner units
outstanding. During 1995, twelve monthly distributions were made totaling
$553,400, with $509,000 distributed to the limited partners and $44,400 to
the general partners. For the year ended December 31, 1995, distributions of
$45.52 per limited partner unit were made, based on 11,181 limited partner
units outstanding. During 1994, twelve monthly distributions were made
totaling $566,493, with $516,343 distributed to the limited partners and
$50,150 to the general partners. For the year ended December 31, 1994,
distributions of $46.18 per limited partner unit were made, based on 11,181
limited partner units outstanding.
Item 6. Selected Financial Data
The following selected financial data for the years ended December 31, 1996,
1995, 1994, 1993 and 1992 should be read in conjunction with the financial
statements included in Item 8:
Years ended December 31,
-------------------------------------------------------
1996 1995 1994 1993 1992
---- ---- ---- ---- ----
Revenues $ 608,727 574,832 566,263 922,576 916,228
Net income
(loss) 388,231 285,783 172,677 (589,083) 336,628
Partners' share
of net income
(loss):
General
partners 52,720 49,078 47,768 82,589 80,547
Limited
partners 335,511 236,705 124,909 (671,672) 256,081
Limited partners'
net income (loss)
per unit 30.01 21.17 11.17 (60.07) 22.90
Limited partners'
cash distributions
per unit 68.80 45.52 46.18 71.58 67.97
Total assets $ 1,844,235 2,302,625 2,570,909 2,965,768 4,460,581
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
The Partnership was formed to acquire nonoperating interests in producing oil
and gas properties, to produce and market crude oil and natural gas produced
from such properties and to distribute any net proceeds from operations to
the general and limited partners. Net revenues from producing oil and gas
properties are not reinvested in other revenue producing assets except to the
extent that producing facilities and wells are reworked or where methods are
employed to improve or enable more efficient recovery of oil and gas
reserves. The economic life of the Partnership thus depends on the period
over which the Partnership's oil and gas reserves are economically
recoverable.
Increases or decreases in Partnership revenues and, therefore, distributions
to partners will depend primarily on changes in the prices received for
production, changes in volumes of production sold, lease operating expenses,
enhanced recovery projects, offset drilling activities pursuant to farm-out
arrangements and on the depletion of wells. Since wells deplete over time,
production can generally be expected to decline from year to year.
Well operating costs and general and administrative costs usually decrease
with production declines; however, these costs may not decrease
proportionately. Net income available for distribution to the limited
partners is therefore expected to fluctuate in later years based on these
factors.
Based on current conditions, management anticipates performing workovers
during the next few years to enhance production. The Partnership could
possibly experience the following changes; a slight increase in 1997, another
increase in 1998 and 1999, leveling off in 2000 and beginning a decline in
2001.
Results of Operations
A. 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 $ 20.01 16.54 21%
Average price per mcf of gas $ 2.13 1.48 44%
Oil production in barrels 59,200 76,400 (23%)
Gas production in mcf 135,500 177,400 (24%)
Income from net profits interests $ 603,894 571,313 6%
Partnership distributions $ 846,613 553,400 53%
Limited partner distributions $ 769,213 509,000 51%
Per unit distribution to limited
partners $ 68.80 45.52 51%
Number of limited partner units 11,181 11,181
Revenues
The Partnership's income from net profits interests increased to $603,894
from $571,313 for the years ended December 31, 1996 and 1995, respectively,
an increase of 6%. 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 21%, or $3.47 per barrel, resulting in an
increase of approximately $265,100 in income from net profits interests.
Oil sales represented 80% of total oil and gas sales during the year
ended December 31, 1996 as compared to 83% 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 44%, or $.65 per mcf, resulting in an increase
of approximately $115,300 in income from net profits interests.
The total increase in income from net profits interests due to the change
in prices received from oil and gas production is approximately $380,400.
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.
2. Oil production decreased approximately 17,200 barrels or 23% during the
year ended December 31, 1996 as compared to the year ended December 31,
1995, resulting in a decrease of approximately $344,200 in income from
net profits interests.
Gas production decreased approximately 41,900 mcf or 24% during the same
period, resulting in a decrease of approximately $89,200 in income from
net profits interests.
The total decrease in income from net profits interests due to the change
in production is approximately $433,400. The decrease is primarily a
result of property sales.
