<PAGE>
Securities and Exchange Commission
Washington, D.C. 20549
FORM 10-K
[ X ] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1999
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
------------ ------------
Commission File number 0-18358
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
(Exact name of registrant as specified in
its Certificate of Limited Partnership)
TEXAS 76-0279533
(State of Organization) (I.R.S. Employer Identification No.)
16825 Northchase Dr., Suite 400
Houston, Texas 77060
(281) 874-2700
(Address and telephone number of principal executive offices)
Securities registered pursuant to Section 12(b) of the Act:
None
Securities registered pursuant to Section 12(g) of the Act:
83,295 Limited Partnership Units
Indicate by check mark whether the 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 periods that the registrant was
required), and (2) has been subject to such filing requirements for the past 90
days.
Yes X No
----- -----
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [ X ]
Registrant does not have an aggregate market value for its Limited Partnership
Interests.
Documents Incorporated by Reference
Document Incorporated as to
Registration Statement No. 33-11773 Items 1 and 13
on Form S-1
<PAGE>
TABLE OF CONTENTS
Form 10-K Annual Report
For the Period Ended December 31, 1999
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
<TABLE>
<CAPTION>
ITEM NO. PART I PAGE
- -------- ------ ----
<S> <C> <C>
1 Business I-1
2 Properties I-5
3 Legal Proceedings I-7
4 Submission of Matters to a Vote of
Security Holders I-7
PART II
-------
5 Market Price of and Distributions on the
Registrant's Units and Related Limited
Partner Matters II-1
6 Selected Financial Data II-2
7 Management's Discussion and Analysis of
Financial Condition and Results of Operations II-2
8 Financial Statements and Supplementary Data II-4
9 Disagreements on Accounting and Financial
Disclosure II-4
PART III
--------
10 Directors and Executive Officers of the
Registrant III-1
11 Executive Compensation III-2
12 Security Ownership of Certain Beneficial
Owners and Management III-2
13 Certain Relationships and Related Transactions III-2
PART IV
-------
14 Exhibits, Financial Statement Schedules
and Reports on Form 8-K IV-1
OTHER
-----
Signatures
</TABLE>
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
PART I
Item 1. Business
General Description of Partnership
Swift Energy Income Partners 1989-B, Ltd., a Texas limited partnership
(the "Partnership" or the "Registrant"), is a partnership formed under a public
serial limited partnership offering denominated Swift Energy Income Partners III
(Registration Statement No. 33-11773 on Form S-1, originally declared effective
March 19, 1987, and amended effective March 28, 1988, May 4, 1989 and May 1,
1990 [the "Registration Statement"]). The Partnership was formed effective June
30, 1989 under a Limited Partnership Agreement dated May 31, 1989. The initial
661 limited partners made capital contributions of $8,329,500.
The Partnership is principally engaged in the business of acquiring,
developing and, when appropriate, disposing of working interests in proven oil
and gas properties within the continental United States. The Partnership does
not engage in exploratory drilling. Each working interest held by the
Partnership entitles the Partnership to receive, in kind or in value, a share of
the production of oil and gas from the producing property, and obligates the
Partnership to participate in the operation of the property and to bear its
proportionate share of all operating costs associated therewith. The Partnership
typically holds less than the entire working interest in its producing
properties.
At December 31, 1999, the Partnership had expended or committed to
expend 100% of the limited partners' net commitments (i.e., limited partners'
commitments available to the Partnership for property acquisitions after payment
of organization fees and expenses) in the acquisition and development of
producing properties, which properties are described under Item 2, "Properties,"
below. The Partnership's revenues and profits are derived almost entirely from
the sale of oil and gas produced from its properties and from the sale of
acquired oil and gas properties, when the sale of such properties is
economically preferable to continued operation.
The Partnership's business and affairs are conducted by its Managing
General Partner, Swift Energy Company, a Texas corporation ("Swift"). The
Partnership's Special General Partner, VJM Corporation, a California corporation
("VJM"), consults with and advises Swift as to certain financial matters. Swift
is the designated operator of many of the properties in which the Partnership
owns interests. The remaining properties are operated by industry operators
designated by the owners of a majority of the working interest in each property.
The general manner in which the Partnership acquires producing
properties and otherwise conducts its business is described in detail in the
Registration Statement under "Proposed Activities," which is incorporated herein
by reference. The following is intended only as a summary of the Partnership's
manner of doing business and specific activities to date.
Liquidation
During the first quarter of 2000, the Managing General Partner mailed
proxy material to the limited partners proposing to sell all the Partnership's
interests in oil and gas properties and dissolve and liquidate the Partnership.
If this proposal is approved, it is anticipated that the liquidation of the
Partnership will be substantially completed within the next two years.
Manner of Acquiring Properties; Net Profits and Overriding Royalty Interest
Agreement
For the sake of legal and administrative convenience, the producing
properties owned by the Registrant have typically been acquired initially by
Swift, which then conveyed ownership of each such property to the Registrant.
The Registrant acquires producing properties from Swift at the property
acquisition cost of such properties to Swift, as adjusted for intervening
operations.
The Registrant entered into a Net Profits and Overriding Royalty
Interest Agreement dated June 30, 1989 (the "NP/OR Agreement") with Swift Energy
Managed Pension Assets Partnership 1989-B, Ltd. (the "Pension Partnership"). The
Pension Partnership is a Texas limited partnership that is also managed by Swift
and VJM. The Pension Partnership was formed to acquire nonoperating interests,
such as net profits, royalty and overriding royalty interests, in producing oil
and gas properties.
I-1
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Under the NP/OR Agreement, the Registrant and the Pension Partnership
have, in effect, combined their funds in acquiring producing properties; using
funds committed to the NP/OR Agreement by both partnerships, the Registrant
acquires producing properties, then promptly conveys nonoperating interests
therein to the Pension Partnership. The Registrant initially committed
$7,024,951 and the Pension Partnership initially committed $3,426,365 for
acquisitions under the NP/OR Agreement. The Registrant is obligated under the
NP/OR Agreement to convey to the Pension Partnership a 33% fixed net profits
interest and a variable overriding royalty interest in specified depths of every
producing property it acquires, except that (i) properties anticipated to
require significant development operations, and (ii) nonoperating interests
offered to the Registrant by third parties may be purchased by the registrant
outside the NP/OR Agreement, without participation by the Pension Partnership.
The Registrant is entitled to withdraw up to 30% of its committed funds under
the NP/OR Agreement for such acquisitions.
All properties acquired by the Registrant since the date of the NP/OR
Agreement have been acquired subject to the NP/OR Agreement and the nonoperating
interests created thereby. At December 31, 1999, the Registrant had not made any
withdrawals to acquire properties anticipated to require significant
development.
