Page 21 of 21
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, 2002
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 0-15408
Southwest Royalties, Inc. Income Fund V
(Exact name of registrant as specified
in its limited partnership agreement)
Tennessee 75-2104619
(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 21.
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, 2001, which are found in the Registrant's Form
10-K Report for 2001 filed with the Securities and Exchange Commission.
The December 31, 2001 balance sheet included herein has been taken from the
Registrant's 2001 Form 10-K Report. Operating results for the three and
nine month periods ended September 30, 2002 are not necessarily indicative
of the results that may be expected for the full year.
Southwest Royalties, Inc. Income Fund V
Balance Sheets
September December
30, 31,
2002 2001
----------- ---------
(unaudited)
Assets
- ------
Current assets:
Cash and cash equivalents $ 7,361 64,290
Receivable from Managing General 33,784 -
Partner
Distribution receivable 425 304
--------- ---------
Total current assets 41,570 64,594
--------- ---------
Oil and gas properties - using the
full-
cost method of accounting 6,159,438 6,159,438
Less accumulated depreciation,
depletion and amortization 5,889,800 5,864,800
--------- ---------
Net oil and gas properties 269,638 294,638
--------- ---------
$ 311,208 359,232
========= =========
Liabilities and Partners' Equity
- --------------------------------
Current liability - distribution $ - 5,775
payable
--------- ---------
Partners' equity:
General partners (645,072) (640,847)
Limited partners 956,280 994,304
--------- ---------
Total partners' equity 311,208 353,457
--------- ---------
$ 311,208 359,232
========= =========
Southwest Royalties, Inc. Income Fund V
Statements of Operations
(unaudited)
Three Months Ended Nine Months Ended
September 30, September 30,
2002 2001 2002 2001
---- ---- ---- ----
Revenues
- --------
Income from net profits $ 25,714 (45,452) 67,832 243,822
interests
Interest 8 417 29 2,068
Miscellaneous settlement - - 3,301 -
------- ------- ------- -------
25,722 (45,035) 71,162 245,890
------- ------- ------- -------
Expenses
- --------
General and administrative 29,761 29,176 88,411 86,485
Depreciation, depletion and
amortization 7,000 38,000 25,000 72,000
------- ------- ------- -------
36,761 67,176 158,485
113,411
------- ------- ------- -------
Net income (loss) $ (11,039) (112,211 87,405
) (42,249)
======= ======= ======= =======
Net income (loss) allocated
to:
Managing General Partner $ (1,104) (10,098) (4,225) 7,866
======= ======= ======= =======
General Partner $ - (1,123) - 874
======= ======= ======= =======
Limited Partners $ (9,935) (100,990 (38,024) 78,665
)
======= ======= ======= =======
Per limited partner unit $ (1.32) (13.47) (5.07) 10.49
======= ======= ======= =======
Southwest Royalties, Inc. Income Fund V
Statements of Cash Flows
(unaudited)
Nine Months Ended
September 30,
2002 2001
---- ----
Cash flows from operating activities
Cash received from income from net
profits interests $ 48,274 330,282
Cash paid to suppliers (108,41 (86,030)
2)
Interest received 29 2,068
Miscellaneous settlement 3,301 -
------- -------
Net cash (used in) provided by operating (56,808 246,320
activities )
------- -------
Cash flows used in financing activities
Distributions to partners (121) (225,085
)
------- -------
Net (decrease) increase in cash and cash (56,929 21,235
equivalents )
Beginning of period 64,290 43,322
------- -------
End of period $ 7,361 64,557
======= =======
Reconciliation of net income (loss) to net cash
(used in) provided by operating activities
Net income (loss) $ (42,249 87,405
)
Adjustments to reconcile net income (loss) to
net
cash (used in) provided by operating activities
Depreciation, depletion and amortization 25,000 72,000
(Increase) decrease receivables (19,558 86,460
)
(Decrease) increase in payables (20,001 455
)
------- -------
Net cash (used in) provided by operating $ (56,808 246,320
activities )
======= =======
Southwest Royalties, Inc. Income Fund V
(a Tennessee limited partnership)
Notes to Financial Statements
1. Organization
Southwest Royalties, Inc. Income Fund V was organized under the laws
of the state of Tennessee on May 1, 1986, 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. 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 90% 10%
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, 2002, and for
the three and nine months ended September 30, 2002, 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, 2001.
