Page 13 of 14
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 September 30, 1998
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 0-20298
SOUTHWEST ROYALTIES INSTITUTIONAL 1990-91 INCOME PROGRAM
Southwest Royalties Institutional Income Fund X-C, L.P.
(Exact name of registrant as specified
in its limited partnership agreement)
Delaware 75-2374449
(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 15.
<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 note thereto for
the year ended December 31, 1997 which are found in the Registrant's Form
10-K Report for 1997 filed with the Securities and Exchange Commission.
The December 31, 1997 balance sheet included herein has been taken from the
Registrant's 1997 Form 10-K Report. Operating results for the three and
nine month periods ended September 30, 1998 are not necessarily indicative
of the results that may be expected for the full year.
<PAGE>
Southwest Royalties Institutional Income Fund X-C, L.P.
Balance Sheets
September 30, December 31,
1998 1997
------------- ------------
(unaudited)
Assets
Current assets
Cash and cash equivalents $ 5,164 20,066
Receivable from Managing General Partner 20,505 105,891
--------- ---------
Total current assets 25,669 125,957
--------- ---------
Oil and gas properties - using the
full cost method of accounting 2,244,628 2,244,628
Less accumulated depreciation,
depletion and amortization 1,776,479 1,703,479
--------- ---------
Net oil and gas properties 468,149 541,149
--------- ---------
$ 493,818 667,106
========= =========
Liabilities and Partners' Equity
Current liability - Distribution payable $ 21 -
--------- ---------
Partners' equity
General partners (28,816) (18,785)
Limited partners 522,613 685,891
--------- ---------
Total partners' equity 493,797 667,106
--------- ---------
$ 493,818 667,106
========= =========
<PAGE>
Southwest Royalties Institutional Income Fund X-C, L.P.
Statements of Operations
(unaudited)
Three Months Ended Nine Months Ended
September 30, September 30,
1998 1997 1998 1997
---- ---- ---- ----
Revenues
Income (loss) from net
profits interests $ (11,442) 74,896 38,792 305,289
Interest 124 500 717 2,858
------ ------- ------- -------
(11,318) 75,396 39,509 308,147
------ ------- ------- -------
Expenses
General and administrative 11,605 9,097 40,818 34,307
Depreciation, depletion and
amortization 12,000 20,000 73,000 66,000
------ ------- ------- -------
23,605 29,097 113,818 100,307
------ ------- ------- -------
Net income (loss) $ (34,923) 46,299 (74,309) 207,840
====== ======= ======= =======
Net income (loss) allocated to:
Managing General Partner $ (2,063) 5,967 (118) 24,646
====== ======= ======= =======
General Partner $ (229) 663 (13) 2,738
====== ======= ======= =======
Limited Partners $ (32,631) 39,669 (74,178) 180,456
====== ======= ======= =======
Per limited partner unit $ (5.45) 6.63 (12.40) 30.16
====== ======= ======= =======
<PAGE>
Southwest Royalties Institutional Income Fund X-C, L.P.
Statements of Cash Flows
(unaudited)
Nine Months Ended
September 30,
1998 1997
---- ----
Cash flows from operating activities
Cash received from income from net
profits interests $ 106,557 348,720
Cash paid to suppliers (23,198) (34,307)
Interest received 717 2,858
------- -------
Net cash provided by operating activities 84,076 317,271
------- -------
Cash flows used in financing activities
Distributions to partners (98,978) (471,465)
------- -------
Net decrease in cash and cash equivalents (14,902) (154,194)
Beginning of period 20,066 170,421
------- -------
End of period $ 5,164 16,227
======= =======
(continued)
<PAGE>
Southwest Royalties Institutional Income Fund X-C, L.P.
Statements of Cash Flows, continued
(unaudited)
Nine Months Ended
September 30,
1998 1997
---- ----
Reconciliation of net income (loss) to net
cash provided by operating activities
Net income (loss) $ (74,309) 207,840
Adjustments to reconcile net income (loss) to
net cash provided by operating activities
Depreciation, depletion and amortization 73,000 66,000
Decrease in receivables 67,765 43,431
Increase in payables 17,620 -
------- -------
Net cash provided by operating activities $ 84,076 317,271
======= =======
<PAGE>
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
Southwest Royalties Institutional Income Fund X-C, L.P. was organized as a
Delaware limited partnership on September 20, 1991. The offering of such
limited partnership interests began October 1, 1991 as part of a shelf
offering registered under the name Southwest Royalties Institutional 1990-
91 Income Program. Minimum capital requirements for the Partnership were
met on January 28, 1992, with the offering of limited partnership interests
concluding April 30, 1992, with 340 limited partners purchasing 5,983 units
for $2,991,500.
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 1998 to enhance production. The Partnership could
possibly experience a normal decline in 1998.