In accordance with its obligations under the NP/OR Agreement, as of
December 31, 1999, the Registrant had conveyed to the Pension Partnership a net
profits interest burdening certain depths of all producing properties acquired
by the Registrant since the date of the NP/OR Agreement. Typically, a net
profits interest in an oil and gas property entitles the owner to a specified
percentage share of the gross proceeds generated by the burdened property, net
of operating costs. The 33% net profits interest conveyed to the Pension
Partnership under the NP/OR Agreement differs from the typical net profits
interest in that it is calculated over the entire group of producing properties
acquired under the NP/OR Agreement; i.e., all operating costs attributable to
the burdened depths of such properties are aggregated, and the total is then
subtracted from the total of all gross proceeds attributable to such depths in
order to calculate the net profits to which the Pension Partnership is entitled.
The net profits interest conveyed to the Pension Partnership burdens only those
depths of each subject property which were evaluated to contain proved reserves
at the date of acquisition, to the extent such depths underlie specified surface
acreage.
The Registrant has also conveyed to the Pension Partnership under the
NP/OR Agreement an overriding royalty interest in each property acquired since
the date of the NP/OR Agreement. An overriding royalty interest is a fractional
interest in the gross production (or the gross proceeds therefrom) of oil and
gas from a property, free of any exploration, development, operation or
maintenance expenses. Under the NP/OR Agreement, the overriding royalty interest
burdens the portions of each producing property that were evaluated at the date
of acquisition not to contain proved reserves.
Competition, Markets and Regulations
Competition
The oil and gas industry is highly competitive in all its phases. The
Partnership encounters strong competition from many other oil and gas producers,
many of which possess substantial financial resources, in acquiring economically
desirable Producing Properties.
Markets
The amounts of and price obtainable for oil and gas production from
Partnership Properties will be affected by market factors beyond the control of
the Partnership. Such factors include the extent of domestic production, the
level of imports of foreign oil and gas, the general level of market demand on a
regional, national and worldwide basis, domestic and foreign economic conditions
that determine levels of industrial production, political events in foreign
oil-producing regions, and variations in governmental regulations and tax laws
and the imposition of new governmental requirements upon the oil and gas
industry. There can be no assurance that oil and gas prices will not decrease in
the future, thereby decreasing net Revenues from Partnership Properties.
From time to time, there may exist a surplus of natural gas or oil
supplies, the effect of which may be to reduce the amount of hydrocarbons that
the Partnerships may produce and sell while such oversupply exists. In recent
years, initial steps have been taken to provide additional gas transportation
lines from Canada to the United States. If additional Canadian gas is brought to
the United States market, it could create downward pressure on United States gas
prices.
I-2
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Regulations
Environmental Regulation
The federal government and various state and local governments have
adopted laws and regulations regarding the control of contamination of the
environment. These laws and regulations may require the acquisition of a permit
by Operators before drilling commences, prohibit drilling activities on certain
lands lying within wilderness areas or where pollution arises and impose
substantial liabilities for pollution resulting from operations, particularly
operations near or in onshore and offshore waters or on submerged lands. These
laws and regulations may also increase the costs of routine drilling and
operation of wells. Because these laws and regulations change frequently, the
costs to the Partnership of compliance with existing and future environmental
regulations cannot be predicted. However, the Managing Partner does not believe
that the Partnership is affected in a significantly different manner by these
regulations than are its competitors in the oil and gas industry.
Federal Regulation of Natural Gas
The transportation and sale of natural gas in interstate commerce is
heavily regulated by agencies of the federal government. The following
discussion is intended only as a summary of the principal statutes, regulations
and orders that may affect the production and sale of natural gas from
Partnership Properties. This summary should not be relied upon as a complete
review of applicable natural gas regulatory provisions.
FERC Orders
Several major regulatory changes have been implemented by the Federal
Energy Regulatory Commission ("FERC") from 1985 to the present that affect the
economics of natural gas production, transportation and sales. In addition, the
FERC continues to promulgate revisions to various aspects of the rules and
regulations affecting those segments of the natural gas industry that remain
subject to the FERC's jurisdiction. In April 1992, the FERC issued Order No. 636
pertaining to pipeline restructuring. This rule requires interstate pipelines to
unbundle transportation and sales services by separately stating the price of
each service and by providing customers only the particular service desired,
without regard to the source for purchase of the gas. The rule also requires
pipelines to (i) provide nondiscriminatory "no-notice" service allowing firm
commitment shippers to receive delivery of gas on demand up to certain limits
without penalties, (ii) establish a basis for release and reallocation of firm
upstream pipeline capacity and (iii) provide non-discriminatory access to
capacity by firm transportation shippers on a downstream pipeline. The rule
requires interstate pipelines to use a straight fixed variable rate design. The
rule imposes these same requirements upon storage facilities.
FERC Order No. 500 affects the transportation and marketability of
natural gas. Traditionally, natural gas has been sold by producers to pipeline
companies, which then resold the gas to end-users. FERC Order No. 500 alters
this market structure by requiring interstate pipelines that transport gas for
others to provide transportation service to producers, distributors and all
other shippers of natural gas on a nondiscriminatory, "first-come, first-served"
basis ("open access transportation"), so that producers and other shippers can
sell natural gas directly to end-users. FERC Order No. 500 contains additional
provisions intended to promote greater competition in natural gas markets.
It is not anticipated that the marketability of and price obtainable
for natural gas production from Partnership Properties will be significantly
affected by FERC Order No. 500. Gas produced from Partnership Properties
normally will be sold to intermediaries who have entered into transportation
arrangements with pipeline companies. These intermediaries will accumulate gas
purchased from a number of producers and sell the gas to end-users through open
access pipeline transportation.
State Regulations
Production of any oil and gas from Partnership Properties will be
affected to some degree by state regulations. Many states in which the
Partnership will operate have statutory provisions regulating the production and
sale of oil and gas, including provisions regarding deliverability. Such
statutes, and the regulations promulgated in connection therewith, are generally
intended to prevent waste of oil and gas and to protect correlative rights to
produce oil and gas between owners of a common reservoir. Certain state
regulatory authorities also regulate the amount of oil and gas produced by
assigning allowable rates of production to each well or proration unit.
I-3
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Federal Leases
Some of the Partnership's properties are located on federal oil and gas
leases administered by various federal agencies, including the Bureau of Land
Management. Various regulations and orders affect the terms of leases,
exploration and development plans, methods of operation and related matters.
Employees
The Partnership has no employees. Swift, however, has a staff of
geologists, geophysicists, petroleum engineers, landmen, and accounting
personnel who administer the operations of Swift and the Partnership. As of
December 31, 1999, Swift had 173 employees. Swift's administrative and overhead
expenses attributable to the Partnership's operations are borne by the
Partnership.
I-4
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Item 2. Properties
As of December 31, 1999, the Partnership has acquired interests in
producing oil and gas properties which are generally described below.
Principal Oil and Gas Producing Properties
The most valuable fields in the Partnership, based upon year-end
engineering estimates of discounted future net revenues using constant pricing
and costs, are described below.
1. The AWP Field is in McMullen County, Texas (Shell Oil Company
acquisition). The wells produce from the Olmos formation, accounting for 57% of
the value.
The remaining value in the Partnership is attributable to numerous
properties none of which equals or exceeds 15 percent of the total Partnership
value.