3. Subsequent Event
On October 17, 2002, Southwest Royalties, Inc. the Managing General
Partner filed an S-4 "Registration of Securities, Business
Combinations" with the Securities and Exchange Commission. The S-4
relates to a proposed plan of merger of twenty-one limited
partnerships.
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
Southwest Royalties, Inc. Income Fund V was organized as a Tennessee
limited partnership on May 1, 1986, after receipt from investors of
$1,000,000 in limited partner capital contributions. The offering of
limited partnership interests began on January 22, 1986 and concluded on
July 22, 1986, with total limited partner contributions of $7,500,000.
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 are not 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, increases
and decreases in lease operating expenses, enhanced recovery projects,
offset drilling activities pursuant to farm-out 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.
Development drilling pursuant to farmout arrangements and workovers may be
performed to increase production in the years 2002 and 2003. The
partnership may have a slight increase in production volumes for the years
2002 and 2003, but thereafter, the partnership will most likely experience
the historical production decline of 11% 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, 2002, the net capitalized costs did
not exceed the estimated present value of 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.
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.
The Partnership recognizes income from its net profits interest in oil and
gas property on an accrual basis, while the quarterly cash distributions of
the net profits interest are based on a calculation of actual cash received
from oil and gas sales, net of expenses incurred during that quarterly
period. The net profits interest is a calculated revenue interest that
burdens the underlying working interest in the property, and the net
profits interest owner is not responsible for the actual development or
production expenses incurred. Accordingly, if the net profits interest
calculation results in expenses incurred exceeding the oil and gas income
received during a quarter, no cash distribution is due to the Partnership's
net profits interest until the deficit is recovered from future net
profits. The Partnership accrues a quarterly loss on its net profits
interest provided there is a cumulative net amount due for accrued revenue
as of the balance sheet date.
Critical Accounting Policies
Full cost ceiling calculations The Partnership follows the full cost method
of accounting for its oil and gas properties. The full cost method
subjects companies to quarterly calculations of a "ceiling", or limitation
on the amount of properties that can be capitalized on the balance sheet.
If the Partnership's capitalized costs are in excess of the calculated
ceiling, the excess must be written off as an expense.
The Partnership's discounted present value of its proved oil and natural
gas reserves is a major component of the ceiling calculation, and
represents the component that requires the most subjective judgments.
Estimates of reserves are forecasts based on engineering data, projected
future rates of production and the timing of future expenditures. The
process of estimating oil and natural gas reserves requires substantial
judgment, resulting in imprecise determinations, particularly for new
discoveries. Different reserve engineers may make different estimates of
reserve quantities based on the same data. The Partnership's reserve
estimates are prepared by outside consultants.
The passage of time provides more qualitative information regarding
estimates of reserves, and revisions are made to prior estimates to reflect
updated information. However, there can be no assurance that more
significant revisions will not be necessary in the future. If future
significant revisions are necessary that reduce previously estimated
reserve quantities, it could result in a full cost property writedown. In
addition to the impact of these estimates of proved reserves on calculation
of the ceiling, estimates of proved reserves are also a significant
component of the calculation of DD&A.
While the quantities of proved reserves require substantial judgment, the
associated prices of oil and natural gas reserves that are included in the
discounted present value of the reserves do not require judgment. The
ceiling calculation dictates that prices and costs in effect as of the last
day of the period are generally held constant indefinitely. Because the
ceiling calculation dictates that prices in effect as of the last day of
the applicable quarter are held constant indefinitely, the resulting value
is not indicative of the true fair value of the reserves. Oil and natural
gas prices have historically been cyclical and, on any particular day at
the end of a quarter, can be either substantially higher or lower than the
Partnership's long-term price forecast that is a barometer for true fair
value.
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.
Results of Operations
A. General Comparison of the Quarters Ended September 30, 2002 and 2001
The following table provides certain information regarding performance
factors for the quarters ended September 30, 2002 and 2001:
Three Months
Ended Percentage
September 30, Increase
2002 2001 (Decrease)
---- ---- ----------
Average price per barrel of oil $ 27.32 25.26 8%
Average price per mcf of gas $ 3.11 2.80 11%
Oil production in barrels 3,200 3,450 (7%)
Gas production in mcf 18,100 24,700 (27%)
Income from net profits interests $ 25,714 (45,452) 157%
Partnership distributions $ - - -
Limited partner distributions $ - - -
Per unit distribution to limited partners $ - - -
Number of limited partner units 7,499 7,499
Revenues
The Partnership's income from net profits interests increased to $25,714
from $(45,452) for the quarters ended September 30, 2002 and 2001,
respectively, an increase of 157%. The principal factors affecting the
comparison of the quarters ended September 30, 2002 and 2001 are as
follows:
1. The average price for a barrel of oil received by the Partnership
increased during the quarter ended September 30, 2002 as compared to
the quarter ended September 30, 2001 by 8%, or $2.06 per barrel,
resulting in an increase of approximately $6,600 in income from net
profits interests. Oil sales represented 61% of total oil and gas
sales during the quarter ended September 30, 2002 as compared to 56%
during the quarter ended September 30, 2001.