3. Lease operating costs and production taxes were 9% lower, or
approximately $86,300 less during the year ended December 31, 1996 as
compared to the year ended December 31, 1995.
Costs and Expenses
Total costs and expenses decreased to $220,496 from $289,049 for the years
ended December 31, 1996 and 1995, respectively, a decrease of 24%. The
decrease is the result of lower general and administrative expense and
depletion expense.
1. General and administrative costs consists of independent accounting and
engineering fees, computer services, postage, and Managing General
Partner personnel costs. General and administrative costs decreased 3%
or approximately $2,500 during the year ended December 31, 1996 as
compared to the year ended December 31, 1995.
2. Depletion expense decreased to $137,000 for the year ended December 31,
1996 from $196,000 for the same period in 1995. This represents a
decrease of 30%. 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 costs. The impact of the revision would have decreased
depletion expense approximately $23,000 as of December 31, 1995.
B. General Comparison of the Years Ended December 31, 1995 and 1994
The following table provides certain information regarding performance
factors for the years ended December 31, 1995 and 1994:
Year Ended Percentage
December 31, Increase
1995 1994 (Decrease)
---- ---- ----------
Average price per barrel of oil $ 16.54 15.18 9%
Average price per mcf of gas $ 1.48 1.76 (16%)
Oil production in barrels 76,400 81,900 (7%)
Gas production in mcf 177,400 234,300 (24%)
Income from net profits interests $ 571,313 563,324 1%
Partnership distributions $ 553,400 566,493 (2%)
Limited partner distributions $ 509,000 516,343 (1%)
Per unit distribution to limited
partners $ 45.52 46.18 (1%)
Number of limited partner units 11,181 11,181
Revenues
The Partnership's income from net profits interests increased to $571,313
from $563,324 for the years ended December 31, 1995 and 1994, respectively,
an increase of 1%. The principal factors affecting the comparison of the
years ended December 31, 1995 and 1994 are as follows:
1. The average price for a barrel of oil received by the Partnership
increased during the year ended December 31, 1995 as compared to the
year ended December 31, 1994 by 9%, or $1.36 per barrel, resulting in an
increase of approximately $111,400 in income from net profits interests.
Oil sales represented 83% of total oil and gas sales during the year
ended December 31, 1995 as compared to 75% during the year ended
December 31, 1994.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 16%, or $.28 per mcf, resulting in
a decrease of approximately $65,600 in income from net profits
interests.
The net total increase in income from net profits interests due to the
change in prices received from oil and gas production is approximately
$45,800. 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.
2. Oil production decreased approximately 5,500 barrels or 7% during the
year ended December 31, 1995 as compared to the year ended December 31,
1994, resulting in a decrease of approximately $91,000 in income from
net profits interests.
Gas production decreased approximately 56,900 mcf or 24% during the same
period, resulting in a decrease of approximately $84,200 in income from
net profits interests.
The total decrease in income from net profits interests due to the
change in production is approximately $175,200.
3. Lease operating costs and production taxes were 12% lower, or
approximately $136,000 less during the year ended December 31, 1995 as
compared to the year ended December 31, 1994.
Costs and Expenses
Total costs and expenses decreased to $289,049 from $393,586 for the years
ended December 31, 1995 and 1994, respectively, a decrease of 27%. The
decline is the result of a decrease in general and administrative costs and
depletion expense.
1. General and administrative costs consists of independent accounting and
engineering fees, computer services, postage, and Managing General
Partner personnel costs. General and administrative costs decreased
approximately $4,500 or 5% during the year ended December 31, 1995 as
compared to the year ended December 31, 1994.
2. Depletion expense decreased to $196,000 for the year ended December 31,
1995 from $296,000 for the same period in 1994. This represents a
decrease of 34%. 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. Consequently,
depletion will usually fluctuate in direct relation to oil and gas
revenues. As noted above, oil and gas revenues declined due to a
decrease in gas prices and oil and gas production for the year ended
December 31, 1995 as compared to the same period for 1994.
C. Revenue and Distribution Comparison
Partnership net income for the years ended December 31, 1996, 1995 and 1994
was $388,231 in 1996, $285,783 in 1995 and $172,677 in 1994. Excluding the
effects of depreciation, depletion and amortization, net income would have
been $527,197 in 1996, $490,783 in 1995 and $477,677 in 1994.
