<PAGE> 1
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 0-13546
APACHE OFFSHORE INVESTMENT PARTNERSHIP
A Delaware IRS Employer
General Partnership No. 41-1464066
One Post Oak Central
2000 Post Oak Boulevard, Suite 100
Houston, Texas 77056-4400
Telephone Number (713) 296-6000
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT: NONE
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
PARTNERSHIP UNITS
Indicate by check mark whether the Partnership (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
Partnership was required to file such reports), 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 Partnership'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
-----
DOCUMENTS INCORPORATED BY REFERENCE:
Portions of Apache Corporation's proxy statement relating to its 2000
annual meeting of shareholders have been incorporated by reference into Part III
hereof.
<PAGE> 2
TABLE OF CONTENTS
DESCRIPTION
<TABLE>
<CAPTION>
ITEM PAGE
- ---- ----
PART I
<S> <C> <C> <C>
1. BUSINESS...................................................................................... 1
2. PROPERTIES.................................................................................... 4
3. LEGAL PROCEEDINGS............................................................................. 4
4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS........................................... 4
PART II
5. MARKET FOR THE PARTNERSHIP'S SECURITIES AND RELATED
SECURITY HOLDER MATTERS.................................................................. 5
6. SELECTED FINANCIAL DATA....................................................................... 5
7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS...................................................... 6
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA................................................... 10
9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE...................................................... 24
PART III
10. DIRECTORS AND EXECUTIVE OFFICERS OF THE PARTNERSHIP........................................... 24
11. EXECUTIVE COMPENSATION........................................................................ 24
12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
AND MANAGEMENT........................................................................... 24
13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS................................................ 24
PART IV
14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K............................... 25
</TABLE>
All defined terms under Rule 4-10(a) of Regulation S-X shall have their
statutorily-prescribed meanings when used in this report. Quantities of natural
gas are expressed in this report in terms of thousand cubic feet (Mcf), million
cubic feet (MMcf) or billion cubic feet (Bcf). Oil is quantified in terms of
barrels (bbls), thousands of barrels (Mbbls) and millions of barrels (MMbbls).
Natural gas is compared to oil in terms of barrels of oil equivalent (boe) or
million barrels of oil equivalent (MMboe). Oil and natural gas liquids are
compared with natural gas in terms of million cubic feet equivalent (MMcfe) and
billion cubic feet equivalent (Bcfe). One barrel of oil is the energy equivalent
of six Mcf of natural gas. Daily oil and gas production is expressed in terms of
barrels of oil per day (bopd) and thousands of cubic feet of gas per day (Mcfd),
respectively. With respect to information relating to the Partnership's working
interest in wells or acreage, "net" oil and gas wells or acreage is determined
by multiplying gross wells or acreage by the Partnership's working interest
therein. Unless otherwise specified, all references to wells and acres are
gross.
<PAGE> 3
PART I
ITEM 1. BUSINESS
GENERAL
Apache Offshore Investment Partnership (the Investment Partnership), a
Delaware general partnership, was organized in October 1983, with public
investors as Investing Partners and Apache Corporation (Apache), a Delaware
corporation, as Managing Partner. The operations of the Investment Partnership
are conducted by Apache Offshore Petroleum Limited Partnership (the Limited
Partnership), a Delaware limited partnership, of which Apache is the sole
general partner and the Investment Partnership is the sole limited partner.
The Investing Partners purchased Units of Partnership Interests (Units) in
the Investment Partnership at $150,000 per Unit, with five percent down and the
balance in payments as called by the Investment Partnership. As of December 31,
1999, a total of $85,000 had been called for each Unit. In 1989, the Investment
Partnership determined that the full $150,000 per Unit was not needed, fixed the
total calls at $85,000 per Unit, and released the Investing Partners from
liability for future calls. The Investment Partnership invested, and will
continue to invest, its entire capital in the Limited Partnership. As used
hereafter, the term "Partnership" refers to either the Investment Partnership or
the Limited Partnership, as the case may be.
The Partnership's business is participation in oil and gas exploration,
development and production activities on federal lease tracts in the Gulf of
Mexico, offshore Louisiana and Texas. Except for the Matagorda Island Block 681
and 682 interests, as described below, the Partnership acquired its oil and gas
interests through the purchase of 85 percent of the working interests held by
Apache as a participant in a venture (the Venture) with Shell Oil Company
(Shell) and certain other companies. The Partnership owns working interests
ranging from 6.29 percent to 9.44 percent in the Venture's properties.