The average price for an mcf of gas received by the Partnership
increased during the same period by 11%, or $.31 per mcf, resulting in
an increase of approximately $5,600 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
$12,200. 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 250 barrels or 7% during the
quarter ended September 30, 2002 as compared to the quarter ended
September 30, 2001, resulting in a decrease of approximately $6,300 in
income from net profits interests.
Gas production decreased approximately 6,600 mcf or 27% during the same
period, resulting in a decrease of approximately $18,500 in income from
net profits interests.
The total decrease in income from net profits interests due to the
change in production is approximately $24,800. The decrease in gas
production is due to several small wells experiencing steep declines.
3. Lease operating costs and production taxes was 30% lower, or
approximately $51,700 less during the quarter ended September 30, 2002
as compared to the quarter ended September 30, 2001. The decrease in
lease operating expense is due to repairs and maintenance on three
leases performed during 2001.
Costs and Expenses
Total costs and expenses decreased to $36,761 from $67,176 for the quarters
ended September 30, 2002 and 2001, respectively, a decrease of 45%. 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 2%
or approximately $600 during the quarter ended September 30, 2002 as
compared to the quarter ended September 30, 2001.
2. Depletion expense decreased to $7,000 for the quarter ended September
30, 2002 from $38,000 for the same period in 2001. This represents a
decrease of 82%. 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 decrease 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 October 1, 2002 as compared to 2002, and
the increase in oil and gas revenues received by the Partnership during
2002 as compared to 2001.
B. General Comparison of the Nine Month Periods Ended September 30, 2002
and 2001
The following table provides certain information regarding performance
factors for the nine month periods ended September 30, 2002 and 2001:
Nine Months
Ended Percentage
September 30, Increase
2002 2001 (Decrease)
---- ---- ---------
Average price per barrel of oil $ 24.18 26.91 (10%)
Average price per mcf of gas $ 2.87 4.64 (38%)
Oil production in barrels 9,350 11,700 (20%)
Gas production in mcf 58,400 73,500 (21%)
Income from net profits interests $ 67,832 243,822 (72%)
Partnership distributions $ - 225,000 (100%)
Limited partner distributions $ - 202,500 (100%)
Per unit distribution to limited partners $ - 27.00 (100%)
Number of limited partner units 7,499 7,499
Revenues
The Partnership's income from net profits interests decreased to $67,832
from $243,822 for the nine months ended September 30, 2002 and 2001,
respectively, a decrease of 72%. The principal factors affecting the
comparison of the nine months ended September 30, 2002 and 2001 are as
follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the nine months ended September 30, 2002 as compared
to the nine months ended September 30, 2001 by 10%, or $2.73 per
barrel, resulting in a decrease of approximately $25,500 in income from
net profits interests. Oil sales represented 57% of total oil and gas
sales during the nine months ended September 30, 2002 as compared to
48% during the nine months ended September 30, 2001.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 38%, or $1.77 per mcf, resulting in
a decrease of approximately $103,400 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
$128,900. 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 2,350 barrels or 20% during the
nine months ended September 30, 2002 as compared to the nine months
ended September 30, 2001, resulting in a decrease of approximately
$63,200 in income from net profits interests.
Gas production decreased approximately 15,100 mcf or 21% during the
same period, resulting in a decrease of approximately $70,100 in income
from net profits interests.
The total decrease in income from net profits interests due to the
change in production is approximately $133,300. The decrease in oil
production is due to one lease experiencing downtime during the nine
months ended September 30, 2002. The decrease in gas production is due
several small wells experiencing steep declines.
3. Lease operating costs and production taxes were 21% lower, or
approximately $86,600 less during the nine months ended September 30,
2002 as compared to the nine months ended September 30, 2001. Lease
operating expense is down due to repairs and maintenance on three
leases performed during 2001.
