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FORM 10-Q
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
(Mark One)
(X) QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 1999
OR
( ) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ________________ to ________________
Commission file number 0-16494
Southwest Royalties Institutional Income Fund VIII-B, L.P.
(Exact name of registrant as specified
in its limited partnership agreement)
Delaware 75-2220418
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
407 N. Big Spring, Suite 300
Midland, Texas 79701
(Address of principal executive offices)
(915) 686-9927
(Registrant's telephone number,
including area code)
Indicate by check mark whether registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act
of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to
such filing requirements for the past 90 days:
Yes X No
The total number of pages contained in this report is 17.
<PAGE>
PART I. - FINANCIAL INFORMATION
Item 1. Financial Statements
The unaudited condensed financial statements included herein have been
prepared by the Registrant (herein also referred to as the "Partnership")
in accordance with generally accepted accounting principles for interim
financial information and with the instructions to Form 10-Q and Rule 10-01
of Regulation S-X. Accordingly, they do not include all of the information
and footnotes required by generally accepted accounting principles for
complete financial statements. In the opinion of management, all
adjustments necessary for a fair presentation have been included and are of
a normal recurring nature. The financial statements should be read in
conjunction with the audited financial statements and the notes thereto for
the year ended December 31, 1998 which are found in the Registrant's Form
10-K Report for 1998 filed with the Securities and Exchange Commission.
The December 31, 1998 balance sheet included herein has been taken from the
Registrant's 1998 Form 10-K Report. Operating results for the three and
six month periods ended June 30, 1999 are not necessarily indicative of the
results that may be expected for the full year.
<PAGE>
Southwest Royalties Institutional Income Fund VIII-B, L.P.
Balance Sheets
June 30, December 31,
1999 1998
--------- ------------
(unaudited)
Assets
Current assets:
Cash and cash equivalents $ 24,112 33,562
Receivable from Managing General Partner 78,995 21,626
--------- ---------
Total current assets 103,107 55,188
--------- ---------
Oil and gas properties - using the
full cost method of accounting 4,133,496 4,133,496
Less accumulated depreciation,
depletion and amortization 3,631,058 3,608,058
--------- ---------
Net oil and gas properties 502,438 525,438
--------- ---------
$ 605,545 580,626
========= =========
Liabilities and Partners' Equity
Current liability - Distributions payable $ 177 532
--------- ---------
Partners' equity:
General partners 4,620 (208)
Limited partners 600,748 580,302
--------- ---------
Total partners' equity 605,368 580,094
--------- ---------
$ 605,545 580,626
========= =========
<PAGE>
Southwest Royalties Institutional Income Fund VIII-B, L.P.
Statements of Operations
(unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
1999 1998 1999 1998
Revenues
Income from net profits
interests $ 94,660 49,840 138,252 141,173
Interest 306 822 534 1,633
------- ------- ------- -------
94,966 50,662 138,786 142,806
------- ------- ------- -------
Expenses
General and administrative 20,383 21,592 40,512 48,990
Depreciation, depletion and
amortization 10,000 51,000 23,000 93,000
------- ------- ------- -------
30,383 72,592 63,512 141,990
------- ------- ------- -------
Net income (loss) $ 64,583 (21,930) 75,274 816
======= ======= ======= =======
Net income (loss) allocated to:
Managing General Partner $ 6,712 2,616 8,845 8,443
======= ======= ======= =======
General Partner $ 746 291 983 939
======= ======= ======= =======
Limited Partners $ 57,125 (24,837) 65,446 (8,566)
======= ======= ======= =======
Per limited partner unit $ 5.63 (2.45) 6.45 (.84)
======= ======= ======= =======
<PAGE>
Southwest Royalties Institutional Income Fund VIII-B, L.P.