The Venture acquired substantially all of its oil and gas properties
through bidding for leases offered by the federal government. The Venture
members relied on Shell's knowledge and expertise in determining bidding
strategies for the acquisitions. When Shell was successful in obtaining the
properties, it generally billed participating members on a promoted basis
(one-third for one-quarter) for the acquisition of exploratory leases and on a
straight-up basis for the acquisition of leases defined as drainage tracts. All
such billings were proportionately reduced to each member's working interest.
In November 1992, Apache and the Partnership formed a joint venture to
acquire Shell's 92.6 percent working interest in Matagorda Island Blocks 681 and
682 pursuant to a jointly-held contractual preferential right to purchase.
Apache and the Partnership previously owned working interests in the blocks
equal to 1.109 percent and 6.287 percent, respectively, and net revenue
interests of .924 percent and 5.239 percent, respectively. To facilitate the
acquisition, Apache and the Partnership contributed all of their interests in
Matagorda Island Blocks 681 and 682 to a newly formed joint venture, and Apache
contributed $64.6 million ($55.6 million net of purchase price adjustments) to
the joint venture to finance the acquisition. The Partnership had neither the
cash nor additional financing to fund its proportionate share of the acquisition
and participated through an increased net revenue interest in the joint venture.
Under the terms of the joint venture agreement, the Partnership's effective
net revenue interest in the Matagorda Island Block 681 and 682 properties
increased to 13.284 percent as a result of the acquisition, while its working
interest was unchanged. The acquisition added approximately 7.5 Bcf of natural
gas and 16 Mbbls of oil to the Partnership's reserve base without any
incremental expenditures by the Partnership.
Since the Venture is not expected to acquire any additional exploratory
acreage, future acquisitions, if any, will be confined to those leases defined
as drainage tracts. The current Venture members would pay their proportionate
share of acquiring any drainage tracts on a non-promoted basis.
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Offshore exploration differs from onshore exploration in that production
from a prospect generally will not commence until a sufficient number of
productive wells have been drilled to justify the significant costs associated
with construction of a production platform. Exploratory wells usually are
drilled from mobile platforms until there are sufficient indications of
commercial production to justify construction of a permanent production
platform.
Apache, as Managing Partner, manages the Partnership's operations. Apache
uses a portion of its staff and facilities for this purpose and is reimbursed
for actual costs paid on behalf of the Partnership, as well as for general,
administrative and overhead costs properly allocable to the Partnership.
1999 BUSINESS DEVELOPMENT
The Partnership spud two new wells in 1999, a sidetrack well at East
Cameron Block 60 which was completed and began production in 1999, and a
developmental well at South Timbalier Block 295. The South Timbalier well was
spud in December 1999 and is expected to be completed in early 2000. A
developmental well spud in late 1998 at North Padre Island Block 976 was
completed and began production in 1999. An exploratory well at North Padre
Island that was being evaluated at December 31, 1998, was plugged and abandoned
in 1999. The Partnership continued to participate in recompletion projects,
primarily at South Timbalier Block 295, to maintain production and enhance
recoverable reserves.
Since inception, the Partnership has acquired an interest in 49 prospects.
As of December 31, 1999, 42 of those prospects have been surrendered or sold.
The status of the Partnership's 49 original prospects is shown in the
following table:
<TABLE>
<CAPTION>
AS OF DECEMBER 31,
------------------
1999 1998
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<S> <C> <C>
Prospect Status
Producing - fully developed 6 6
Producing - partially developed 1 1
----- -----
Total discoveries 7 7
Surrendered/sold 42 42
----- -----
Total 49 49
===== =====
</TABLE>
As of December 31, 1999, 117 wells have been drilled on the seven remaining
prospects. Of the 117 wells, 91 were productive and of those, 62 are currently
producing. Fifteen of the Partnership's producing wells are dual completions.
The Partnership had, at December 31, 1999, estimated proved oil and gas reserves
of 13.1 Bcfe, of which 69 percent was natural gas.
In June 1999, the Partnership sold its interest in Matagorda Island Block
705 (Roberto Prospect) and the southwest quadrant of North Padre Island Block
976 (Rosita Prospect) through two separate sales transactions. The Partnership
retained other existing interests in both prospects.