Correspondingly, Partnership distributions for the years ended December 31,
1996, 1995 and 1994 were $846,613, $553,400 and $566,493, respectively.
These differences are indicative of the changes in oil and gas prices,
production and property sales.
The sources for the 1996 distributions of $846,613 were oil and gas
operations of approximately $494,100 and property sales of approximately
$127,200, with the balance from available cash on hand at the beginning of
the period. The sources for the 1995 distributions of $553,400 were oil and
gas operations of approximately $502,200 and property sales of approximately
$271,700, resulting in excess cash for contingencies or subsequent
distributions. The sources for the 1994 distributions of $566,493 were oil
and gas operations of approximately $503,500 and property sales of
approximately $65,100, resulting in excess cash for contingencies or
subsequent distributions.
Total distributions during the year ended December 31, 1996 were $846,613 of
which $769,213 was distributed to the limited partners and $77,400 to the
general partners. The per unit distribution to limited partners during the
same period was $68.80. Total distributions during the year ended December
31, 1995 were $553,400 of which $509,000 was distributed to the limited
partners and $44,400 to the general partners. The per unit distribution to
limited partners during the same period was $45.52. Total distributions
during the year ended December 31, 1994 were $566,493 of which $516,343 was
distributed to the limited partners and $50,150 to the general partners. The
per unit distribution to limited partners during the same period was $46.18.
Since inception of the Partnership, cumulative monthly cash distributions of
$3,866,971 have been made to the partners. As of December 31, 1996,
$3,523,958 or $315.17 per limited partner unit, has been distributed to the
limited partners, representing a 63% return of the capital contributed.
Liquidity and Capital Resources
The primary source of cash is from operations, the receipt of income from
net profits interests in oil and gas properties. The Partnership knows of no
material change, nor does it anticipate any such change.
Cash flows provided by operating activities were approximately $494,100 in
1996 compared to approximately $502,200 in 1995 and approximately $503,500 in
1994. The primary source of the 1996 cash flow from operating activities was
profitable operations.
Cash flows provided by investing activities were approximately $127,200 in
1996 compared to approximately $271,700 in 1995 and approximately $65,100 in
1994. The principal source of the 1996 cash flow from investing activities
was from the sale of oil and gas properties.
Cash flows used in financing activities were approximately $846,600 in 1996
compared to approximately $553,400 in 1995 and approximately $567,500 in
1994. The only use in financing activities was the distributions to
partners.
As of December 31, 1996, the Partnership had approximately $254,500 in
working capital. The Managing General Partner knows of no unusual
contractual commitments and believes the revenue generated from operation are
adequate to meet the needs of the Partnership.
Item 8. Financial Statements and Supplementary Data
Index to Financial Statements
Page
Report of Independent Accountants. . . . . . . . . . . . . . . . . . . .20
Balance Sheets . . . . . . . . . . . . . . . . . . . . . . . . . . . . .21
Statements of Operations . . . . . . . . . . . . . . . . . . . . . . . .22
Statement of Changes in Partners' Equity . . . . . . . . . . . . . . . .23
Statements of Cash Flows . . . . . . . . . . . . . . . . . . . . . . . .24
Notes to Financial Statements. . . . . . . . . . . . . . . . . . . . . .26
REPORT OF INDEPENDENT ACCOUNTANTS
To the Partners
Southwest Royalties Institutional
Income Fund X-B, L.P.
Midland, Texas
We have audited the accompanying balance sheets of Southwest Royalties
Institutional Income Fund X-B, L.P. as of December 31, 1996 and 1995, and the
related statements of operations, changes in partners' equity and cash flows
for each of the three years in the period ended December 31, 1996. 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 Royalties
Institutional Income Fund X-B, L.P. as of December 31, 1996 and 1995, and the
results of its operations and its cash flows for each of the three years in
the period ended December 31, 1996, in conformity with generally accepted
accounting principles.