Title to Properties
Title to substantially all significant producing properties of the
Partnership has been examined. The properties are subject to royalty, overriding
royalty and other interests customary in the industry. The Managing General
Partner does not believe any of these burdens materially detract from the value
of the properties or will materially detract from the value of the properties or
materially interfere with their use in the operation of the business of the
Partnership.
Production and Sales Price
The following table summarizes the sales volumes of the Partnership's
net oil and gas production expressed in MCFs. Equivalent MCFs are obtained by
converting oil to gas on the basis of their relative energy content; one barrel
equals 6,000 cubic feet of gas.
<TABLE>
<CAPTION>
Net Production
-------------------------------------------
For the Years Ended
December 31,
-------------------------------------------
1999 1998 1997
------- ------- -------
<S> <C> <C> <C>
Net Volumes (Equivalent MCFs) 336,083 435,490 553,381
Average Sales Price
per Equivalent MCF $2.58 $2.00 $2.86
Average Production Cost
per Equivalent MCF
(includes production taxes) $0.91 $0.90 $0.91
</TABLE>
I-5
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Net Proved Oil and Gas Reserves
Presented below are the estimates of the Partnership's proved reserves
as of December 31, 1999, 1998 and 1997. All of the Partnership's proved reserves
are located in the United States.
<TABLE>
<CAPTION>
December 31,
----------------------------------------------------------------------------------
1999 1998 1997
------------------------ ------------------------- -------------------------
Natural Natural Natural
Oil Gas Oil Gas Oil Gas
---------- -------- ---------- --------- ---------- --------
(BBLS) (MMCF) (BBLS) (MMCF) (BBLS) (MMCF)
<S> <C> <C> <C> <C> <C> <C>
Proved developed
reserves at end of year 82,942 1,227 129,401 1,681 221,271 1,849
========== ======== ========== ======== ========== =========
Proved reserves
Balance at beginning
of year 149,252 1,879 258,253 2,284 319,784 2,696
Extensions, discoveries
and other additions 8,540 26 5 1 -- --
Revisions of previous
estimates 26,030 218 (74,853) (175) (13,163) (18)
Sales of minerals in
place (52,695) (490) -- -- (2,042) (119)
Production (21,316) (208) (34,153) (231) (46,326) (275)
--------- -------- ---------- --------- ---------- ---------
Balance at end of year 109,811 1,425 149,252 1,879 258,253 2,284
========== ======== ========== ========= ========== =========
</TABLE>
Revisions of previous quantity estimates are related to upward or
downward variations based on current engineering information for production
rates, volumetrics and reservoir pressure. Additionally, changes in quantity
estimates are the result of the increase or decrease in crude oil and natural
gas prices at each year end which have the effect of adding or reducing proved
reserves on marginal properties due to economic limitations.
I-6
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
The following table summarizes by acquisition the Registrant's reserves
and gross and net interests in producing oil and gas wells as of December 31,
1999:
<TABLE>
<CAPTION>
Reserves
December 31, 1999
---------------------
Natural Wells
Oil Gas -----------------------
Acquisition State(s) (BBLS) (MMCF) Gross Net
- ---------- --------- ------- ------ ----- -------
<S> <C> <C> <C> <C> <C>
Shell Oil Company TX 45,318 976 67 2.912
Union Pacific AR, KS, NM,
OK, TX 19,476 141 127 5.072
Ellison OK 15,320 1 40 1.067
Cairn AL, AR, CA, KS,
LA, MI, MS, NM,
OK, TX, WY 5,893 20 177 1.828
Hyde AK, LA, OK, TX 1,666 101 25 0.712
Norcen Explorer WY 19,817 -- 29 0.975
U.S. Companies TX 51 6 19 0.457
Mission Oil
Company TX 510 22 47 0.308
Hardy Oil Company TX 627 26 4 0.012
Amoco OK 1,133 132 108 2.243
------- ------ ----- -------
109,811 1,425 643 15.586
======= ====== ===== =======
</TABLE>
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting the future rates of production, timing and
plan of development. Oil and gas reserve engineering must be recognized as a
subjective process of estimating underground accumulations of oil and gas that
cannot be measured in an exact way, and estimates of other engineers might
differ from those above, audited by H. J. Gruy and Associates, Inc., an
independent petroleum consulting firm. The accuracy of any reserve estimate is a
function of the quality of available data and of engineering and geological
interpretation and judgment. Results of drilling, testing and production
subsequent to the date of the estimate may justify revision of such estimate,
and, as a general rule, reserve estimates based upon volumetric analysis are
inherently less reliable than those based on lengthy production history.
Accordingly, reserve estimates are often different from the quantities of oil
and gas that are ultimately recovered.
In estimating the oil and natural gas reserves, the Registrant, in
accordance with criteria prescribed by the Securities and Exchange Commission,
has used prices received as of December 31, 1999 without escalation, except in
those instances where fixed and determinable gas price escalations are covered
by contracts, limited to the price the Partnership reasonably expects to
receive. The Registrant does not believe that any favorable or adverse event
causing a significant change in the estimated quantity of proved reserves has
occurred between December 31, 1999 and the date of this report.
Future prices received for the sale of the Partnership's products may
be higher or lower than the prices used in the evaluation described above; the
operating costs relating to such production may also increase or decrease from
existing levels. The estimates presented above are in accordance with rules
adopted by the Securities and Exchange Commission.
Item 3. Legal Proceedings
The Partnership is not aware of any material pending legal proceedings
to which it is a party or of which any of its property is the subject.
Item 4. Submission of Matters to a Vote of Security Holders
No matters were submitted to a vote of limited partners during the
fourth quarter of the fiscal year covered by this report.
I-7
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
PART II
Item 5. Market Price of and Distributions on the Registrant's Units and
Related Limited Partner Matters
Market Information
Units in the Partnership were initially sold at a price of $100 per
Unit. Units are not traded on any exchange and there is no established public
trading market for the Units. Swift is aware of negotiated transfers of Units
between unrelated parties; however, these transfers have been limited and
sporadic. Due to the nature of these transactions, Swift has no verifiable
information regarding prices at which Units have been transferred.
Holders
As of December 31, 1999, there were 598 Limited Partners holding Units
in the Partnership.
Distributions
The Partnership generally makes distributions to Limited Partners on a
quarterly basis, subject to the restrictions set forth in the Limited
Partnership Agreement. In the fiscal years ending December 31, 1998 and 1999,
the Partnership distributed a total of $801,700 and $308,200, respectively, to
holders of its Units. Cash distributions constitute net proceeds from sale of
oil and gas production after payment of lease operating expenses and other
partnership expenses. Some or all of such amounts or any proceeds from the sale
of partnership properties could be deemed to constitute a return of investors'
capital.
Oil and gas investments involve a high risk of loss, and no assurance
can be given that any particular level of distributions to holders of Units can
be achieved or maintained. Although it is anticipated that quarterly
distributions will continue to be made through 2000, the Partnership's ability
to make distributions could be diminished by any event adversely affecting the
oil and gas properties in which the Partnership owns interests or the amount of
revenues received by the Partnership therefrom.
