Page 14 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, 2001
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 14.
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, 2000, which are found in the Registrant's Form
10-K Report for 2000 filed with the Securities and Exchange Commission.
The December 31, 2000 balance sheet included herein has been taken from the
Registrant's 2000 Form 10-K Report. Operating results for the three and
nine month periods ended September 30, 2001 are not necessarily indicative
of the results that may be expected for the full year.
Southwest Royalties Institutional Income Fund X-C, L.P.
Balance Sheets
September 30, December 31,
2001 2000
------------- ------------
(unaudited)
Assets
- ------
Current assets:
Cash and cash equivalents $ 20,226 87,960
Receivable from Managing General Partner 50,891 111,036
--------- ---------
Total current assets 71,117 198,996
--------- ---------
Oil and gas properties - using the
full-cost method of accounting 2,221,662 2,221,662
Less accumulated depreciation,
depletion and amortization 2,045,479 1,960,479
--------- ---------
Net oil and gas properties 176,183 261,183
--------- ---------
$ 247,300 460,179
========= =========
Liabilities and Partners' Equity
- --------------------------------
Partners' equity:
General partners $ (24,937) (12,149)
Limited partners 272,237 472,328
--------- ---------
Total partners' equity 247,300 460,179
--------- ---------
$ 247,300 460,179
========= =========
Southwest Royalties Institutional Income Fund X-C, L.P.
Statements of Operations
(unaudited)
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
---- ---- ---- ----
Revenues
- --------
Income from net
profits interests $ 39,868 112,639 209,750 273,888
Interest 538 1,014 2,585 2,168
------- ------- ------- -------
40,406 113,653 212,335 276,056
------- ------- ------- -------
Expenses
- --------
General and administrative 10,225 10,265 30,214 30,858
Depreciation, depletion and
amortization 49,000 10,000 85,000 25,000
------- ------- ------- -------
59,225 20,265 115,214 55,858
------- ------- ------- -------
Net income (loss) $ (18,819) 93,388 97,121 220,198
======= ======= ======= =======
Net income (loss) allocated to:
Managing General Partner $ 2,716 9,305 16,391 22,068
======= ======= ======= =======
General Partner $ 302 1,034 1,821 2,452
======= ======= ======= =======
Limited Partners $ (21,837) 83,049 78,909 195,678
======= ======= ======= =======
Per limited partner unit $ (3.65) 13.88 13.19 32.71
======= ======= ======= =======
Southwest Royalties Institutional Income Fund X-C, L.P.
Statements of Cash Flows
(unaudited)
Nine Months Ended
September 30,
2001 2000
---- ----
Cash flows from operating activities
Cash received from income from net
profits interests $ 268,812 264,570
Cash paid to suppliers (29,131) (18,235)
Interest received 2,585 2,168
------- -------
Net cash provided by operating activities 242,266 248,503
------- -------
Cash flow used in investing activities
Additions to oil and gas properties - (5)
------- -------
Cash flows used in financing activities
Distributions to partners (310,000) (190,002)
------- -------
Net (decrease) increase in cash and cash equivalents (67,734)
58,496
Beginning of period 87,960 22,098
------- -------
End of period $ 20,226 80,594
======= =======
Reconciliation of net income to net
cash provided by operating activities
Net income $ 97,121 220,198
Adjustments to reconcile net income to
net cash provided by operating activities
Depreciation, depletion and amortization 85,000 25,000
Decrease (increase) receivables 59,060 (9,318)
Increase in payables 1,085 12,623
------- -------
Net cash provided by operating activities $ 242,266 248,503
======= =======
Southwest Royalties Institutional Income Fund X-C, L.P.
(a Delaware limited partnership)
Notes to Financial Statements
1. Organization
Southwest Royalties Institutional Income Fund X-C, L.P. was organized
under the laws of the state of Delaware on September 20, 1991, 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 several 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% -
Syndication costs 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.
2. Summary of Significant Accounting Policies
The interim financial information as of September 30, 2001, and for
the three and nine months ended September 30, 2001, 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, 2000.