JOSEPH DECOSIMO AND COMPANY
A Tennessee Registered Limited Liability Partnership
Chattanooga, Tennessee
March 14, 1997
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Balance Sheets
December 31, 1996 and 1995
1996 1995
---- ----
Assets
Current assets:
Cash and cash equivalents $ 16,680 242,006
Receivable from Managing General Partner 137,799 104,790
Other receivable 100,000 -
--------- ---------
Total current assets 254,479 346,796
--------- ---------
Oil and gas properties - using the
full-cost method of accounting 4,244,847 4,471,954
Less accumulated depreciation,
depletion and amortization 2,655,091 2,518,091
--------- ---------
Net oil and gas properties 1,589,756 1,953,863
--------- ---------
Organization costs, net of amortization of
$43,500 for 1995 - 1,966
--------- ---------
$ 1,844,235 2,302,625
========= =========
Liabilities and Partners' Equity
Current liability - Distribution payable $ - 8
--------- ---------
Partners' equity:
General partners (6,433) 18,247
Limited partners 1,850,668 2,284,370
--------- ---------
Total partners' equity 1,844,235 2,302,617
--------- ---------
$ 1,844,235 2,302,625
========= =========
The accompanying notes are an integral
part of these financial statements.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Statements of Operations
Years ended December 31, 1996, 1995 and 1994
1996 1995 1994
---- ---- ----
Revenues
Income from net profits interests $ 603,894 571,313 563,324
Interest from operations 4,833 3,519 2,939
------- ------- -------
608,727 574,832 566,263
------- ------- -------
Expenses
General and administrative 81,530 84,049 88,586
Depreciation, depletion and
amortization 138,966 205,000 305,000
------- ------- -------
220,496 289,049 393,586
------- ------- -------
Net income $ 388,231 285,783 172,677
======= ======= =======
Net income allocated to:
Managing General Partner $ 47,448 44,170 42,991
======= ======= =======
General Partner $ 5,272 4,908 4,777
======= ======= =======
Limited partners $ 335,511 236,705 124,909
======= ======= =======
Per limited partner unit $ 30.01 21.17 11.17
======= ======= =======
The accompanying notes are an integral
part of these financial statements.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Statement of Changes in Partners' Equity
Years ended December 31, 1996, 1995 and 1994
General Limited
Partners Partners Total
-------- -------- -----
Balance at December 31, 1993 $ 15,951 2,948,099 2,964,050
Net income 47,768 124,909 172,677
Distributions (50,150) (516,343) (566,493)
------- --------- ---------
Balance at December 31, 1994 13,569 2,556,665 2,570,234
Net income 49,078 236,705 285,783
Distributions (44,400) (509,000) (553,400)
------- --------- ---------
Balance at December 31, 1995 18,247 2,284,370 2,302,617
Net income 52,720 335,511 388,231
Distributions (77,400) (769,213) (846,613)
------- --------- ---------
Balance at December 31, 1996 $ (6,433) 1,850,668 1,844,235
======= ========= =========
The accompanying notes are an integral
part of these financial statements.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Statements of Cash Flows
Years ended December 31, 1996, 1995 and 1994
1996 1995 1994
---- ---- ----
Cash flows from operating activities:
Cash received from net profits
interests $ 570,794 583,375 589,177
Cash paid to suppliers (81,530) (84,700) (88,585)
Interest received 4,833 3,519 2,939
-------- -------- --------
Net cash provided by operating
activities 494,097 502,194 503,531
-------- -------- --------
Cash flows provided by investing
activities:
Sale of oil and gas properties 127,198 271,657 65,143
-------- -------- --------
Cash flows used in financing activities:
Distributions to partners (846,621) (553,416) (567,537)
-------- -------- --------
Net increase (decrease) in cash and
cash equivalents (225,326) 220,435 1,137
Beginning of period 242,006 21,571 20,434
-------- -------- --------
End of period $ 16,680 242,006 21,571
======== ======== ========
(continued)
The accompanying notes are an integral
part of these financial statements.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Statements of Cash Flows, continued
Years ended December 31, 1996, 1995 and 1994
1996 1995 1994
---- ---- ----
Reconciliation of net income to net
cash provided by operating activities:
Net income $ 388,231 285,783 172,677
Adjustments to reconcile net income
to net cash provided by operating
activities:
Depreciation, depletion and
amortization 138,966 205,000 305,000
(Increase) decrease in receivables (33,100) 12,062 25,854
Decrease in payables - (651) -
------- ------- -------
Net cash provided by operating
activities $ 494,097 502,194 503,531
======= ======= =======
Supplemental schedule of noncash
investing and financing activities:
Sale of oil and gas properties
included in receivable from
Managing General Partner $ - 91 -
Sale of oil and gas properties
included in other receivable $ 100,000 - -
The accompanying notes are an integral
part of these financial statements.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
1. 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 units of 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, 1996, 1995 and 1994 the
net capitalized costs did not exceed the estimated present value of the
oil and gas reserves.