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 September 30, 1998, the net capitalized costs did
not exceed the estimated present value of oil and gas reserves. A
continuation of the oil price environment experienced during the first
three quarters of 1998 will have an adverse affect on the Company's
revenues and operating cash flow. Also, further declines in oil prices
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 September 30, 1998 and 1997
The following table provides certain information regarding performance
factors for the quarters ended September 30, 1998 and 1997:
Three Months
Ended Percentage
September 30, Increase
1998 1997 (Decrease)
---- ---- ---------
Average price per barrel of oil $ 10.42 16.87 (38%)
Average price per mcf of gas $ 1.44 2.14 (33%)
Oil production in barrels 9,400 10,900 (14%)
Gas production in mcf 14,700 18,300 (20%)
Income (loss) from net profits interests $(11,422) 74,896 (115%)
Partnership distributions $ 9,000 115,000 (92%)
Limited partner distributions $ 8,100 103,500 (92%)
Per unit distribution to limited partners $ 1.35 17.30 (92%)
Number of limited partner units 5,983 5,983
Revenues
The Partnership's income from net profits interests decreased to $(11,442)
from $74,896 for the quarters ended September 30, 1998 and 1997,
respectively, a decrease of 115%. The principal factors affecting the
comparison of the quarters ended September 30, 1998 and 1997 are as
follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the quarter ended September 30, 1998 as compared to
the quarter ended September 30, 1997 by 38%, or $6.45 per barrel,
resulting in a decrease of approximately $70,300 in income from net
profits interests. Oil sales represented 82% of total oil and gas
sales during the quarter ended September 30, 1998 and 1997.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 33%, or $.70 per mcf, resulting in
a decrease of approximately $12,800 in income from net profits
interests.
The total decrease in income from net profits interests due to the
change in prices received from oil and gas production is approximately
$83,100. 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 1,500 barrels or 14% during the
quarter ended September 30, 1998 as compared to the quarter ended
September 30, 1997, resulting in a decrease of approximately $15,600 in
income from net profits interests.
Gas production decreased approximately 3,600 mcf or 20% during the same
period, resulting in a decrease of approximately $5,200 in income from
net profits interests.
The total decrease in income from net profits interests due to the
change in production is approximately $20,800. Decrease is due to
natural decline.
3. Lease operating costs and production taxes were 12% lower, or
approximately $17,600 less during the quarter ended September 30, 1998
as compared to the quarter ended September 30, 1997.
Costs and Expenses
Total costs and expenses decreased to $23,605 from $29,097 for the quarters
ended September 30, 1998 and 1997, respectively, a decrease of 19%. The
decrease is the result of lower depletion expense, partially offset by an
increase in general and administrative 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 increased
28% or approximately $2,500 during the quarter ended September 30, 1998
as compared to the quarter ended September 30, 1997. The increase in
general and administrative costs are due largely to higher accounting
fees. The 10-Q's are now required to be reviewed based on new
accounting pronouncements.
2. Depletion expense decreased to $12,000 for the quarter ended September
30, 1998 from $20,000 for the same period in 1997. This represents a
decrease of 40%. 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 decrease in the price of oil and thus the decline in
gross oil and gas revenues.
<PAGE>
B. General Comparison of the Nine Month Periods Ended September 30, 1998
and 1997
The following table provides certain information regarding performance
factors for the nine month periods ended September 30, 1998 and 1997:
Nine Months
Ended Percentage
September 30, Increase
1998 1997 (Decrease)
---- ---- ---------
Average price per barrel of oil $ 11.35 18.57 (39%)
Average price per mcf of gas $ 1.68 2.31 (27%)
Oil production in barrels 31,300 33,700 (7%)
Gas production in mcf 48,600 55,500 (12%)
Income from net profits interests $ 38,792 305,289 (87%)
Partnership distributions $ 99,000 471,500 (79%)
Limited partner distributions $ 89,100 424,350 (79%)
Per unit distribution to limited partners $ 14.89 70.93 (79%)
Number of limited partner units 5,983 5,983
Revenues
The Partnership's income from net profits interests decreased to $38,792
from $305,289 for the nine months ended September 30, 1998 and 1997,
respectively, a decrease of 87%. The principal factors affecting the
comparison of the nine months ended September 30, 1998 and 1997 are as
follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the nine months ended September 30, 1998 as compared
to the nine months ended September 30, 1997 by 39%, or $7.22 per
barrel, resulting in a decrease of approximately $243,300 in income
from net profits interests. Oil sales represented 81% of total oil and
gas sales during the nine months ended September 30, 1998 as compared
to 83% during the nine months ended September 30, 1997.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 27%, or $.63 per mcf, resulting in
a decrease of approximately $35,000 in income from net profits
interests.
The total decrease in income from net profits interests due to the
change in prices received from oil and gas production is approximately
$278,300. 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 2,400 barrels or 7% during the
nine months ended September 30, 1998 as compared to the nine months
ended September 30, 1997, resulting in a decrease of approximately
$27,200 in income from net profits interests.
Gas production decreased approximately 6,900 mcf or 12% during the same
period, resulting in a decrease of approximately $11,600 in income from
net profits interests.
The total decrease in income from net profits interests due to the
change in production is approximately $38,800.
