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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, 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 0-18398
Southwest Royalties Institutional Income Fund IX-B, L.P.
(Exact name of registrant as specified
in its limited partnership agreement)
Delaware 75-2274633
(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 notes 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
six month periods ended June 30, 1998 are not necessarily indicative of the
results that may be expected for the full year.
Southwest Royalties Institutional Income Fund IX-B, L.P.
Balance Sheets
June 30, December 31,
1998 1997
--------- ------------
(unaudited)
Assets
Current assets:
Cash and cash equivalents $ 64,370 29,956
Receivable from Managing General Partner 35,462 83,386
--------- ---------
Total current assets 99,832 113,342
--------- ---------
Oil and gas properties - using the
full cost method of accounting 3,183,393 3,286,714
Less accumulated depreciation,
depletion and amortization 2,519,000 2,474,000
--------- ---------
Net oil and gas properties 664,393 812,714
--------- ---------
$ 764,225 926,056
========= =========
Liabilities and Partners' Equity
Current liability - Distributions payable $ 158 245
--------- ---------
Partners' equity:
General partners (59,367) (49,134)
Limited partners 823,434 974,945
--------- ---------
Total partners' equity 764,067 925,811
--------- ---------
$ 764,225 926,056
========= =========
Southwest Royalties Institutional Income Fund IX-B, L.P.
Statements of Operations
(unaudited)
Three Months Ended Six Months Ended
June 30, June 30,
1998 1997 1998 1997
Revenues
Income from net profits
interests $ 52,308 92,105 99,640 226,914
Interest 391 297 910 680
------ ------- ------- -------
52,699 92,402 100,550 227,594
------ ------- ------- -------
Expenses
General and administrative 21,300 17,888 47,389 42,347
Depreciation, depletion and
amortization 24,000 18,000 45,000 38,000
------ ------- ------- -------
45,300 35,888 92,389 80,347
------ ------- ------- -------
Net income $ 7,399 56,514 8,161 147,247
====== ======= ======= =======
Net income allocated to:
Managing General Partner $ 2,827 6,706 4,785 16,673
====== ======= ======= =======
General Partner $ 314 745 532 1,852
====== ======= ======= =======
Limited partners $ 4,258 49,063 2,844 128,722
====== ======= ======= =======
Per limited partner unit $ .44 5.02 .29 13.16
====== ======= ======= =======
Southwest Royalties Institutional Income Fund IX-B, L.P.
Statements of Cash Flows
(unaudited)
Six Months Ended
June 30,
1998 1997
Cash flows from operating activities:
Cash received from income from net profits
interests $ 143,694 289,209
Cash paid to suppliers (43,518) (42,004)
Interest received 910 680
-------- -------
Net cash provided by operating activities 101,086 247,885
-------- -------
Cash flows provided by investing activities:
Cash received from sale of oil and gas
properties 103,320 -
-------- -------
Cash flows used in financing activities:
Distributions to partners (169,992) (257,959)
-------- -------
Net increase (decrease) in cash and cash
equivalents 34,414 (10,074)
Beginning of period 29,956 13,489
-------- -------
End of period $ 64,370 3,415
======== =======
(continued)
Southwest Royalties Institutional Income Fund IX-B, L.P.
Statements of Cash Flows, continued
(unaudited)
Six Months Ended
June 30,
1998 1997
Reconciliation of net income to net cash
provided by operating activities:
Net income $ 8,161 147,247
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation, depletion and amortization 45,000 38,000
Decrease in receivables 44,054 62,295
Increase in payables 3,871 343
------- -------
Net cash provided by operating activities $ 101,086 247,885
======= =======
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations
General
Southwest Royalties Institutional Income Fund IX-B, L.P. was organized as a
Delaware limited partnership on March 9, 1989. The offering of such limited
partnership interests began on May 11, 1989, minimum capital requirements
were met on September 26, 1989, and the offering concluded on March 31,
1990, with total limited partner contributions of $4,891,000.
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, 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.
Based on current conditions, management does not anticipate performing
workovers during the next year. The Partnership may undergo an increase
1998. Thereafter, 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, 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 half 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.