The Partnership's interest in oil and gas properties consists of net
profits interests in proved properties located within the continental
United States. A net profits interest is created when the owner of a
working interest in a property enters into an arrangement providing that
the net profits interest owner will receive a stated percentage of the
net profit from the property. The net profits interest owner will not
otherwise participate in additional costs and expenses of the property.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
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.
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 gas-
balancing arrangements. Under this method the Partnership recognizes
sales revenue on all gas sold. As of December 31, 1996, the Partnership
was under produced by 2,195 mcf of gas and as of December 31, 1995 and
1994 was over produced 7 and 1,208 mcf of gas, respectively.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
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 net oil and gas properties at December 31, 1996 and 1995 is
$526,778 and $439,280, respectively, more 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.
Number of Limited Partner Units
As of December 31, 1996, 1995 and 1994 there were 11,181 limited partner
units outstanding.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
2. Organization
Southwest Royalties Institutional Income Fund X-B, L.P. was organized
under the laws of the state of Delaware on November 27, 1990 for the
purpose of acquiring producing oil and gas properties and to produce and
market crude oil and natural gas produced from such properties for a
term of 50 years, unless terminated at an earlier date as provided for
in the Partnership Agreement. The Partnership sells 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 and H. H. Wommack, III, as the
individual general partner. Revenues, costs and expenses are allocated
as follows:
Limited General
Partners Partners
-------- --------
Interest income on capital contributions 100% -
Oil and gas sales 90% 10%
All other revenues 90% 10%
Organization and offering costs (1) 100% -
Amortization of organization costs 100% -
Property acquisition costs 100% -
Gain/loss on property disposition 90% 10%
Operating and administrative costs (2) 90% 10%
Depreciation, depletion and amortization
of oil and gas properties 100% -
All other costs 90% 10%
(1) All organization costs in excess of 3% 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 3% 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.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
3. Oil and Gas Properties
Costs incurred in connection with the Partnership's oil and gas
producing activities for the years ended December 31, 1996, 1995 and
1994 are as follows:
1996 1995 1994
---- ---- ----
Depreciation, depletion and
amortization $ 137,000 196,000 296,000
======= ======= =======
All of the Partnership's properties were proved when acquired.
4. Commitments and Contingent Liabilities
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, 1996, 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.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
5. 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
$106,000, $118,000 and $130,000 for the years ended December 31, 1996,
1995 and 1994, 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 of the Managing General Partner perform various
oilfield services for properties in which the Partnership owns an
interest. Such services aggregated approximately $150, $1,000 and
$3,000 for the years ended December 31, 1996, 1995 and 1994,
respectively. 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
$72,000 during 1996, 1995 and 1994 as an administrative fee for
reimbursement of indirect general and administrative expenses.
Receivables from Southwest Royalties, Inc., the Managing General
Partner, of approximately $137,799 and $104,790 are from oil and gas
production, net of lease operating costs and production taxes, as of
December 31, 1996 and 1995, respectively.
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 $50 for the year ended December 31, 1996.
There were no legal services provided as of December 31, 1995 and
approximately $100 for the year ended December 31, 1994.
6. Major Customers and Significant Leases
During 1996, three customers purchased 33%, 15% and 12% of the
Partnership's oil and gas production. During 1995, three customers
purchased 32%, 13% and 10% of the Partnership's oil and gas production.
During 1994, two customers purchased 28% and 11% of the Partnership's
oil and gas production.
During 1996, one lease accounted for 19% of the Partnership's gross
revenue. During 1995, one lease accounted for 17% of the Partnership's
gross revenues.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
7. 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, 1994 580,000 1,443,000
Revisions of previous estimates 179,000 387,000
Production (82,000) (234,000)
Sale of minerals in place - (198,000)
------- ---------
December 31, 1994 677,000 1,398,000
Revisions of previous estimates 178,000 8,000
Production (76,000) (177,000)
Sale of minerals in place (63,000) (53,000)
------- ---------
December 31, 1995 716,000 1,176,000
Revisions of previous estimates 103,000 193,000
Production (59,000) (136,000)
Sale of minerals in place (33,000) (49,000)
------- ---------
December 31, 1996 727,000 1,184,000
======= =========
Proved developed reserves -
December 31, 1994 625,000 1,100,000
======= =========
December 31, 1995 698,000 1,099,000
======= =========
December 31, 1996 709,000 1,110,000
======= =========
All of the Partnership's reserves are located within the continental
United States.