3. Lease operating costs and production taxes were 11% lower, or
approximately $50,300 less during the nine months ended September 30,
1998 as compared to the nine months ended September 30, 1997.
Costs and Expenses
Total costs and expenses increased to $113,818 from $100,307 for the nine
months ended September 30, 1998 and 1997, respectively, an increase of 13%.
The increase is the result of higher 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 increased
19% or approximately $6,500 during the nine months ended September 30,
1998 as compared to the nine months ended September 30, 1997. The
increase in general and administrative costs are due largely to higher
accounting fees. The 10-Q's are now required to be reviewed based on
new accounting pronouncements.
2. Depletion expense increased to $73,000 for the nine months ended
September 30, 1998 from $66,000 for the same period in 1997. This
represents an increase of 11%. 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.
<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 $84,100 in
the nine months ended September 30, 1998 as compared to approximately
$317,300 in the nine months ended September 30, 1997. The primary source
of the 1998 cash flow from operating activities was profitable operations.
There were no cash flows provided by investing activities in the nine
months ended September 30, 1998 and 1997.
Cash flows used in financing activities were approximately $98,900 in the
nine months ended September 30, 1998 as compared to approximately $471,500
in the nine months ended September 30, 1997. The only use in financing
activities was the distributions to partners.
Total distributions during the nine months ended September 30, 1998 were
$99,000 of which $89,100 was distributed to the limited partners and $9,900
to the general partners. The per unit distribution to limited partners
during the nine months ended September 30, 1998 was $14.89. Total
distributions during the nine months ended September 30, 1997 were $471,500
of which $424,350 was distributed to the limited partners and $47,150 to
the general partners. The per unit distribution to limited partners during
the nine months ended September 30, 1997 was $70.93.
The sources for the 1998 distributions of $99,000 were oil and gas
operations of approximately $84,100, with the balance from available cash
on hand at the beginning o the period. The source for the 1997
distributions of $471,500 was oil and gas operations of approximately
$317,300, with the balance from available cash on hand at the beginning of
the period.
Since inception of the Partnership, cumulative monthly cash distributions
of $2,556,468 have been made to the partners. As of September 30, 1998,
$2,312,678 or $386.54 per limited partner unit has been distributed to the
limited partners, representing a 77% return of the capital contributed.
As of September 30, 1998, the Partnership had approximately $25,600 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>
Information Systems for the Year 2000
The Partnership relies on the Managing General Partner for their data
processing requirements. This includes use of a program designed and
implemented by Midland Southwest Software, the Managing General Partner's
software subsidiary. Midland Southwest Software currently has a year 2000
plan in effect. They have surveyed existing programs and hardware and
estimate a compliance date of early 1999. Determination of the total cost
in connection with the year 2000 compliance issue is difficult to determine
due to the fact that they are in the process of developing their new 1998
version of marketed oil and gas software, which has, from inception,
included year 2000 compliance. Third party software programs utilized by
the Managing General Partner are either in compliance or are not affected
by the year 2000, with the exception of the payroll service, which is
currently modifying its system to accurately handle the Year 2000 issue.
The Managing General Partner has not completed its evaluation of its
vendors or suppliers systems to determine the effect, if any, the non-
compliance of such systems would have on the operations of the Managing
General Partner. Plans are under way to perform an audit in late 1998 or
early 1999 to determine the effect of non-compliance of its vendors and
suppliers on the Managing General Partner and thus formulate a contingency
plan.
A potential source of risk includes, but is not limited to, the inability
of principal purchasers and suppliers to be year 2000 compliant, which
could have a material effect on the Managing General Partner's production,
cash flow and overall financial condition, notwithstanding the Managing
General Partner's actions to prepare its own information systems. The
Managing General Partner currently does not have a contingency plan in
place to cover any unforeseen problems encountered that relate to the year
2000, but intends to produce one before the end of the fiscal year.
<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) No reports on Form 8-K were filed during the quarter for
which this report is filed.
<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 X-C, 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: November 15, 1998
<PAGE>
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
This schedule contians summary financial information extracted from the
Balance Sheet at September 30, 1998 (Unaudited) and the Statement of
Operations for the Nine Months Ended September 30, 1998 (Unaudited) and is
qualified in its entirety by reference to such financial statements.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> SEP-30-1998
<CASH> 5,164
<SECURITIES> 0
<RECEIVABLES> 20,505
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 25,669
<PP&E> 2,244,628
<DEPRECIATION> 1,776,479
<TOTAL-ASSETS> 493,818
<CURRENT-LIABILITIES> 21
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 493,797
<TOTAL-LIABILITY-AND-EQUITY> 493,818
<SALES> 38,792
<TOTAL-REVENUES> 39,509
<CGS> 0
<TOTAL-COSTS> 0
<OTHER-EXPENSES> 113,818
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> (74,309)
<INCOME-TAX> 0
<INCOME-CONTINUING> (74,309)
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> (74,309)
<EPS-PRIMARY> (12.40)
<EPS-DILUTED> (12.40)
</TABLE>