FULL COST CEILING TEST
Under the full cost accounting rules of the Securities and Exchange
Commission (SEC), the Partnership reviews the carrying value of its oil and gas
properties each quarter. Under these rules, capitalized costs of proved oil and
gas properties, net of accumulated depreciation, depletion and amortization, may
not exceed the present value of estimated future net cash flows from proved oil
and gas reserves, discounted at 10 percent, plus the lower of cost or fair
market value of unproved properties included in the costs being amortized, if
any. Application of these rules generally requires pricing future production at
the unescalated oil and gas prices in effect at the end of each fiscal quarter
and requires a write-down if the "ceiling" is exceeded, even if prices declined
for only a short period of time. The Partnership had no write-downs during 1999,
1998 or 1997 due to ceiling test limitations.
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MARKETING
Apache, on behalf of the Partnership, seeks and negotiates oil and gas
marketing arrangements with various marketers and purchasers. During 1999, the
Partnership's spot market gas was purchased primarily by Producers Energy
Marketing LLC (ProEnergy) and the Partnership's oil and condensate production
was purchased primarily by Plains Petroleum Operating Co. (Plains Petroleum). In
June 1998, Apache formed a strategic alliance with Cinergy Corp. (Cinergy) to
market substantially all of Apache's natural gas production from North America
and sold its 57 percent interest in ProEnergy to Cinergy. ProEnergy, renamed
Cinergy Marketing & Trading, LLC in June 1999, will continue to market Apache's
North American natural gas production for 10 years, with an option to terminate
after six years, under an amended and restated gas purchase agreement effective
July 1, 1998. The prices the Partnership received for its gas production prior
to the sale of ProEnergy were, in the opinion of Apache, comparable to the
prices that would have been received from a non-affiliated party. The prices the
Partnership received after the sale of ProEnergy and will continue to receive
for its gas production, in the opinion of Apache, approximate market prices.
See Note (5) "Major Customer Information" to the Partnership's financial
statements under Item 8. Because the Partnership's oil and gas products are
commodities and the prices and terms of its sales reflect those of the market,
the Partnership does not believe that the loss of any customer would have a
material adverse affect on the Partnership's business or results of operations.
The Partnership is not in a position to predict future oil and gas prices.
ENVIRONMENTAL
The Partnership, as an owner or lessee of interests in oil and gas
properties, is subject to various federal, state and local laws and regulations
relating to the discharge of materials into, and protection of, the environment.
These laws and regulations may, among other things, impose liability on the
lessee under an oil and gas lease for the cost of pollution clean-up resulting
from operations, subject the lessee to liability for pollution damages and
require suspension or cessation of operations in affected areas.
The Partnership has made and will continue to make expenditures in its
efforts to comply with these requirements. These costs are inextricably
connected to normal operating expenses such that the Partnership is unable to
separate the expenses related to environmental matters; however, the Partnership
does not believe such expenditures are material to its financial position or
results of operations.
The Partnership does not believe that compliance with federal, state or
local provisions regulating the discharge of materials into the environment, or
otherwise relating to the protection of the environment, will have a material
adverse effect upon the capital expenditures, earnings and the competitive
position of the Partnership, but there is no assurance that changes in or
additions to laws or regulations regarding the protection of the environment
will not have such an impact.
COMPETITION
The Partnership is a very minor factor in the oil and gas industry in the
Gulf of Mexico area and faces strong competition from much larger producers for
the marketing of its oil and gas. The Partnership's ability to compete for
purchasers and favorable marketing terms will depend on the general demand for
oil and gas from Gulf of Mexico producers. More particularly, it will depend
largely on the efforts of Apache to find the best markets.
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ITEM 2. PROPERTIES
Acreage is held by the Partnership pursuant to the terms of various leases.
The Partnership does not anticipate any difficulty in retaining any of its
desirable leases. A summary of the Partnership's producing wells and gross
acreage as of December 31, 1999, is set forth below:
<TABLE>
<CAPTION>
PRODUCING
OIL/GAS WELLS AVERAGE GROSS ACRES
------------------ WORKING -------------------------
LEASE BLOCK PROSPECT STATE GROSS NET INTEREST DEVELOPED UNDEVELOPED
- ------------------------------ -------- ----- ----- ---- -------- --------- -----------
<S> <C> <C> <C> <C> <C> <C> <C>
Ship Shoal 258, 259 Genesis LA 7 .4 .0628698 10,141 --
South Timbalier 276, 295, 296 Grover LA 20 1.4 .0708333 15,000 --
North Padre Island 969, 975,
976 Rosita TX 10 .7 .0708333 10,080 5,760
Matagorda Island 681, 682 Roberto TX 18 1.1 .0628698 10,080 --
South Pass 83 Manx LA 4 .3 .0678914 5,000 --
East Cameron 60 East Aragonite LA 1 .1 .0944444 5,000 --
Ship Shoal 201, 202 Bromeliad LA 2 -- ORRI 10,000 --
---- ---- --------- ---------
62 4.0 65,301 5,760
===== ==== ========== =========
</TABLE>
In June 1999, the Partnership sold its interest in Matagorda Island Block
705 and the southwest quadrant of North Padre Island Block 976. See Note (4)
"Oil and Gas Properties" to the Partnership's financial statements for costs
incurred in oil and gas development and production activities. See Supplemental
Oil and Gas Disclosures under Item 8 for related reserve information. On a net
basis, the Partnership owns four wells.