The Partnership's Limited Partnership Agreement contains various
provisions which might serve to delay, defer or prevent a change in control of
the Partnership, such as the requirement of a vote of Limited Partners in order
to sell all or substantially all of the Partnership's properties or the
requirement of consent by the Managing General Partner to transfers of limited
partnership interests.
II-1
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Item 6. Selected Financial Data
The following selected financial data, prepared in accordance with
generally accepted accounting principles as of December 31, 1999, 1998, 1997,
1996 and 1995, should be read in conjunction with the financial statements
included in Item 8:
<TABLE>
<CAPTION>
1999 1998 1997 1996 1995
------------- ------------- ------------- ------------- -------------
<S> <C> <C> <C> <C> <C>
Revenues $ 898,995 $ 919,530 $ 1,668,209 $ 2,087,152 $ 1,446,892
Income (Loss) $ 164,300 $ (826,418) $ 545,642 $ 878,068 $ 88,233
Total Assets $ 1,850,190 $ 2,190,617 $ 3,871,732 $ 4,602,323 $ 4,553,686
Cash Distributions $ 362,356 $ 867,764 $ 1,171,200 $ 621,647 $ 327,156
Long Term Obligations $ -- $ -- $ -- $ -- $ --
Limited Partners' Net
Income (Loss) Per Unit $ 1.73 $ (10.52) $ 5.53 $ 9.11 $ (.61)
Limited Partners' Cash
Distributions Per Unit $ 3.70 $ 9.63 $ 12.63 $ 6.25 $ 3.32
</TABLE>
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations
Liquidity and Capital Resources
Oil and gas reserves are depleting assets and therefore often experience
significant production declines each year from the date of acquisition through
the end of the life of the property. The primary source of liquidity to the
Partnership comes almost entirely from the income generated from the sale of oil
and gas produced from ownership interests in oil and gas properties. This source
of liquidity and the related results of operations, and in turn cash
distributions, will decline in future periods as the oil and gas produced from
these properties also declines while production and general and administrative
costs remain relatively stable making it unlikely that the Partnership will hold
the properties until they are fully depleted, but will likely liquidate when a
substantial majority of the reserves have been produced. Cash distributions to
partners are determined quarterly, based upon net proceeds from sale of oil and
gas production after payment of lease operating expense, taxes and development
costs, less general and administrative expenses. In addition, future partnership
cash requirements are taken into account to determine necessary cash reserves.
Net cash provided by operating activities totaled $310,655, $631,921 and
$1,136,772 in 1999, 1998 and 1997, respectively. The decrease in cash provided
by operating activities in 1999 is related to changes in oil and gas sales
receivable and accounts payable. Cash provided by property sale proceeds totaled
$475,322 and $147,994 in 1999 and 1997, respectively. Capital expenditures
totaled $56,850, $153,380 and $220,719 in 1999, 1998 and 1997, respectively.
Cash distributions totaled $362,356, $867,764 and $1,171,200 in 1999, 1998 and
1997, respectively. In 1999, cash distributions were effected by production
declines from the 1999 property sales and low oil and gas prices received during
the first part of this year.
The Partnership has expended all of the partners' net commitments
available for property acquisitions and development by acquiring producing oil
and gas properties. The partnership invests primarily in proved producing
properties with nominal levels of future costs of development for proven but
undeveloped reserves. Significant purchases of additional reserves or extensive
drilling activity are not anticipated. The Partnership does not allow for
additional assessments from the partners to fund capital requirements. However,
funds in addition to the remaining unexpended net capital commitments of the
partners are available from partnership revenues, borrowings or proceeds from
the sale of partnership property. Subject to 2000 market conditions remaining
comparable with 1999, the Managing General Partner anticipates an increase in
liquidity, provided that certain development work scheduled in 2000 is completed
successfully. The Partnership plans to spend in the next two years an estimated
$196,000 for capital expenditures needed for this development work and the
enhancement of proved oil and gas reserves. The Managing General Partner
believes that the funds currently available to the Partnership will be adequate
to meet any anticipated capital requirements.
II-2
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
Results of Operations
Oil and gas sales declined $21,380 or 2 percent in 1999 vs. 1998,
primarily due to decreased oil and gas production. In 1999, production volumes
decreased 23 percent as oil and gas production declined 38 percent and 10
percent, respectively, when compared to 1998. Production declines were a result
of the accelerated depletion of the Partnership's mature wells and the
Partnership's property sales. Oil prices increased 54 percent or $6.01/BBL to an
average of $17.06/BBL and gas prices increased 13 percent or $0.28/MCF to an
average of $2.42/MCF for 1999. Increased oil and gas prices helped offset the
effect of decreased production.
Corresponding production costs per equivalent MCF remained flat in 1999
compared to 1998, and total production costs decreased 22 percent in 1999, due
to production declines.
Total depreciation expense for 1999 decreased 79 percent or $955,683
when compared to 1998. In 1998, two components, the normal provision, calculated
on the units of production method, and the additional provision, relating to the
ceiling limitation, make up total depreciation expense. Normal depreciation
expense decreased 36 percent or $140,551 in 1999 compared to 1998, related to
the decline in production volumes.
Oil and gas sales decreased 45 percent in 1998 vs. 1997. A decline in
the 1998 oil prices received of 38 percent or $6.73/BBL had a significant impact
on partnership performance. The average sales price per equivalent MCF decreased
30 percent in 1998 as oil prices decreased 38 percent and gas prices declined 23
percent. Also, production volumes decreased 21 percent due to a 26 percent oil
production decrease and a 16 percent production decline.
Production cost per equivalent MCF decreased a slight 1 percent in 1998
compared to 1997; however, total production costs decreased 22 percent in 1998.
Associated depreciation expense decreased 16 percent in 1998 when
compared to 1997, also related to the decline in production volumes.
The Partnership recorded an additional provision in depreciation,
depletion and amortization in 1998 of $815,132 when the present value,
discounted at ten percent, of estimated future net revenues from oil and gas
properties, using the guidelines of the Securities and Exchange Commission, was
below the fair market value paid for oil and gas properties resulting in a full
cost ceiling impairment.
During 2000, Partnership revenues and costs will be shared between the
limited partners and general partners in an 85:15 ratio, based on Partnership
payout having occurred in January 1998.
Year 2000
The Year 2000 issue resulted from computer programs and embedded
computer chips with date fields which could not distinguish between the years
1900 and 2000. The Managing General Partner implemented steps necessary to make
its operations and the related operations of the Partnership capable of
addressing the Year 2000. These steps included upgrading, testing and certifying
its computer systems and field operation services and obtaining Year 2000
compliance certification from all important business suppliers. The Managing
General Partner formed a task force during 1998 to address the Year 2000 issue
and prepare its business systems for the Year 2000. The Managing General Partner
either replaced or updated mission critical systems and completed testing before
2000 began.
The Managing General Partner's business systems are almost entirely
comprised of off-the-shelf software. Most of the necessary changes in computer
instructional code were made by upgrading this software. In addition, the
Managing General Partner received certification as to Year 2000 compliance from
vendors or third party consultants.