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 the next twelve months. The Partnership could possibly
experience a normal decline of 8% 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 September 30, 2001, the net capitalized costs did
not exceed the estimated present value of oil and gas reserves.
Results of Operations
A. General Comparison of the Quarters Ended September 30, 2001 and 2000
The following table provides certain information regarding performance
factors for the quarters ended September 30, 2001 and 2000:
Three Months
Ended Percentage
September 30, Increase
2001 2000 (Decrease)
---- ---- ---------
Average price per barrel of oil $ 21.85 29.16 (25%)
Average price per mcf of gas $ 2.09 4.25 (51%)
Oil production in barrels 7,300 7,600 (4%)
Gas production in mcf 11,200 9,100 23%
Income from net profits interests $ 39,868 112,639 (65%)
Partnership distributions $ 90,000 80,000 13%
Limited partner distributions $ 81,000 72,000 13%
Per unit distribution to limited partners $ 13.54 12.03 13%
Number of limited partner units 5,983 5,983
Revenues
The Partnership's income from net profits interests decreased to $39,868
from $112,639 for the quarters ended September 30, 2001 and 2000,
respectively, a decrease of 65%. The principal factors affecting the
comparison of the quarters ended September 30, 2001 and 2000 are as
follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the quarter ended September 30, 2001 as compared to
the quarter ended September 30, 2000 by 25%, or $7.31 per barrel,
resulting in a decrease of approximately $53,400 in income from net
profits interests. Oil sales represented 87% of total oil and gas
sales during the quarter ended September 30, 2001 as compared to 85%
during the quarter ended September 30, 2000.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 51%, or $2.16 per mcf, resulting
in a decrease of approximately $24,200 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
$77,600. 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 300 barrels or 4% during the
quarter ended September 30, 2001 as compared to the quarter ended
September 30, 2000, resulting in a decrease of approximately $8,700 in
income from net profits interests.
Gas production increased approximately 2,100 mcf or 23% during the same
period, resulting in an increase of approximately $8,900 in income from
net profits interests.
The net total increase in income from net profits interests due to the
change in production is approximately $200. The increase in gas
production is in relation to an unsuccessful workover, which was
performed on a non-operated lease during 2000. The workover caused the
well to shut down and was determined to be unrecoverable. During the
nine months ended September 30, 2001, a new well on the same lease was
brought on line and has proven successful in replacing the lost
production of the old well.
3. Lease operating costs and production taxes were 3% lower, or
approximately $4,300 less during the quarter ended September 30, 2001
as compared to the quarter ended September 30, 2000.
Costs and Expenses
Total costs and expenses increased to $59,225 from $20,265 for the quarters
ended September 30, 2001 and 2000, respectively, an increase of 192%. The
increase is the result of higher depletion expense, partially offset by a
decrease 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 decreased
less than 1% or approximately $40 during the quarter ended September
30, 2001 as compared to the quarter ended September 30, 2000.
2. Depletion expense increased to $49,000 for the nine months ended
September 30, 2001 from $10,000 for the same period in 2000. This
represents an increase of 390%. 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 increase in depletion expense
between the comparative periods were the decrease in the price of oil
and gas used to determine the Partnership's reserves for October 1,
2001 as compared to 2000, and the decrease in oil and gas revenues
received by the Partnership during 2001 as compared to 2000.
B. General Comparison of the Nine Month Periods Ended September 30, 2001
and 2000
The following table provides certain information regarding performance
factors for the nine month periods ended September 30, 2001 and 2000:
Nine Months
Ended Percentage
September 30, Increase
2001 2000 (Decrease)
---- ---- ---------
Average price per barrel of oil $ 23.13 27.26 (15%)
Average price per mcf of gas $ 3.89 3.58 9%
Oil production in barrels 21,400 23,000 (7%)
Gas production in mcf 33,900 20,740 63%
Income from net profits interests $ 209,750 273,888 (23%)
Partnership distributions $ 310,000 190,000 63%
Limited partner distributions $ 279,000 171,000 63%
Per unit distribution to limited partners $ 46.63 28.58 63%
Number of limited partner units 5,983 5,983
Revenues
The Partnership's income from net profits interests decreased to $209,750
from $273,888 for the nine months ended September 30, 2001 and 2000,
respectively, a decrease of 23%. The principal factors affecting the
comparison of the nine months ended September 30, 2001 and 2000 are as
follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the nine months ended September 30, 2001 as compared
to the nine months ended September 30, 2000 by 15%, or $4.13 per
barrel, resulting in a decrease of approximately $88,400 in income from
net profits interests. Oil sales represented 79% of total oil and gas
sales during the nine months ended September 30, 2001 as compared to
89% during the nine months ended September 30, 2000.