Costs and Expenses
Total costs and expenses decreased to $113,411 from $158,485 for the nine
months ended September 30, 2002 and 2001, respectively, a decrease of 28%.
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 2%
or approximately $1,900 during the nine months ended September 30, 2002
as compared to the nine months ended September 30, 2001.
2. Depletion expense decreased to $25,000 for the nine months ended
September 30, 2002 from $72,000 for the same period in 2001. This
represents a decrease of 65%. 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 decrease 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 October 1, 2002 as compared
to 2001, and the decrease in oil and gas revenues received by the
Partnership during 2002 as compared to 2001.
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 (used in) provided by operating activities were approximately
$(56,800) in the nine months ended September 30, 2002 as compared to
approximately $246,300 in the nine months ended September 30, 2001. The
primary use of the 2002 cash flow from operating activities was operations.
Cash flows used in financing activities were approximately $100 in the nine
months ended September 30, 2002 as compared to approximately $225,100 in
the nine months ended September 30, 2001. The only use in financing
activities was the distributions to partners.
There were no distributions during the nine months ended September 30,
2002. Total distributions during the nine months ended September 30, 2001
were $225,000 of which $202,500 was distributed to the limited partners and
$22,500 to the general partners. The per unit distribution to limited
partners during the nine months ended September 30, 2001 was $27.00.
The sources for the 2001 distributions of $225,000 were oil and gas
operations of approximately $246,300, resulting in excess cash for
contingencies or subsequent distributions.
Since inception of the Partnership, cumulative monthly cash distributions
of $7,863,543 have been made to the partners. As of September 30, 2002,
$7,060,820 or $941.57 per limited partner unit has been distributed to the
limited partners, representing an 94% return of the capital contributed.
As of September 30, 2002, the Partnership had approximately $41,600 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.
On October 17, 2002, Southwest Royalties, Inc. the Managing General Partner
filed an S-4 "Registration of Securities, Business Combinations" with the
Securities and Exchange Commission. The S-4 relates to a proposed plan of
merger of twenty-one limited partnerships.
Recent Accounting Pronouncements
The FASB has issued Statement No. 143 "Accounting for Asset Retirement
Obligations" which establishes requirements for the accounting of removal-
type costs associated with asset retirements. The standard is effective
for fiscal years beginning after June 15, 2002, with earlier application
encouraged. The Managing General Partner is currently assessing the impact
on the partnerships financial statements.
On October 3, 2001, the FASB issued Statement No. 144 "Accounting for the
Impairment or Disposal of Long-Lived Assets." This pronouncement
supercedes FAS 121 "Accounting for the Impairment of Long-Lived Assets and
for Long-Lived Assets to Be Disposed" and eliminates the requirement of
Statement 121 to allocate goodwill to long-lived assets to be tested for
impairment. The provisions of this statement are effective for financial
statements issued for fiscal years beginning after December 15, 2001, and
interim periods within those fiscal years. The Managing General Partner
believes that the impact from SFAS No. 144 on the Partnerships financial
position and results of operation should not be significantly different
from that of SFAS No. 121.
In April 2002, FASB issued SFAS No. 145, "Rescission of SFAS No. 4, 44, and
64, Amendment of SFAS No. 13, and Technical Corrections." This Statement
rescinds SFAS No. 4, "Reporting Gains and Losses from Extinguishment of
Debt", and an amendment of that Statement, SFAS No. 64, "Extinguishments of
Debt Made to Satisfy Sinking-Fund Requirements". This Statement also
rescinds or amends other existing authoritative pronouncements to make
various technical corrections, clarify meanings, or describe their
applicability under changed conditions. This standard is effective for
fiscal years beginning after May 15, 2002. The Managing General Partner
believes that the adoption of this statement will not have a significant
impact on the Partnerships financial statements.
In July 2002, FASB issued SFAS No. 146 "Accounting for Costs Associated
with Exit or Disposal Activities" which establishes requirements for
financial accounting and reporting for costs associated with exit or
disposal activities. This standard is effective for exit or disposal
activities initiated after December 31, 2002. The Managing General Partner
is currently assessing the impact of this statement on the Partnerships'
future financial statements.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
The Partnership is not a party to any derivative or
embedded derivative instruments.
Item 4. Controls and Procedures
(a) Evaluation of Disclosure Controls and Procedures.