Southwest Royalties Institutional Income Fund X-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
7. 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, 1996, 1995 and 1994 is
presented below:
1996 1995 1994
Future cash inflows, net of
production and development
costs $ 9,904,000 5,846,000 5,754,000
10% annual discount for
estimated timing of cash
flows 4,140,000 2,241,000 2,039,000
---------- --------- ---------
Standardized measure of
discounted future net cash
flows $ 5,764,000 3,605,000 3,715,000
========== ========= =========
The principal sources of change in the standardized measure of
discounted future net cash flows for the years ended December 31, 1996,
1995 and 1994 are as follows:
1996 1995 1994
Sales of oil and gas produced,
net of production costs $ (1,159,000) (932,000) (955,000)
Changes in price 3,229,000 605,000 1,289,000
Revisions to estimated
production costs (102,000) (718,000) 147,000
Sales of minerals in place (152,000) (221,000) (126,000)
Revisions of previous
quantities estimates (205,000) 821,000 287,000
Accretion of discount 548,000 335,000 301,000
Discounted future net
cash flows -
Beginning of year 3,605,000 3,715,000 2,772,000
---------- --------- ---------
End of year $ 5,764,000 3,605,000 3,715,000
========== ========= =========
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.
Item 9. Changes in and Disagreements With Accountants on Accounting and
Financial Disclosure
None.
Part III
Item 10. Directors and Executive Officers of the Registrant
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 41 Chairman of the Board, President,
Chief Executive Officer, Treasurer
and Director
H. Allen Corey 41 Secretary and Director
Bill E. Coggin 42 Vice President and Chief Financial
Officer
Richard E. Masterson 43 Vice President, Exploration and
Acquisitions
Jon P. Tate 39 Vice President, Land and Assistant
Secretary
Joel D. Talley 35 Vice President, Acquisitions and
Exploitation Manager
R. Douglas Keathley 41 Vice President, Operations
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.
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.
Richard E. Masterson, Vice President, Exploration and Acquisitions, first
became associated with the Managing General Partner as a geological
consultant in 1985. He was employed as a petroleum geologist by Grand Banks
Energy (1980-1985), Monsanto (1977-1980) and Texaco, Inc. (1974-1976) prior
to joining the Managing General Partner. Mr. Masterson is a member of the
Society of Economic Paleontologists and Mineralogists and the West Texas
Geological Society. Mr. Masterson received his B.A. degree in Geology from
Trinity University.
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.
Key Employees
Accounting and Administrative Officer - Debbie A. Brock, age 44, 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 47, 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 30, 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 55, 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 40, 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.
Vice President, Marketing - Steve J. Person, age 38, joined the Managing
General Partner 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.
Investor Relations Manager - Sandra K. Flournoy, age 50, 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
$72,000 during 1996, 1995 and 1994 as an administrative fee.
Item 12. Security Ownership of Certain Beneficial Owners and Management
There are no limited partners who own of record, or are known by the Managing
General Partner to beneficially own, more than five percent of the
Partnership's limited partnership interests.
The Managing General Partner owns a nine percent interest as a general
partner. Through prior purchases, the Managing General Partner also owns 208
limited partner units, or a 1.9% limited partner interest. The Managing
General Partner total percentage interest ownership in the Partnership is
10.7%.