Statements of Cash Flows
(unaudited)
Six Months Ended
June 30,
1999 1998
Cash flows from operating activities:
Cash received from income from net
profits interests $ 69,165 192,267
Cash paid to suppliers (28,794) (30,137)
Interest received 534 1,633
-------- --------
Net cash provided by operating activities 40,905 163,763
-------- --------
Cash flows provided by investing activities:
Cash received from sale of oil and gas
properties - 52,241
-------- --------
Cash flows used in financing activities:
Distributions to partners (50,355) (205,298)
-------- --------
Net increase (decrease) in cash and cash
equivalents (9,450) 10,706
Beginning of period 33,562 3,347
-------- --------
End of period $ 24,112 14,053
======== ========
(continued)
<PAGE>
Southwest Royalties Institutional Income Fund VIII-B, L.P.
Statements of Cash Flows, continued
(unaudited)
Six Months Ended
June 30,
1999 1998
Reconciliation of net income to net cash
provided by operating activities:
Net income $ 75,274 816
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation, depletion and amortization 23,000 93,000
Decrease (increase) in receivables (69,087) 51,094
Increase in payables 11,718 18,853
------- -------
Net cash provided by operating activities $ 40,905 163,763
======= =======
<PAGE>
Southwest Royalties Institutional Income Fund VIII-B, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
1. Organization
Southwest Royalties Institutional Income Fund VIII-B, L.P. was
organized under the laws of the state of Delaware on November 30,
1987, 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 offering of
limited partner units began March 31, 1988, minimum capital
requirements were met July 11, 1988, with the offering concluded on
March 31, 1989.
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 from net profits interests 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 dispositions 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 Partner and will be
treated as a capital contribution.
2. Summary of Significant Accounting Policies
The interim financial information as of June 30, 1999, and for the
three and six months ended June 30, 1999, is unaudited. Certain
information and footnote disclosures normally included in financial
statements prepared in accordance with generally accepted accounting
principles have been condensed or omitted in this Form 10-Q pursuant
to the rules and regulations of the Securities and Exchange
Commission. However, in the opinion of management, these interim
financial statements include all the necessary adjustments to fairly
present the results of the interim periods and all such adjustments
are of a normal recurring nature. The interim consolidated financial
statements should be read in conjunction with the audited financial
statements for the year ended December 31, 1998.
<PAGE>
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
Southwest Royalties Institutional Income Fund VIII-B, L.P. was organized as
a Delaware limited partnership on November 30, 1987. The offering of such
limited partnership interests began March 31, 1988, minimum capital
requirements were met July 11, 1988, and concluded on March 31, 1989 with
total limited partner contributions of $5,073,500.
The Partnership was formed to acquire royalty and net profits interests in
producing oil and gas properties, to produce and market crude oil and
natural gas produced from such properties, and to distribute the net
proceeds from operations to the limited and general partners. Net revenues
from producing oil and gas properties will not be reinvested in other
revenue producing assets except to the extent that production facilities
and wells are improved or reworked or where methods are employed to improve
or enable more efficient recovery of oil and gas reserves.
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 farmout arrangements, sales of properties, and 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 partners is
therefore expected to fluctuate in later years based on these factors.
Based on current conditions, management does not anticipate performing
workovers during the next two years. The Partnership could possibly
experience a normal decline of 8% to 10% per year.
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.
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 June 30, 1999, the net capitalized costs did not
exceed the estimated present value of oil and gas reserves. The oil price
environment experienced during 1998 had an adverse affect on the Company's
revenues and operating cash flow. Further declines of oil prices during
1999 could result in additional decreases in the carrying value of the
Company's oil and gas properties.