The costs incurred to address the Year 2000 issue with respect to the
Managing General Partners' business systems did not have a material effect on
the Partnership's results of operations, or its liquidity and financial
condition. The estimated total cost to the Managing General Partner to address
Year 2000 issues was less than $150,000, most of which was spent during the
testing phase. The Partnership's share of this cost was insignificant.
II-3
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
The most reasonably likely worst case scenario would have been a
prolonged disruption of external power sources upon which core equipment relies,
resulting in a substantial decrease in the Partnership's oil and gas production
activities. In addition, the pipeline operators to whom the Managing General
Partner sells the Partnership's natural gas, as well as other customers and
suppliers, could have been prone to Year 2000 problems that could not be
assessed or detected by the Managing General Partner.
As of the filing of this report, the Managing General Partner is not
aware of any Year 2000 problems either experienced by it or by parties which it
does business, and does not expect to experience such problems in the future.
Item 8. Financial Statements and Supplementary Data
See Part IV, Item 14(a) for index to financial statements.
Item 9. Disagreements on Accounting and Financial Disclosure
None.
II-4
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
PART III
Item 10. Directors and Executive Officers of the Registrant
As a limited partnership, the Registrant has no directors or executive
officers. The business and affairs of the Registrant are managed by Swift as
Managing General Partner. Set forth below is certain information as of March 10,
2000 regarding the directors and executive officers of Swift.
<TABLE>
<CAPTION>
Position(s) with
Name Age Swift and Other Companies
---- --- -------------------------
DIRECTORS
---------
<S> <C> <C>
A. Earl Swift 66 Chief Executive Officer and
Chairman of the Board
Virgil N. Swift 71 Executive Vice President - Business
Development, Vice Chairman of the Board
G. Robert Evans 68 Director of Swift; Chairman of the Board,
Material Sciences Corporation;
Director, Consolidated Freightways, Inc.,
Fibreboard Corporation, Elco Industries, and
Old Second Bancorp
Raymond O. Loen 75 Director of Swift; President, R. O. Loen
Company
Henry C. Montgomery 64 Director of Swift; Chairman of the Board,
Montgomery Financial Services Corporation;
Director, Southwall Technology Corporation
Clyde W. Smith, Jr. 51 Director of Swift; President, Somerset
Properties, Inc.
Harold J. Withrow 72 Director of Swift
EXECUTIVE OFFICERS
------------------
Terry E. Swift 44 President
Joe A. D'Amico 51 Chief Operating Officer
John R. Alden 54 Senior Vice President - Finance,
Chief Financial Officer and Secretary
Bruce H. Vincent 52 Senior Vice President - Funds Management
James M. Kitterman 55 Senior Vice President - Operations
Alton D. Heckaman, Jr. 42 Vice President - Finance and Controller
</TABLE>
III-1
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
From time to time, Swift as Managing General Partner of the Partnership
purchases Units in the Partnership from investors who offer the Units pursuant
to their right of presentment, which purchases are made pursuant to terms set
out in the Partnership's original Limited Partnership Agreement. Due to the
frequency and large number of these transactions, Swift reports these
transactions under Section 16 of the Securities Exchange Act of 1934 on an
annual rather than a monthly basis. In some cases such annual reporting may
constitute a late filing of the required Section 16 reports under the applicable
Section 16 rules.
Item 11. Executive Compensation
As noted in Item 10, "Directors and Executive Officers of the
Registrant," above, the Partnership has no executive officers. The executive
officers of Swift and VJM are not compensated by the Partnership.
Certain fees and allowances contemplated by the Limited Partnership
Agreement have been paid by the Partnership to Swift and VJM. See Note (4) in
Notes To Financial Statements (Related-Party Transactions) for further
discussion.
Item 12. Security Ownership of Certain Beneficial Owners and Management
Swift Energy Company, the Managing General Partner, located at 16825
Northchase Drive, Suite 400, Houston, Texas 77060, owns 7,514 Limited
Partnership Units, which is 9.11 percent of all outstanding Limited Partnership
Units. All Limited Partnership Units owned by Swift were acquired from investors
who offered the Limited Partnership Units pursuant to their right of
presentment. As the Managing General Partner, Swift is not permitted generally,
under the Limited Partnership Agreement, to vote its Limited Partnership Units.
Swift also owns a general partnership interest of 13.5 percent of all
partnership interests in the Partnership.
Swift and VJM are not aware of any arrangement, the operation of which
may at a subsequent date result in a change in control of the Partnership.
Item 13. Certain Relationships and Related Transactions
As noted in Item 10, "Directors and Executive Officers of the
Registrant," above, the Partnership has no executive officers or directors, and
thus has not engaged in any transactions in which any such person had an
interest. The Partnership is permitted to engage in certain transactions with
Swift as Managing General Partner and VJM as Special General Partner, subject to
extensive guidelines and restrictions as described in the "Conflicts of
Interest" section of the Amended Prospectus contained in the Registration
Statement, which is incorporated herein by reference.
Summarized below are the principal transactions that have occurred
between the Partnership and Swift, VJM and their affiliates.
1. The oil and gas properties acquired by the Partnership, as described
in Item 2, "Properties" above, were typically acquired initially by Swift from
the seller thereof and subsequently transferred to the Partnership. Such
transfers were made by Swift at its Property Acquisition Costs (as defined in
the Limited Partnership Agreement), less any amounts received from sale of
production between the time of acquisition by Swift and the time of sale to the
Partnership.
2. Swift acts as operator for many of the wells in which the
Partnership has acquired interests and has received compensation for such
activities in accordance with standard industry operating agreements.
3. The Partnership paid to Swift and VJM certain fees as contemplated
by the Limited Partnership Agreement. See Note (4) in Notes To Financial
Statements (Related-Party Transactions) for further discussion.
III-2
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K
<TABLE>
<CAPTION>
a(1) FINANCIAL STATEMENTS PAGE NO.
-------------------- --------
<S> <C>
Report of Independent Public Accountants IV-2
Balance Sheets as of December 31, 1999 and 1998 IV-3
Statements of Operations for the years ended
December 31, 1999, 1998 and 1997 IV-4
Statements of Partners' Capital for the years ended
December 31, 1999, 1998 and 1997 IV-5
Statements of Cash Flows for the years ended
December 31, 1999, 1998 and 1997 IV-6
Notes to Financial Statements IV-7
</TABLE>
a(2) FINANCIAL STATEMENT SCHEDULES
All schedules required by the SEC are either inapplicable or the
required information is included in the Financial Statements, the
Notes thereto, or in other information included elsewhere in this
report.
a(3) EXHIBITS
3.1 Limited Partnership Agreement of Swift Energy Income
Partners 1989-B, Ltd., dated May 31, 1989. (Form 10-K for
year ended December 31, 1989, Exhibit 3.1).
3.2 Certificate of Limited Partnership of Swift Energy Income
Partners 1989-B, Ltd., as filed June 30, 1989, with the
Texas Secretary of State. (Form 10-K for year ended
December 31, 1989, Exhibit 3.2).