No officer or director of the Managing General Partner owns Units in the
Partnership. H. H. Wommack, III, as the individual general partner of the
Partnership, owns a one percent interest in the Partnership as a general
partner. The officers and directors of the Managing General Partner are
considered beneficial owners of the limited partner units acquired by the
Managing General Partner by virtue of their status as such. A list of
beneficial owners of limited partner units, acquired by the Managing General
Partner, is as follows:
Amount and
Nature of Percent
Name and Address of Beneficial of
Title of Class Beneficial Owner Ownership Class
- ------------------- --------------------------- --------------- -------
Limited Partnership Southwest Royalties, Inc. Directly Owns 1.9%
Interest Managing General Partner 208 Units
407 N. Big Spring Street
Midland, TX 79701
Limited Partnership H. H. Wommack, III Indirectly Owns 1.9%
Interest Chairman of the Board, 208 Units
President, CEO, Treasurer
and Director of Southwest
Royalties, Inc., the
Managing General Partner
407 N. Big Spring Street
Midland, TX 79701
Limited Partnership H. Allen Corey Indirectly Owns 1.9%
Interest Secretary and Director of 208 Units
Southwest Royalties, Inc.,
the Managing General
Partner
633 Chestnut Street
Chattanooga, TN 37450-1800
Limited Partnership Bill E. Coggin Indirectly Owns 1.9%
Interest Vice President and CFO of 208 Units
Southwest Royalties, Inc.,
the Managing General
Partner
407 N. Big Spring Street
Midland, TX 79701
Limited Partnership Richard E. Masterson Indirectly Owns 1.9%
Interest Vice President, Exploration 208 Units
and Acquisitions of
Southwest Royalties, Inc.,
the Managing General
Partner
407 N. Big Spring Street
Midland, TX 79701
Limited Partnership Jon P. Tate Indirectly Owns 1.9%
Interest Vice President, Land and 208 Units
Assistant Secretary of
Southwest Royalties, Inc.,
the Managing General
Partner
407 N. Big Spring Street
Midland, TX 79701
Amount and
Nature of Percent
Name and Address of Beneficial of
Title of Class Beneficial Owner Ownership Class
- ------------------- --------------------------- --------------- -------
Limited Partnership Joel D. Talley Indirectly Owns 1.9%
Interest Vice President, 208 Units
Acquisitions and
Exploitation Manager of
Southwest Royalties, Inc.,
the Managing General Partner
407 N. Big Spring Street
Midland, TX 79701
Limited Partnership R. Douglas Keathley Indirectly Owns 1.9%
Interest Vice President, Operations 208 Units
of Southwest Royalties, Inc.,
the Managing General Partner
407 N. Big Spring Street
Midland, TX 79701
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 1996, the Managing General Partner received $72,000 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 ar operated by the Managing General Partner, who
was paid approximately $106,000 for administrative overhead attributable to
operating such properties during 1996.
Certain subsidiaries of the Managing General Partner perform various oilfield
services for properties in which the Partnership owns an interest. Such
services aggregated approximately $150 for the year ended December 31, 1996.
The law firm of Miller & Martin, of which H. Allen Corey, an officer and
director of the Managing General Partner, is a partner, is counsel to the
Partnership. Legal services rendered by Miller & Martin to the Partnership
during 1996 were approximately $50, which constitutes an immaterial portion
of that firm's business. Subsequent to December 31, 1996, the counsel to the
Partnership, H. Allen Corey, became a partner in the law firm Baker,
Donelson, Bearman & Caldwell.
In the opinion of management, the terms of the above transactions are similar
to ones with unaffiliated third parties.
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 --
Report of Independent Accountants
Balance Sheets
Statements of Operations
Statement of Changes in Partners' Equity
Statements of Cash Flows
Notes to Financial Statements
(2) Schedules required by Article 12 of Regulation S-X are
either omitted because they are not applicable or because
the required information is shown in the financial
statements or the notes thereto.
(3) Exhibits:
4 (a) Certificate of Limited Partnership of Southwest
Royalties Institutional Income Fund X-B, L.P.,
dated November 27, 1990. (Incorporated by
reference from Partnership's Form 10-K for the
fiscal year ended December 31, 1990.)
(b) Agreement of Limited Partnership of Southwest
Royalties Institutional Income Fund X-B, L.P.
dated November 27, 1990. (Incorporated by
reference from Partnership's Form 10-K for the
fiscal year ended December 31, 1991.)
27 Financial Data Schedule
(b) Reports on Form 8-K
There were no reports filed on Form 8-K during the quarter
ended December 31, 1996.
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 Royalties Institutional Income
Fund X-B, 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 26, 1997
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 26, 1997
By: /s/ H. Allen Corey
-----------------------------
H. Allen Corey, Secretary and
Director
Date: March 26, 1997