<PAGE>
Results of Operations
A. General Comparison of the Quarters Ended June 30, 1999 and 1998
The following table provides certain information regarding performance
factors for the quarters ended June 30, 1999 and 1998:
Three Months
Ended Percentage
June 30, Increase
1999 1998 (Decrease)
---- ---- ----------
Average price per barrel of oil $ 16.24 13.06 24%
Average price per mcf of gas $ 2.62 2.04 28%
Oil production in barrels 10,600 12,000 (12%)
Gas production in mcf 14,800 10,500 41%
Income from net profits interests $ 94,660 49,840 90%
Partnership distributions $ 50,000 67,000 (25%)
Limited partner distributions $ 45,000 60,300 (25%)
Per unit distribution to limited
partners $ 4.43 5.94 (25%)
Number of limited partner units 10,147 10,147
Revenues
The Partnership's income from net profits interests increased to $94,660
from $49,840 for the quarters ended June 30, 1999 and 1998, respectively,
an increase of 90%. The principal factors affecting the comparison of the
quarters ended June 30, 1999 and 1998 are as follows:
1. The average price for a barrel of oil received by the Partnership
increased during the quarter ended June 30, 1999 as compared to the
quarter ended June 30, 1998 by 24%, or $3.18 per barrel, resulting in
an increase of approximately $38,200 in income from net profits
interests. Oil sales represented 82% of total oil and gas sales during
the quarter ended June 30, 1999 as compared to 88% during the quarter
ended June 30, 1998.
The average price for an mcf of gas received by the Partnership
increased during the same period by 28%, or $.58 per mcf, resulting in
an increase of approximately $6,100 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
$44,300. 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 1,400 barrels or 12% during the
quarter ended June 30, 1999 as compared to the quarter ended June 30,
1998, resulting in a decrease of approximately $22,800 in income from
net profits interests.
Gas production increased approximately 4,300 mcf or 41% during the same
period, resulting in an increase of approximately $11,300 in income
from net profits interests.
The net total decrease in income from net profits interests due to the
change in production is approximately $11,500. The increase in gas
production is due primarily to a workover performed on one lease in the
second quarter of 1999.
3. Lease operating costs and production taxes were 9% lower, or
approximately $12,100 less during the quarter ended June 30, 1999 as
compared to the quarter ended June 30, 1998.
Costs and Expenses
Total costs and expenses decreased to $30,383 from $72,592 for the quarters
ended June 30, 1999 and 1998, respectively, a decrease of 58%. 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 6%
or approximately $1,200 during the quarter ended June 30, 1999 as
compared to the quarter ended June 30, 1998.
2. Depletion expense decreased to $10,000 for the quarter ended June 30,
1999 from $51,000 for the same period in 1998. This represents a
decrease of 80%. 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. Contributing
factors to the decline in depletion expense between the comparative
periods were the increase in the price of oil and gas used to determine
the Partnership's reserves for April 1, 1999 as compared to 1998 and
the decrease in gross oil and gas revenues.
<PAGE>
B. General Comparison of the Six Month Periods Ended June 30, 1999 and
1998
The following table provides certain information regarding performance
factors for the six month periods ended June 30, 1999 and 1998:
Six Months
Ended Percentage
June 30, Increase
1999 1998 (Decrease)
---- ---- ----------
Average price per barrel of oil $ 13.35 13.91 (4%)
Average price per mcf of gas $ 2.26 2.13 6%
Oil production in barrels 21,500 25,300 (15%)
Gas production in mcf 27,800 24,600 13%
Income from net profits interests $ 138,252 141,173 (2%)
Partnership distributions $ 50,000 205,320 (76%)
Limited partner distributions $ 45,000 186,620 (76%)
Per unit distribution to limited
partners $ 4.43 18.39 (76%)
Number of limited partner units 10,147 10,147
Revenues
The Partnership's income from net profits interests decreased to $138,252
from $141,173 for the six months ended June 30, 1999 and 1998,
respectively, a decrease of 2%. The principal factors affecting the
comparison of the six months ended June 30, 1999 and 1998 are as follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the six months ended June 30, 1999 as compared to the
six months ended June 30, 1998 by 4%, or $.56 per barrel, resulting in
a decrease of approximately $14,200 in income from net profits
interests. Oil sales represented 82% of total oil and gas sales during
the six months ended June 30, 1999 as compared to 87% during the six
months ended June 30, 1998.
The average price for an mcf of gas received by the Partnership
increased during the same period by 6%, or $.13 per mcf, resulting in
an increase of approximately $3,200 in income from net profits
interests.