10.1 Net Profits and Overriding Royalty Interest Agreement
between Swift Energy Income Partners 1989-B, Ltd. and
Swift Energy Managed Pension Assets Partnership 1989-B,
Ltd. dated June 30, 1989. (Form 10-K for the year ended
December 31, 1989, Exhibit 10.1).
99.1 A copy of the following section of the Amended Prospectus
dated March 28, 1988, contained in Post-Effective
Amendment No. 1 to Registration Statement No. 33-11773 on
Form S-1 for Swift Energy Income Partners III, as filed on
March 25, 1988, which have been incorporated herein by
reference: "Proposed Activities" (pp 36 - 50) and
"Conflicts of Interest" (pp. 70 - 78). (Form 10-K for year
ended December 31, 1989, Exhibit 28.1).
b(1) REPORTS ON FORM 8-K
No reports on Form 8-K have been filed during the quarter ended
December 31, 1999.
Supplemental Information to be Furnished with Reports Filed Pursuant to Section
15(d) of the Act by Registrants Which Have Not Registered Securities Pursuant to
Section 12 of the Act.
No annual report to security holders covering the Partnership's 1999
fiscal year has been sent to Limited Partners of the Partnership.
IV-1
<PAGE>
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To Swift Energy Income Partners 1989-B, Ltd.:
We have audited the accompanying balance sheets of Swift Energy Income
Partners 1989-B, Ltd., (a Texas limited partnership) as of December 31, 1999 and
1998, and the related statements of operations, partners' capital and cash flows
for the years ended December 31, 1999, 1998 and 1997. These financial statements
are the responsibility of the Managing General Partner's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and perform
the audit to obtain reasonable assurance about whether the financial statements
are free of material misstatement. An audit includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial statements. An
audit also includes assessing the accounting principles used and significant
estimates made by management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present
fairly, in all material respects, the financial position of Swift Energy Income
Partners 1989-B, Ltd., as of December 31, 1999 and 1998, and the results of its
operations and its cash flows for the years ended December 31, 1999, 1998 and
1997, in conformity with accounting principles generally accepted in the United
States.
ARTHUR ANDERSEN LLP
Houston, Texas
February 9, 2000
IV-2
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
BALANCE SHEETS
DECEMBER 31, 1999 AND 1998
<TABLE>
<CAPTION>
1999 1998
-------------- --------------
ASSETS:
<S> <C> <C>
Current Assets:
Cash and cash equivalents $ 368,082 $ 1,311
Oil and gas sales receivable 184,848 191,690
-------------- --------------
Total Current Assets 552,930 193,001
-------------- --------------
Gas Imbalance Receivable 31,442 64,023
-------------- --------------
Oil and Gas Properties, using full cost
accounting 8,252,610 8,671,082
Less-Accumulated depreciation, depletion
and amortization (6,986,792) (6,737,489)
-------------- --------------
1,265,818 1,933,593
-------------- --------------
$ 1,850,190 $ 2,190,617
============== ==============
LIABILITIES AND PARTNERS' CAPITAL:
Current Liabilities:
Accounts Payable $ 45,582 $ 158,562
-------------- --------------
Deferred Revenues 23,239 52,630
Limited Partners' Capital (83,295 Limited Partnership
Units; $100 per unit) 1,768,836 1,957,698
General Partners' Capital 12,533 21,727
-------------- --------------
Total Partners' Capital 1,781,369 1,979,425
-------------- --------------
$ 1,850,190 $ 2,190,617
============== ==============
</TABLE>
See accompanying notes to financial statements.
IV-3
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
STATEMENTS OF OPERATIONS
FOR THE YEARS ENDED DECEMBER 31, 1999, 1998 AND 1997
<TABLE>
<CAPTION>
1999 1998 1997
-------------- -------------- --------------
REVENUES:
<S> <C> <C> <C>
Oil and gas sales $ 886,798 $ 908,178 $ 1,637,588
Interest income 12,197 5,025 22,462
Other -- 6,327 8,159
-------------- -------------- --------------
898,995 919,530 1,668,209
-------------- -------------- --------------
COSTS AND EXPENSES:
Lease operating 266,415 341,962 414,190
Production taxes 40,580 50,333 89,684
Depreciation, depletion
and amortization -
Normal 249,303 389,854 463,397
Additional -- 815,132 --
General and administrative 178,397 148,667 155,296
-------------- -------------- --------------
734,695 1,745,948 1,122,567
-------------- -------------- --------------
NET INCOME (LOSS) $ 164,300 $ (826,418) $ 545,642
============== ============== ==============
</TABLE>
See accompanying notes to financial statements.
IV-4
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
STATEMENTS OF PARTNERS' CAPITAL
FOR THE YEARS ENDED DECEMBER 31, 1999, 1998 AND 1997
<TABLE>
<CAPTION>
Limited General Combining
Partners Partners Adjustment Total
-------------- -------------- -------------- --------------
<S> <C> <C> <C> <C>
Balance,
December 31, 1996 $ 4,125,593 $ 87,223 $ 86,349 $ 4,299,165
Income (Loss) 460,810 81,986 2,846 545,642
Cash Distributions (1,051,600) (119,600) -- (1,171,200)
-------------- -------------- -------------- --------------
Balance,
December 31, 1997 3,534,803 49,609 89,195 3,673,607
-------------- -------------- -------------- --------------
Income (Loss) (876,218) 38,182 11,618 (826,418)
Cash Distributions (801,700) (66,064) -- (867,764)
-------------- -------------- -------------- --------------
Balance,
December 31, 1998 1,856,885 21,727 100,813 1,979,425
-------------- -------------- -------------- --------------
Income (Loss) 144,473 44,962 (25,135) 164,300
Cash Distributions (308,200) (54,156) -- (362,356)
-------------- -------------- -------------- --------------
Balance,
December 31, 1999 $ 1,693,158 $ 12,533 $ 75,678 $ 1,781,369
============== ============== ============== ==============
Limited Partners' net income (loss)
per unit
1997 $ 5.53
==============
1998 $ (10.52)
==============
1999 $ 1.73
==============
</TABLE>
See accompanying notes to financial statements.
IV-5
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER 31, 1999, 1998 AND 1997
<TABLE>
<CAPTION>
1999 1998 1997
------------- ------------- --------------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Income (loss) $ 164,300 $ (826,418) $ 545,642
Adjustments to reconcile income (loss) to
net cash provided by operations:
Depreciation, depletion and amortization 249,303 1,204,986 463,397
Change in gas imbalance receivable
and deferred revenues 3,190 22,853 31,690
Change in assets and liabilities:
(Increase) decrease in oil and gas sales receivable 6,842 210,345 191,348
Increase (decrease) in accounts payable (112,980) 20,155 (95,305)
------------- ------------- --------------
Net cash provided by (used in) operating activities 310,655 631,921 1,136,772
------------- ------------- --------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas properties (56,850) (153,380) (220,719)
Proceeds from sales of oil and gas properties 475,322 -- 147,994
------------- ------------- --------------
Net cash provided by (used in) investing activities 418,472 (153,380) (72,725)
------------- ------------- --------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Cash distributions to partners (362,356) (867,764) (1,171,200)
------------- ------------- --------------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 366,771 (389,223) (107,153)
------------- ------------- --------------
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 1,311 390,534 497,687
------------- ------------- --------------
CASH AND CASH EQUIVALENTS AT END OF YEAR $ 368,082 $ 1,311 $ 390,534
============= ============= ==============
</TABLE>
See accompanying notes to financial statements.