Results of Operations
A. General Comparison of the Quarters Ended June 30, 1998 and 1997
The following table provides certain information regarding performance
factors for the quarters ended June 30, 1998 and 1997:
Three Months
Ended Percentage
June 30, Increase
1998 1997 (Decrease)
---- ---- ----------
Average price per barrel of oil $ 12.53 18.69 (33%)
Average price per mcf of gas $ 1.75 1.80 (3%)
Oil production in barrels 8,300 7,500 11%
Gas production in mcf 33,700 46,300 (27%)
Income from net profits interests $ 52,308 92,105 (43%)
Partnership distributions $ 72,904 75,000 (3%)
Limited partner distributions $ 67,054 67,500 (1%)
Per unit distribution to limited
partners $ 6.85 6.90 (1%)
Number of limited partner units 9,782 9,782
Revenues
The Partnership's income from net profits interests decreased to $52,308
from $92,105 for the quarters ended June 30, 1998 and 1997, respectively, a
decrease of 43%. The principal factors affecting the comparison of the
quarters ended June 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 June 30, 1998 as compared to the
quarter ended June 30, 1997 by 33%, or $6.16 per barrel, resulting in a
decrease of approximately $46,200 in income from net profits interests.
Oil sales represented 64% of total oil and gas sales during the quarter
ended June 30, 1998 as compared to 63% during the quarter ended June
30, 1997.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 3%, or $.05 per mcf, resulting in a
decrease of approximately $2,315 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
$48,515. 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 increased approximately 800 barrels or 11% during the
quarter ended June 30, 1998 as compared to the quarter ended June 30,
1997, resulting in an increase of approximately $10,024 in income from
net profits interests.
Gas production decreased approximately 12,600 mcf or 27% during the
same period, resulting in a decrease of approximately $22,050 in income
from net profits interests.
The net total decrease in income from net profits interests due to the
change in production is approximately $12,026. The decrease in gas
production is due primarily to a farm-out agreement on one well which
decreased the partnerships ownership percentage and one well which
experienced downtime in the second quarter of 1997 and then a sharp
decline in production.
3. Lease operating costs and production taxes were 16% lower, or
approximately $20,472 less during the quarter ended June 30, 1998 as
compared to the quarter ended June 30, 1997. The decrease is primarily
attributable to workovers performed on two wells during the quarter
ended June 30, 1997.
Costs and Expenses
Total costs and expenses increased to $45,300 from $35,888 for the quarters
ended June 30, 1998 and 1997, respectively, an increase of 26%. The
increase is a result of higher depletion expense and 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
19% or approximately $3,412 during the quarter ended June 30, 1998 as
compared to the quarter ended June 30, 1997. Increase in general and
administrative costs are the result of higher accounting fees due to
the necessity of contracting out preparation of tax depletion and K-1
schedules.
2. Depletion expense increased to $24,000 for the quarter ended June 30,
1998 from $18,000 for the same period in 1997. This represents an
increase of 33%. 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 used to determine the
Partnership's reserves for January 1, 1998 as compared to 1997 and the
decline in oil and gas revenue.
B. General Comparison of the Six Month Periods Ended June 30, 1998 and
1997
The following table provides certain information regarding performance
factors for the six month periods ended June 30, 1998 and 1997:
Six Months
Ended Percentage
June 30, Increase
1998 1997 (Decrease)
---- ---- ----------
Average price per barrel of oil $ 13.26 18.83 (30%)
Average price per mcf of gas $ 1.60 1.91 (16%)
Oil production in barrels 15,000 15,400 (3%)
Gas production in mcf 74,000 100,000 (26%)
Income from net profits interests $ 99,640 226,914 (56%)
Partnership distributions $ 169,904 258,000 (34%)
Limited partner distributions $ 154,354 232,200 (34%)
Per unit distribution to limited
partners $ 15.78 23.74 (34%)
Number of limited partner units 9,782 9,782
Revenues
The Partnership's income from net profits interests decreased to $99,640
from $226,914 for the six months ended June 30, 1998 and 1997,
respectively, a decrease of 56%. The principal factors affecting the
comparison of the six months ended June 30, 1998 and 1997 are as follows:
1. The average price for a barrel of oil received by the Partnership
decreased during the six months ended June 30, 1998 as compared to the
six months ended June 30, 1997 by 30%, or $5.57 per barrel, resulting
in a decrease of approximately $85,778 in income from net profits
interests. Oil sales represented 63% of total oil and gas sales during
the six months ended June 30, 1998 as compared to 60% during the six
months ended June 30, 1997.