The net total decrease in income from net profits interests due to the
change in prices received from oil and gas production is approximately
$11,000. 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 3,800 barrels or 15% during the
six months ended June 30, 1999 as compared to the six months ended June
30, 1998, resulting in a decrease of approximately $50,700 in income
from net profits interests.
Gas production increased approximately 3,200 mcf or 13% during the same
period, resulting in an increase of approximately $7,200 in income from
net profits interests.
The net total decrease in income from net profits interests due to the
change in production is approximately $43,500.
3. Lease operating costs and production taxes were 20% lower, or
approximately $51,700 less during the six months ended June 30, 1999 as
compared to the six months ended June 30, 1998. The decline in lease
operating costs is primarily in relation to the drop in oil prices
experienced throughout 1998 and into the first six months of 1999,
which made it uneconomical to perform workovers necessary to increase
production and perform major repairs thus making it necessary to shut-
in some wells.
Costs and Expenses
Total costs and expenses decreased to $63,512 from $141,990 for the six
months ended June 30, 1999 and 1998, respectively, a decrease of 55%. 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
17% or approximately $8,500 during the six months ended June 30, 1999
as compared to the six months ended June 30, 1998. The decrease of
general and administrative costs were in part due to additional
accounting costs incurred in 1998 in relation to the outsourcing of K-1
tax package preparation; a change in auditors requiring opinions from
both the predecessors and successor auditors and a new accounting
pronouncement requiring review by the independent auditors of the 10-
Q's. The Managing General Partner has also made an effort to cut back
on general and administrative costs whenever and wherever possible.
2. Depletion expense decreased to $23,000 for the six months ended June
30, 1999 from $93,000 for the same period in 1998. This represents a
decrease of 75%. 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. Contributing
factors to the decline in depletion expense between the comparative
periods were the increase in the price of oil and gas used to determine
the Partnership's reserves for April 1, 1999 as compared to 1998 and
the decrease in gross oil and gas revenues.
<PAGE>
Liquidity and Capital Resources
The primary source of cash is from operations, the receipt of income from
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 $40,900 in
the six months ended June 30, 1999 as compared to approximately $163,800 in
the six months ended June 30, 1998. The primary source of the 1999 cash
flow from operating activities was profitable operations.
There were no cash flows provided by investing activities in the six months
ended June 30, 1999. Cash flows provided by investing activities were
approximately $52,200 in the six months ended June 30, 1998.
Cash flows used in financing activities were approximately $50,400 in the
six months ended June 30, 1999 as compared to approximately $205,300 in the
six months ended June 30, 1998. The only use in financing activities was
the distributions to partners.
Total distributions during the six months ended June 30, 1999 were $50,000
of which $45,000 was distributed to the limited partners and $5,000 to the
general partners. The per unit distribution to limited partners during the
six months ended June 30, 1999 was $4.43. Total distributions during the
six months ended June 30, 1998 were $205,320 of which $186,620 was
distributed to the limited partners and $18,700 to the general partners.
The per unit distribution to limited partners during the six months ended
June 30, 1998 was $18.39.
The source for the 1999 distributions of $50,000 was oil and gas operations
of approximately $40,900, with the balance from available cash on hand at
the beginning of the period. The sources for the 1998 distributions of
$205,320 were oil and gas operations of approximately $163,800 and the sale
of oil and gas properties of $52,200, resulting in excess cash for
contingencies or subsequent distributions.
Since inception of the Partnership, cumulative monthly cash distributions
of $5,631,587 have been made to the partners. As of June 30, 1999,
$5,088,913 or $501.52 per limited partner unit has been distributed to the
limited partners, representing a 100% return of the capital contributed.
As of June 30, 1999, the Partnership had approximately $102,900 in working
capital. The Managing General Partner knows of no unusual contractual
commitments and believes the revenues generated from operations are
adequate to meet the needs of the Partnership.