IV-6
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
NOTES TO FINANCIAL STATEMENTS
(1) Organization and Terms of Partnership Agreement -
Swift Energy Income Partners 1989-B, Ltd., a Texas limited partnership
("the Partnership"), was formed on June 30, 1989, for the purpose of purchasing
and operating producing oil and gas properties within the continental United
States. Swift Energy Company ("Swift"), a Texas corporation, and VJM Corporation
("VJM"), a California corporation, serve as Managing General Partner and Special
General Partner of the Partnership, respectively. The general partners are
required to contribute up to 1/99th of limited partner net contributions. The
661 limited partners made total capital contributions of $8,329,500.
Property acquisition costs and the management fee are borne 99 percent
by the limited partners and one percent by the general partners. Organization
and syndication costs were borne solely by the limited partners.
Initially, all continuing costs (including development costs, operating
costs, general and administrative reimbursements and direct expenses) and
revenues are allocated 90 percent to the limited partners and ten percent to the
general partners. If prior to partnership payout, as defined, however, the cash
distribution rate (as defined in the Partnership Agreement) for a certain period
equals or exceeds 17.5 percent, then for the following calendar year, these
continuing costs and revenues will be allocated 85 percent to the limited
partners and 15 percent to the general partners. After partnership payout,
continuing costs and revenues will be shared 85 percent by the limited partners,
and 15 percent by the general partners, even if the cash distribution rate is
less than 17.5 percent. During 1992 and 1991, the cash distribution rate
exceeded 17.5 percent and thus, in 1993 and 1992, the continuing costs and
revenues were shared 85 percent by the limited partners and 15 percent by the
general partners. During 1997, 1996, 1995, 1994 and 1993, the cash distribution
rate fell below 17.5 percent and thus, in 1997, 1996, 1995 and 1994 the
continuing costs and revenues were shared 90 percent by the limited partners and
10 percent by the general partners. Payout occurred in January 1998; therefore,
for 1998 and each year remaining in the life of the partnership, the continuing
costs and revenues were (will be) shared 85 percent by the limited partners and
15 percent by the general partners.
During the first quarter of 2000, the Managing General Partner mailed
proxy material to the limited partners proposing to sell all the Partnership's
interests in oil and gas properties and dissolve and liquidate the Partnership.
If this proposal is approved, it is anticipated that the liquidation of the
Partnership will be substantially completed within the next two years.
(2) Significant Accounting Policies -
Use of Estimates --
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities at the
date of the financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from
estimates.
Oil and Gas Revenues --
Oil and gas revenues are reported using the entitlement method in which
the Partnership recognizes its interest in oil and natural gas production as
revenue.
Oil and Gas Properties --
The Partnership accounts for its ownership interest in oil and gas
properties using the proportionate consolidation method, whereby the
Partnership's share of assets, liabilities, revenues and expenses is included in
the appropriate classification in the financial statements.
For financial reporting purposes, the Partnership follows the
"full-cost" method of accounting for oil and gas property costs. Under this
method of accounting, all productive and nonproductive costs incurred in the
acquisition and development of oil and gas reserves are capitalized. Such costs
include lease acquisitions, geological and geophysical services, drilling,
completion, equipment and certain general and administrative costs directly
associated with acquisition and development activities. General and
administrative costs related to production and general overhead are expensed as
incurred. No general and administrative costs were capitalized during the years
ended December 31, 1999, 1998 and 1997.
IV-7
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
Future development, site restoration, dismantlement and abandonment
costs, net of salvage values, are estimated on a property-by-property basis
based on current economic conditions and are amortized to expense as the
Partnership's capitalized oil and gas property costs are amortized.
The unamortized cost of oil and gas properties is limited to the
"ceiling limitation", (calculated separately for the Partnership, limited
partners, and general partners). The "ceiling limitation" is calculated on a
quarterly basis and represents the estimated future net revenues from proved
properties using current prices, discounted at ten percent. Proceeds from the
sale or disposition of oil and gas properties are treated as a reduction of oil
and gas property costs with no gains or losses being recognized except in
significant transactions.
The Partnership computes the provision for depreciation, depletion and
amortization of oil and gas properties on the units-of-production method. Under
this method, the provision is calculated by multiplying the total unamortized
cost of oil and gas properties, including future development, site restoration,
dismantlement and abandonment costs, by an overall amortization rate that is
determined by dividing the physical units of oil and gas produced during the
period by the total estimated units of proved oil and gas reserves at the
beginning of the period.
The calculation of the "ceiling limitation" and the provision for
depreciation, depletion, and amortization is based on estimates of proved
reserves. There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting the future rates of production, timing and
plan of development. The accuracy of any reserve estimate is a function of the
quality of available data and of engineering and geological interpretation and
judgment. Results of drilling, testing and production subsequent to the date of
the estimate may justify revision of such estimate. Accordingly, reserve
estimates are often different from the quantities of oil and gas that are
ultimately recovered.
Cash and Cash Equivalents --
Highly liquid debt instruments with an initial maturity of three months
or less are considered to be cash equivalents.
Reclassifications --
Certain reclassifications have been made to the prior year balances to
conform with the current year presentation.
(3) Oil and Gas Capitalized Costs -
The following table sets forth capital expenditures related to the
Partnership's oil and gas operations:
<TABLE>
<CAPTION>
Year Ended December 31,
--------------------------------------------
1999 1998 1997
-------- -------- ---------
<S> <C> <C> <C>
Acquisition of
proved properties $ -- $ -- $ --
Development 56,850 153,380 2 20,719
-------- -------- --------
$ 56,850 $153,380 $ 220,719
======== ======== =========
</TABLE>
All oil and gas property acquisitions are made by Swift on behalf of
the Partnership. The costs of the properties include the purchase price plus any
costs incurred by Swift in the evaluation and acquisition of properties.
IV-8
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
During 1998, the Partnership's unamortized oil and gas property costs
exceeded the quarterly calculations of the "ceiling limitation" resulting in an
additional provision for depreciation, depletion and amortization of $815,132.
In addition, the limited partners' share of unamortized oil and gas property
costs exceeded their "ceiling limitation" in 1998 resulting in a valuation
allowance of $853,480. This amount is included in the income (loss) attributable
to the limited partners shown in the statements of partners' capital together
with a "combining adjustment" for the differences between the limited partners'
valuation allowances and the Partnership's full cost ceiling write down. The
"combining adjustment" changes quarterly as the Partnership's total
depreciation, depletion and amortization provision is more or less than the
combined depreciation, depletion and amortization provision attributable to the
general and limited partners.