PRODUCTION AND PRICING DATA
The following table describes, for each of the last three fiscal years, oil
and gas production for the Partnership, average production costs (excluding
severance taxes) and average sales prices.
<TABLE>
<CAPTION>
PRODUCTION AVERAGE SALES PRICES
-------------------------- AVERAGE ---------------------------
YEAR ENDED OIL GAS PRODUCTION OIL GAS
DECEMBER 31, (MBBLS) (MMCF) COST PER MCFE (PER BBL) (PER MCF)
-------------- ---------- ----------- ---------------- ----------- -----------
<S> <C> <C> <C> <C> <C>
1999 122 2,938 $ .18 $ 18.10 $ 2.15
1998 106 3,127 .27 12.40 2.08
1997 125 3,878 .10 19.30 2.49
</TABLE>
See the Supplemental Oil and Gas Disclosures under Item 8 for estimated oil
and gas reserves quantities.
ITEM 3. LEGAL PROCEEDINGS
There are no material legal proceedings pending to which the Partnership is
a party or to which the Partnership's interests are subject.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no matters submitted to a vote of security holders during the
fourth quarter of 1999.
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PART II
ITEM 5. MARKET FOR THE PARTNERSHIP'S SECURITIES AND RELATED SECURITY HOLDER
MATTERS
As of December 31, 1999, there were 1,132.5 of the Partnership's Units
outstanding held by approximately 924 investors of record. The Partnership has
no other class of security outstanding or authorized. The Units are not traded
on any security market. Cash distributions to Investing Partners totaled
approximately $4 million, or $3,500 per Unit, during 1999 and approximately $1.7
million, or $1,500 per Unit, during 1998.
As discussed in Item 7, an amendment to the Partnership Agreement in
February 1994 created a right of presentment under which all Investing Partners
have a limited and voluntary right to offer their Units to the Partnership twice
each year to be purchased in cash.
ITEM 6. SELECTED FINANCIAL DATA
The following selected financial data for the five years ended December 31,
1999, should be read in conjunction with the Partnership's financial statements
and related notes included under Item 8.
<TABLE>
<CAPTION>
AS OF OR FOR THE YEAR ENDED DECEMBER 31,
----------------------------------------------------------------------------
1999 1998 1997 1996 1995
------------ ------------ ------------ ------------- -------------
(In thousands, except per Unit amounts)
<S> <C> <C> <C> <C> <C>
Total assets $ 8,722 $ 9,841 $ 10,524 $ 12,252 $ 13,486
============ ============ ============ ============= =============
Long-term debt $ - $ - $ - $ 1,998 $ 7,310
============ ============ ============ ============= =============
Partners' capital $ 7,755 $ 9,080 $ 8,647 $ 8,498 $ 5,472
============ ============ ============ ============= =============
Oil and gas sales $ 8,521 $ 7,827 $ 12,067 $ 17,511 $ 13,138
============ ============ ============ ============= =============
Net income $ 4,351 $ 3,621 $ 8,244 $ 11,127 $ 6,214
============ ============ ============ ============= =============
Net income allocated to:
Managing Partner $ 1,269 $ 1,061 $ 1,967 $ 2,652 $ 1,800
Investing Partners 3,082 2,560 6,277 8,475 4,414
------------ ------------ ------------ ------------- -------------
$ 4,351 $ 3,621 $ 8,244 $ 11,127 $ 6,214
============ ============ ============ ============= =============
Net income per Investing
Partner Unit $ 2,707 $ 2,193 $ 5,260 $ 7,032 $ 3,584
============ ============ ============ ============= =============
Cash distributions per
Investing Partner Unit $ 3,500 $ 1,500 $ 4,500 $ 4,500 $ 2,250
============ ============ ============ ============= =============
</TABLE>
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
The Partnership's net income and net income per Investing Partner Unit
increased in 1999 due to higher oil and gas prices and reduced operating costs.