The average price for an mcf of gas received by the Partnership
decreased during the same period by 16%, or $.31 per mcf, resulting in
a decrease of approximately $31,000 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
$116,778. 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 400 barrels or 3% during the six
months ended June 30, 1998 as compared to the six months ended June 30,
1997, resulting in a decrease of approximately $5,304 in income from
net profits interests.
Gas production decreased approximately 26,000 mcf or 26% during the
same period, resulting in a decrease of approximately $41,600 in income
from net profits interests.
The total decrease in income from net profits interests due to the
change in production is approximately $46,904. The decrease in gas
production is due primarily to a farm-out agreement on one well which
decreased the partnerships ownership percentage and one well which
experienced downtime in the second quarter of 1997 and then a sharp
decline in production.
3. Lease operating costs and production taxes were 15% lower, or
approximately $36,900 less during the six months ended June 30, 1998 as
compared to the six months ended June 30, 1997.
Costs and Expenses
Total costs and expenses increased to $92,389 from $80,347 for the six
months ended June 30, 1998 and 1997, respectively, an increase of 15%. 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
12% or approximately $5,042 during the six months ended June 30, 1998
as compared to the six months ended June 30, 1997. Increase in general
and administrative costs are the result of higher accounting fees due
to the necessity of contracting out preparation of tax depletion and K-
1 schedules.
2. Depletion expense increased to $45,000 for the six months ended June
30, 1998 from $38,000 for the same period in 1997. This represents an
increase of 18%. Depletion is calculated using the units of revenue
method of amortization based on a percentage of current period gross
revenues to total future gross oil and gas revenues, as estimated by
the Partnership's independent petroleum consultants. A contributing
factor to the increase in depletion expense between the comparative
periods was the decrease in the price of oil used to determine the
Partnership's reserves for January 1, 1998 as compared to 1997.
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 $101,100 in
the six months ended June 30, 1998 as compared to approximately $247,900 in
the six months ended June 30, 1997. The primary source of the 1998 cash
flow from operating activities was profitable operations.
Cash flow provided by investing activities were approximately $103,300 in
the six months ended June 30, 1998. There were no cash flows provided by
investing activities in the six months ended June 30, 1997. The primary
source of the 1998 cash flow from investing activities was the sale of oil
and gas properties.
Cash flows used in financing activities were approximately $170,000 in the
six months ended June 30, 1998 as compared to approximately $258,000 in the
six months ended June 30, 1997. The only use in financing activities was
the distributions to partners.
Total distributions during the six months ended June 30, 1998 were $169,904
of which $154,354 was distributed to the limited partners and $15,550 to
the general partners. The per unit distribution to limited partners during
the six months ended June 30, 1998 was $15.78. Total distributions during
the six months ended June 30, 1997 were $258,000 of which $232,200 was
distributed to the limited partners and $25,800 to the general partners.
The per unit distribution to limited partners during the six months ended
June 30, 1997 was $23.74.
The sources for the 1998 distributions of $169,904 were oil and gas
operations of approximately $101,100 and the sale of oil and gas properties
of approximately $103,300, resulting in excess cash for contingencies or
subsequent distributions. The source for the 1997 distributions of
$258,000 was oil and gas operations of approximately $247,900, with the
balance from available cash on hand at the beginning of the period.
Since inception of the Partnership, cumulative monthly cash distributions
of $5,461,610 have been made to the partners. As of June 30, 1998,
$4,954,116 or $506.45 per limited partner unit has been distributed to the
limited partners, representing a 101% return of the capital contributed.
As of June 30, 1998, the Partnership had approximately $99,674 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.
Information Systems for the Year 2000
The Managing General Partner provides all data processing needs of the
Partnership. The Managing General Partner has reviewed and evaluated its
information systems to determine if its systems accurately process data
referencing the year 2000. Primarily all necessary programming
modifications to correct year 2000 referencing in the Managing General
Partners internal accounting and operating systems have been made to-date.
However the Managing General Partner has not completed its evaluation of
its vendors and suppliers systems to determine the effect, if any, the non-
compliance of such systems would have on the operation of the Managing
General Partnership or the operations of the Partnership.
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, 1998.
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 IX-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, 1998