(4) Related-Party Transactions -
An affiliate of the Special General Partner, as Dealer Manager,
received $202,238 for managing and overseeing the offering of limited
partnership units.
A one-time management fee of $208,238 was paid to Swift in 1989 for
services performed for the Partnership. During 1999, 1998 and 1997, the
Partnership paid Swift $124,943 per year as a general and administrative
overhead allowance.
Effective June 30, 1989, the Partnership entered into a Net Profits and
Overriding Royalty Interest Agreement ("NP/OR Agreement") with Swift Energy
Managed Pension Assets Partnership 1989-B, Ltd. ("Pension Partnership"), managed
by Swift for the purpose of acquiring working interests in producing oil and gas
properties. Under terms of the NP/OR Agreement, the Partnership has conveyed to
the Pension Partnership a nonoperating interest in the aggregate net profits
(i.e., oil and gas sales net of related operating costs) of the properties
acquired equal to its proportionate share of the property acquisition costs.
(5) Federal Income Taxes -
The Partnership is not a tax-paying entity. No provision is made in the
accounts of the Partnership for federal or state income taxes, since such taxes
are liabilities of the individual partners, and the amounts thereof depend upon
their respective tax situations.
The tax returns and the amount of distributable Partnership income are
subject to examination by the federal and state taxing authorities. If the
Partnership's ordinary income for federal income tax purposes is ultimately
changed by the taxing authorities, the tax liability of the limited partners
could be changed accordingly. Ordinary income reported on the Partnership's
federal return of income for the years ended December 31, 1999, 1998 and 1997
was $516,789, $363,951 and $1,010,086, respectively. The difference between
ordinary income for federal income tax purposes reported by the Partnership and
net income or loss reported herein primarily results from the exclusion of
depletion (as described below) from ordinary income reported in the
Partnership's federal return of income.
For federal income tax purposes, depletion with respect to production
of oil and gas is computed separately by the partners and not by the
Partnership. Since the amount of depletion on the production of oil and gas is
not computed at the Partnership level, depletion is not included in the
Partnership's income for federal income tax purposes but is charged directly to
the partners' capital accounts to the extent of the cost of the leasehold
interests, and thus is treated as a separate item on the partners' Schedule K-1.
Depletion for federal income tax purposes may vary from that computed for
financial reporting purposes in cases where a ceiling adjustment is recorded, as
such amount is not recognized for tax purposes.
(6) Gas Imbalances -
The Partnership recognizes its ownership interest in natural gas
production as revenue. Actual production quantities sold may be different than
the Partnership's ownership share in a given period. If the Partnership's sales
exceed its ownership share of production, the differences are recorded as
deferred revenue. Gas balancing receivables are recorded when the Partnership's
ownership share of production exceeds sales.
IV-9
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
NOTES TO FINANCIAL STATEMENTS (CONTINUED)
(7) Vulnerability Due to Certain Concentrations -
The Partnership's revenues are primarily the result of sales of its oil
and natural gas production. Market prices of oil and natural gas may fluctuate
and adversely affect operating results.
In the normal course of business, the Partnership extends credit,
primarily in the form of monthly oil and gas sales receivables, to various
companies in the oil and gas industry which results in a concentration of credit
risk. This concentration of credit risk may be affected by changes in economic
or other conditions and may accordingly impact the Partnership's overall credit
risk. However, the Managing General Partner believes that the risk is mitigated
by the size, reputation, and nature of the companies to which the Partnership
extends credit. In addition, the Partnership generally does not require
collateral or other security to support customer receivables.
(8) Fair Value of Financial Instruments -
The Partnership's financial instruments consist of cash and cash
equivalents and short-term receivables and payables. The carrying amounts
approximate fair value due to the highly liquid nature of the short-term
instruments.
IV-10
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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.
SWIFT ENERGY INCOME
PARTNERS 1989-B, LTD.
(Registrant)
By: SWIFT ENERGY COMPANY
General Partner
Date: March 10, 2000 By: s/b A. Earl Swift
---------------- -------------------------------
A. Earl Swift
Chief Executive Officer
Date: March 10, 2000 By: s/b John R. Alden
---------------- -------------------------------
John R. Alden
Principal Financial Officer
Date: March 10, 2000 By: s/b Alton D. Heckaman, Jr.
---------------- -------------------------------
Alton D. Heckaman, Jr.
Principal Accounting Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following persons on behalf of the Registrant and
in the capacities and on the dates indicated.
SWIFT ENERGY INCOME
PARTNERS 1989-B, LTD.
(Registrant)
By: SWIFT ENERGY COMPANY
General Partner
Date: March 10, 2000 By: s/b A. Earl Swift
---------------- -------------------------------
A. Earl Swift
Director and Principal
Executive Officer
Date: March 10, 2000 By: s/b Virgil N. Swift
---------------- -------------------------------
Virgil N. Swift
Director and Executive
Vice President - Business
Development
V-1
<PAGE>
SWIFT ENERGY INCOME PARTNERS 1989-B, LTD.
SIGNATURES
Date: March 10, 2000 By: s/b G. Robert Evans
---------------- -------------------------------
G. Robert Evans
Director
Date: March 10, 2000 By: s/b Raymond O. Loen
---------------- -------------------------------
Raymond O. Loen
Director
Date: March 10, 2000 By: s/b Henry C. Montgomery
---------------- -------------------------------
Henry C. Montgomery
Director
Date: March 10, 2000 By: s/b Clyde W. Smith, Jr.
---------------- -------------------------------
Clyde W. Smith, Jr.
Director
Date: March 10, 2000 By: s/b Harold J. Withrow
---------------- -------------------------------
Harold J. Withrow
Director
V-2
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
This schedule contains summary financial information extracted from Swift
Energy Income Partners 1989-B, Ltd's balance sheet and statement of operations
contained in its Form 10-K for the year ended December 31, 1999 and is
qualified in its entirety by reference to such financial statements.
</LEGEND>
<S> <C>
<PERIOD-TYPE> Year
<FISCAL-YEAR-END> Dec-31-1999
<PERIOD-END> Dec-31-1999
<CASH> 368,082
<SECURITIES> 0
<RECEIVABLES> 184,848
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 552,930
<PP&E> 8,252,610
<DEPRECIATION> (6,986,792)
<TOTAL-ASSETS> 1,850,190
<CURRENT-LIABILITIES> 45,582
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 1,781,369
<TOTAL-LIABILITY-AND-EQUITY> 1,850,190
<SALES> 886,798
<TOTAL-REVENUES> 898,995
<CGS> 0
<TOTAL-COSTS> 556,298<F1>
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 164,300
<INCOME-TAX> 0
<INCOME-CONTINUING> 164,300
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 164,300
<EPS-BASIC> 0
<EPS-DILUTED> 0
<FN>
<F1>Includes lease operating expenses, production taxes and depreciation and
amortization expense. Excludes general and administrative and interest expense.
</FN>
</TABLE>