<PAGE>
Liquidity - Managing General Partner
The Managing General Partner has a highly leveraged capital structure with
over $21.0 million of interest payments due in 1999 on its debt
obligations. Due to severely depressed commodity prices, the Managing
General Partner is experiencing difficulty in generating sufficient cash
flow to meet its obligations and sustain its operations. The Managing
General Partner is currently in the process of renegotiating the terms of
its various obligations with its creditors and/or attempting to seek new
lenders or equity investors. Additionally, the Managing General Partner
would consider disposing of certain assets in order to meet its
obligations.
There can be no assurance that the Managing General Partner's debt
restructuring efforts will be successful or that the lenders will agree to
a course of action consistent with the Managing General Partners
requirements in restructuring the obligations. Even if such agreement is
reached, it may require approval of additional lenders, which is not
assured. Furthermore, there can be no assurance that the sales of assets
can be successfully accomplished on terms acceptable to the Managing
General Partner. Under current circumstances, the Managing General
Partner's ability to continue as a going concern depends upon its ability
to (1) successfully restructure its obligations or obtain additional
financing as may be required, (2) maintain compliance with all debt
covenants, (3) generate sufficient cash flow to meet its obligations on a
timely basis, and (4) achieve satisfactory levels of future earnings. If
the Managing General Partner is unsuccessful in its efforts, it may be
unable to meet its obligations making it necessary to undertake such other
actions as may be appropriate to preserve asset values.
Information Systems for the Year 2000
The Managing General Partner provides all data processing needs of the
Partnership. The Managing General Partner is continuing in its effort to
identify and assess its exposure to the potential Year 2000 software and
imbedded chip processing and date sensitivity issue. Through the Managing
General Partners data processing subsidiary, Midland Southwest Software,
Inc., the Managing General Partner proactively initiated a plan to identify
applicable hardware and software, assess impact and effect, estimate costs,
construct and implement corrective actions, and prepare contingency plans.
Identification & Assessment
The Managing General Partner currently believes it has identified the
internal and external software and hardware that may have date sensitivity
problems. Four critical systems and/or functions were identified: (1) the
proprietary software of the Partnership (OGAS) that is used for oil & gas
property management and financial accounting functions, (2) the DEC VAX/VMS
hardware and operating system, (3) various third-party application software
including lease economic analysis, fixed asset management, geological
applications, and payroll/human resource programs, and (4) External Agents.
The proprietary software of the Partnership is currently in process of
meeting compliance requirements with an estimated completion date of mid-
year 1999. Since this is an internally generated software package, the
Managing General Partner has estimated the cost to be approximately $25,000
by estimating the necessary man-hours. These modifications are being made
by internal staff and do not represent additional costs to the Partnership.
The Managing General Partner has not made contingency plans at this time
since the conversion is ahead of schedule and being handled by Managing
General Partner controlled internal programmers. Given the complexity of
the systems being modified, it is anticipated that some problems may arise,
but with an expected early completion date, the Managing General Partner
feels that adequate time is available to overcome unforeseen delays.
DEC has released a fully compliant version of its operating system that is
used by the Partnership on the DEC VAX system. It will be installed in
August 1999, the Managing General Partner believes that this will solve any
potential problems on the system.
<PAGE>
The Managing General Partner has identified various third-party software
that may have date sensitivity problems and is working with the vendors to
secure solutions as well as prepare contingency plans. After review and
evaluation of the vendor plans and status, the Managing General Partner
believes that the problems will be resolved prior to the year 2000 or the
alternate contingency plan will sufficiently and adequately remediate the
problem so that there is no material disruption to business functions.
The External Agents of the Partnership include suppliers, customers,
owners, vendors, banks, product purchasers including pipelines, and other
oil and gas property operators. The Managing General Partner is in the
process of identifying and communicating with each critical External Agent
about its plan and progress thereof in addressing the Year 2000 issue.
This process is on schedule and the Managing General Partner, at this time,
believes that there should be no material interference or disruption
associated with any of the critical External Agent's functions necessary to
the Partnership's business. The Managing General Partner estimates
completion of this audit by mid-year 1999 and believes that alternate plans
can be devised to circumvent any material problems arising from critical
External Agent noncompliance.