The average price for an mcf of gas received by the Partnership
increased during the same period by 9%, or $.31 per mcf, resulting in
an increase of approximately $10,500 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
$77,900. 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 1,600 barrels or 7% during the
nine months ended September 30, 2001 as compared to the nine months
ended September 30, 2000, resulting in a decrease of approximately
$43,600 in income from net profits interests.
Gas production increased approximately 13,160 mcf or 63% during the
same period, resulting in an increase of approximately $47,100 in
income from net profits interests.
The net total increase in income from net profits interests due to the
change in production is approximately $3,500. The increase in gas
production is in relation to an unsuccessful workover, which was
performed on a non-operated lease during 2000. The workover caused the
well to shut down and was determined to be unrecoverable. During the
nine months ended September 30, 2001, a new well on the same lease was
brought on line and has proven successful in replacing the lost
production of the old well.
3. Lease operating costs and production taxes were 2% lower, or
approximately $10,300 less during the nine months ended September 30,
2001 as compared to the nine months ended September 30, 2000.
Costs and Expenses
Total costs and expenses increased to $115,214 from $55,858 for the nine
months ended September 30, 2001 and 2000, respectively, an increase of
106%. The increase is the result of higher depletion expense, partially
offset by a decrease 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 decreased 2%
or approximately $600 during the nine months ended September 30, 2001
as compared to the nine months ended September 30, 2000.
2. Depletion expense increased to $85,000 for the nine months ended
September 30, 2001 from $25,000 for the same period in 2000. This
represents an increase of 240%. 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 increase in depletion expense
between the comparative periods were the decrease in the price of oil
and gas used to determine the Partnership's reserves for October 1,
2001 as compared to 2000, and the decrease in oil and gas revenues
received by the Partnership during 2001 as compared to 2000.
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 $242,300 in
the nine months ended September 30, 2001 as compared to approximately
$248,500 in the nine months ended September 30, 2000. The primary source
of the 2001 cash flow from operating activities was profitable operations.
There were no cash flows used in investing activities for the nine months
ended September 30, 2001 as compared to approximately $(5) in the nine
months ended September 30, 2000.
Cash flows used in financing activities were approximately $310,000 in the
nine months ended September 30, 2001 as compared to approximately $190,000
in the nine months ended September 30, 2000. The only use in financing
activities was the distributions to partners.
Total distributions during the nine months ended September 30, 2001 were
$310,000 of which $279,000 was distributed to the limited partners and
$31,000 to the general partners. The per unit distribution to limited
partners during the nine months ended September 30, 2001 was $46.63. Total
distributions during the nine months ended September 30, 2000 were $190,000
of which $171,000 was distributed to the limited partners and $19,000 to
the general partners. The per unit distribution to limited partners during
the nine months ended September 30, 2000 was $28.58.
The source for the 2001 distributions of $310,000 was oil and gas
operations of approximately $242,300, with the balance from available cash
on hand at the beginning of the period. The sources for the 2000
distributions of $190,000 were oil and gas operations of approximately
$248,500, resulting in excess cash for contingencies or subsequent
distributions.
Since inception of the Partnership, cumulative monthly cash distributions
of $3,243,295 have been made to the partners. As of September 30, 2001,
$2,932,450 or $490.13 per limited partner unit has been distributed to the
limited partners, representing a 98% return of the capital contributed.
As of September 30, 2001, the Partnership had approximately $71,100 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.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
The Partnership is not a party to any derivative or
embedded derivative instruments.
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) No reports on Form 8-K were filed during the quarter for
which this report is filed.
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 14, 2001