The chief executive officer
and chief financial officer of the Partnership's managing
general partner have
evaluated the effectiveness of the design and operation of
the Partnership's disclosure
controls and procedures (as defined in Exchange Act Rule 13a-14(c))
as of a date within
90 days of the filing date of this quarterly report. Based
on that evaluation, the
chief executive officer and chief financial officer have
concluded that the
Partnership's disclosure controls and procedures are
effective to ensure that material
information relating to the Partnership and the Partnership's
consolidated subsidiaries
is made known to such officers by others within these entities,
particularly during the
period this quarterly report was prepared, in order to allow
timely decisions regarding
required disclosure.
(b) Changes in Internal Controls. There have not been any
significant changes in
the Partnership's internal controls or in other factors that
could significantly affect
these controls subsequent to the date of their evaluation.
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, Inc. Income Fund V
a Tennessee limited partnership
By: Southwest Royalties, Inc.
Managing General Partner
By: /s/ Bill E. Coggin
------------------------------
Bill E. Coggin, Executive Vice
President
and Chief Financial Officer
Date: November 14, 2002
CERTIFICATIONS
I, H.H. Wommack, III, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Southwest
Royalties, Inc. Income Fund V;
2. Based on my knowledge, this quarterly report does not contain any
untrue statement of a material fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances under
which such statements were made, not misleading with respect to the period
covered by this quarterly report;
3. Based on my knowledge, the financial s
tatements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and cash
flows of the registrant as of, and for, the periods presented in this
quarterly report;
4. The registrant's other certifying officers and I
are responsible for
establishing and maintaining disclosure controls and
procedures (as defined
in Exchange Act Rules 13a-14 and 15d-14) for the
registrant and we have:
a) designed such disclosure controls and
procedures to ensure that
material information relating to the registrant,
including its consolidated
subsidiaries, is made known to us by others
within those entities,
particularly during the period in which this
quarterly report is being
prepared;
b) evaluated the effectiveness of the registrant's
disclosure controls
and procedures as of a date within 90 days prior
to the filing date of this
quarterly report (the "Evaluation Date"); and
c) presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures
based on our
evaluation as of the Evaluation Date;
5. The registrant's other certifying officers a
nd I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the audit
committee of registrant's board of directors (or persons performing the
equivalent functions):
a) all significant deficiencies in the design
or operation of internal
controls which could adversely affect the
registrant's ability to record,
process, summarize and report financial data
and have identified for the
registrant's auditors any material weaknesses
in internal controls; and
b) any fraud, whether or not material, that
involves management or other
employees who have a significant role in the
registrant's internal
controls; and
6. The registrant's other certifying officers and
I have indicated in
this quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant deficiencies
and material weaknesses.
Date: November 14, 2002
/s/ H.H. Wommack, III
H. H. Wommack, III
Chairman, President and Chief Executive Officer
of Southwest Royalties, Inc., the
Managing General Partner of
Southwest Royalties, Inc. Income Fund V
CERTIFICATIONS
I, Bill E. Coggin, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Southwest
Royalties, Inc. Income Fund V;
2. Based on my knowledge, this quarterly report does not contain any
untrue statement of a material fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances under
which such statements were made, not misleading with respect to the period
covered by this quarterly report;
3. Based on my knowledge, the financial statements,
and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and cash
flows of the registrant as of, and for, the periods presented in this
quarterly report;
4. The registrant's other certifying officers and
I are responsible for
establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:
a) designed such disclosure controls and
procedures to ensure that
material information relating to the registrant,
including its consolidated
subsidiaries, is made known to us by others
within those entities,
particularly during the period in which this
quarterly report is being
prepared;
b) evaluated the effectiveness of the registrant's
disclosure controls
and procedures as of a date within 90 days
prior to the filing date of this
quarterly report (the "Evaluation Date"); and
c) presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls
and procedures based on our
evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and
I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the audit
committee of registrant's board of directors (or persons performing the
equivalent functions):
a) all significant deficiencies in the design
or operation of internal
controls which could adversely affect the
registrant's ability to record,
process, summarize and report financial data
and have identified for the
registrant's auditors any material weaknesses
in internal controls; and
b) any fraud, whether or not material, that involves
management or other
employees who have a significant role in
the registrant's internal
controls; and
6. The registrant's other certifying officers and
I have indicated in
this quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant deficiencies
and material weaknesses.
Date: November 14, 2002
/s/ Bill E. Coggin
Bill E. Coggin
Executive Vice President
and Chief Financial Officer of
Southwest Royalties, Inc., the
Managing General Partner of
Southwest Royalties, Inc. Income Fund V