Cost
To date, the Managing General Partner has incurred only minimal internal
man-hour costs for identification, planning, and maintenance. The Managing
General Partner believes that the necessary additional costs will also be
minimal and most will fall under normal and general maintenance procedures
and updates. An accurate cost cannot be determined at this time, but it is
expected that the total cost to remediate all systems to be less than
$50,000.
Risks/Contingency
The failure to correct critical systems of the Partnership, or the failure
of a material business partner or External Agent to resolve critical Year
2000 issues could have a serious adverse impact on the ability of the
Partnership to continue operations and meet obligations. Based on the
Managing General Partner's evaluation and assessment to date, it is
believed that any interruption in operation will be minor and short-lived
and pose no material monetary loss, safety, or environmental risk to the
Partnership. However, until all assessment is complete, it is impossible
to accurately identify the risks, quantify potential impacts or establish a
final contingency plan. The Managing General Partner believes that its
assessment and contingency planning will be complete no later than mid-year
1999.
Worst Case Scenario
The Securities and Exchange Commission requires that public companies must
forecast the most reasonably likely worst case Year 2000 scenario, assuming
that the Managing General Partner's Year 2000 plan is not effective.
Analysis of the most reasonably likely worst case Year 2000 scenarios the
Partnership may face leads to contemplation of the following possibilities
which, though considered highly unlikely, must be included in any
consideration of worst cases: widespread failure of electrical, gas, and
similar supplies by utilities serving the Partnership; widespread
disruption of the services of communications common carriers; similar
disruption to means and modes of transportation for the Partnership and its
employees, contractors, suppliers, and customers; significant disruption to
the Partnership's ability to gain access to, and continue working in,
office buildings and other facilities; and the failure, of third-parties
systems, the effects of which would have a cumulative material adverse
impact on the Partnership's critical systems. The Partnership could
experience an inability by customers, traders, and others to pay, on a
timely basis or at all, obligations owed to the Partnership. Under these
circumstances, the adverse effect on the Partnership, and the diminution of
Partnership revenues, could be material, although not quantifiable at this
time.
<PAGE>
PART II. - OTHER INFORMATION
Item 1. Legal Proceedings
None
Item 2. Changes in Securities
None
Item 3. Defaults Upon Senior Securities
None
Item 4. Submission of Matter to a Vote of Security Holders
None
Item 5. Other Information
None
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits:
27 Financial Data Schedule
(b) Reports on Form 8-K:
No reports on Form 8-
K were filed during the quarter ended June 30, 1999.
<PAGE>
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
SOUTHWEST ROYALTIES INSTITUTIONAL
INCOME FUND VIII-B, L.P.
a Delaware limited partnership
By: Southwest Royalties, Inc.
Managing General Partner
By: /s/ Bill E. Coggin
Bill E. Coggin, Vice
President
and Chief Financial Officer
Date: August 15, 1999
<PAGE>
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
This schedule contains summary financial information extracted from the
Balance Sheet at June 30, 1999 (Unaudited) and the Statement of Operations
for the Six Months Ended June 30, 1999 (Unaudited) and is qualified in its
entirety by reference to such financial statements.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-END> JUN-30-1999
<CASH> 24,112
<SECURITIES> 0
<RECEIVABLES> 78,995
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 103,107
<PP&E> 4,133,496
<DEPRECIATION> 3,631,058
<TOTAL-ASSETS> 605,545
<CURRENT-LIABILITIES> 177
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 605,368
<TOTAL-LIABILITY-AND-EQUITY> 605,545
<SALES> 138,252
<TOTAL-REVENUES> 138,786
<CGS> 0
<TOTAL-COSTS> 0
<OTHER-EXPENSES> 63,512
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 75,274
<INCOME-TAX> 0
<INCOME-CONTINUING> 75,274
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 75,274
<EPS-BASIC> 6.45
<EPS-DILUTED> 6.45
</TABLE>