The average crude oil price increased 46 percent from the average price in 1998,
while the average natural gas price increased three percent from last year.
Lease operating expense (LOE) was down from 1998 due to reduced workover costs.
Distributions per Investing Partner Unit in 1999 increased with improved product
prices.
RESULTS OF OPERATIONS
NET INCOME AND REVENUE
The Partnership reported net income of $4.4 million for 1999 versus $3.6
million in 1998. Net income per Investing Partner Unit increased 23 percent, to
$2,707 from $2,193. The impact of lower gas production on net income in 1999 was
more than offset by higher product prices and reduced LOE.
Revenues increased nine percent, from $7.9 million in 1998, to $8.6 million
in 1999. Natural gas and crude oil sales contributed approximately 73 percent
and 26 percent, respectively, to the Partnership's total revenue in 1999. The
Partnership is not in a position to predict future oil and gas prices.
The Partnership's oil and gas production volume and price information is
summarized in the following table:
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
----------------------------------- INCREASE
1999 1998 (DECREASE)
------- ------ ----------
<S> <C> <C> <C>
Gas volumes - Mcf per day 8,049 8,567 (6%)
Average gas price - per Mcf $ 2.15 $2.08 3%
Oil volume - barrels per day 335 291 15%
Average oil price - per barrel $ 18.10 $12.40 46%
</TABLE>
Declines in oil and gas production can be expected in future years due to
normal depletion. It is not anticipated that the Partnership will acquire any
additional exploratory leases or that significant exploratory drilling will take
place on leases in which the Partnership currently holds interests.
1999 COMPARED TO 1998
Natural gas sales for 1999 totaled $6.3 million, down slightly from 1998,
as lower gas production more than offset the impact of higher realized gas
prices. The decrease in production volumes resulted primarily from normal
declines at Matagorda Island Block 681 and the sale of the Partnership's
interest in Matagorda Island Block 705 during 1999.
The Partnership's crude oil sales for 1999 totaled $2.2 million, a 68
percent increase from 1998. The average realized price for 1999 increased $5.70
per barrel, or 46 percent, when compared to 1998. In addition to the increase in
crude oil prices, the Partnership recognized a 15 percent increase in production
versus 1998. The increase in oil production resulted primarily from a new
completion at East Cameron Block 60 and recompletion operations at South
Timbalier Block 295.
Given the small number of producing wells owned by the Partnership, and the
fact that offshore wells tend to decline at a faster rate than onshore wells,
the Partnership's future production will be subject to more volatility than
those entities with greater reserves and longer-lived properties.
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OPERATING EXPENSES
The Partnership's depreciation, depletion and amortization (DD&A) rate,
expressed as a percentage of oil and gas sales, was approximately 36 percent
during 1999, up slightly from 1998. The increase in the DD&A rate was a result
of lower natural gas and crude oil prices during the first quarter of 1999 and
unfavorable reserve revisions recognized in late 1998. Overall, 1999 DD&A
expense of $3 million increased by $.3 million when compared to 1998.
LOE of $.7 million declined by $.3 million during 1999 when compared to
1998 due to lower workover activity in 1999.
1998 COMPARED TO 1997
Natural gas sales for 1998 totaled $6.5 million, 33 percent lower than in
1997. The decrease was driven by lower average prices and lower production
volumes. The decrease in production volumes resulted primarily from normal
declines at Matagorda Island Block 681 and North Padre Island Block 969 and the
sale of West Cameron Block 368.
The Partnership's crude oil sales for 1998 totaled $1.3 million, a 45
percent decrease from 1997. The average realized price for 1998 decreased 36
percent when compared to 1997. In addition to the decrease in crude oil prices
was a 15 percent decline in production versus 1997. The decrease in oil
production resulted primarily from normal decline at East Cameron Block 60 and
downtime for drilling operations at Ship Shoal Block 259.
OPERATING EXPENSES
The Partnership's DD&A rate, expressed as a percentage of oil and gas
sales, was approximately 35 percent during 1998, up from 25 percent for 1997.
The increase in the DD&A rate was a result of decreased natural gas and crude
oil prices. Overall, 1998 DD&A expense of $2.7 million decreased by $.3 million
when compared to 1997 due to lower production in the current period.
LOE of $1.0 million increased by $.6 million during 1998 when compared to
1997. The increase in LOE was the result of higher workover activity in 1998 and
non-recurring credits received from joint venture audits in 1997.
CASH FLOW, LIQUIDITY AND CAPITAL RESOURCES
CAPITAL COMMITMENTS
The Partnership's primary needs for cash are for operating expenses,
drilling and recompletion expenditures, distributions to Investing Partners, and
the purchase of Units offered by Investing Partners under the right of
presentment. The Partnership had no outstanding debt at December 31, 1999.
During 1999, the Partnership's oil and gas property additions totaled $1.4
million. The 1999 additions included a sidetrack well at East Cameron Block 60
and a developmental well at South Timbalier Block 295. A developmental well spud
in late 1998 at North Padre Island Block 976 was completed and began production
in 1999. An exploratory well at North Padre Island that was being evaluated at
December 31, 1998, was plugged and abandoned in 1999. Also in 1999, the
Partnership participated in recompletion projects at South Timbalier Block 295.
Additions to oil and gas properties totaled $2.3 million and $4 million in 1998
and 1997, respectively.
The Partnership anticipates capital expenditures will total approximately
$1.8 million in 2000, based on preliminary information provided by the operators
of the properties in which the Partnership owns interests. The anticipated
capital expenditures relate primarily to drilling and recompletion activity at
South Timbalier Block 295. Additional capital expenditures may be proposed by
the operators in the future.
During 1999, the Partnership paid distributions to Investing Partners
totaling approximately $4 million or $3,500 per Unit, which was 133 percent
higher than the per Unit distribution in 1998. Apache, as the Managing Partner,
will review the possibility of distributions in 2000 given current revenues and
available cash balances. Future distributions will be dependent on actual and
expected production levels, realized and expected oil and gas prices and actual
and anticipated capital expenditures.
7
<PAGE> 10
In February 1994, an amendment to the Partnership Agreement created a right
of presentment under which all Investing Partners have a limited and voluntary
right to offer their Units to the Partnership twice each year to be purchased
for cash. In 1999, the first right of presentment offer of $8,410 per Unit, plus
interest to the date of payment, was made to Investing Partners based on a
December 31, 1998 valuation date. The second right of presentment offer of
$6,769 per Unit, plus interest to the date of payment, was made to the Investing
Partners based on a valuation date of June 30, 1999. As a result, the
Partnership acquired 8.49 Units for a total of approximately $69,000 in cash. In
1998 and 1997, Investing Partners were paid approximately $487,000 and $180,000,
respectively, for a total of 56.89 Units.
There will be two rights of presentment in 2000, but the Partnership is not
in a position to predict how many Units will be presented for repurchase and
cannot, at this time, determine if the Partnership will have sufficient funds
available to repurchase Units. The Amended Partnership Agreement contains
limitations on the number of Units that the Partnership can repurchase,
including an annual limit on repurchases of 10 percent of outstanding Units. The
Partnership has no obligation to repurchase any Units presented to the extent
that it determines that it has insufficient funds for such repurchases.
CAPITAL RESOURCES AND LIQUIDITY
The Partnership's primary capital resource is net cash provided by
operating activities, which totaled $8.3 million for 1999. After dropping 40
percent from 1997 to 1998, net cash provided by operating activities increased
$1.4 million, or 20 percent, in 1999 due to improved oil and gas prices and
lower LOE. Future operating cash flows will be influenced by oil and gas prices
and production which cannot be predicted.
The Partnership's future financial condition and results of operations will
largely depend upon prices received for its oil and natural gas production and
the costs of acquiring, finding, developing and producing reserves. A
substantial portion of the Partnership's production is sold under
market-sensitive contracts. Prices for oil and natural gas are subject to
fluctuations in response to changes in supply, market uncertainty and a variety
of factors beyond the Partnership's control. These factors include worldwide
political instability (especially in the Middle East), the foreign supply of oil
and natural gas, the price of foreign imports, the level of consumer demand and
the price and availability of alternative fuels. With natural gas accounting for
80 percent of the Partnership's 1999 production and 69 percent of total proved
reserves, on an energy equivalent basis, the Partnership is affected more by
fluctuations in natural gas prices than in oil prices.
It is expected that the net cash provided by operating activities will be
sufficient to meet the Partnership's liquidity needs for routine operations over
the next two years. However, in the event that future short-term operating cash
requirements are greater than the Partnership's financial resources, the
Partnership will seek short-term, interest-bearing advances from the Managing
Partner as needed.
In accordance with the Partnership's continuing objectives to maximize unit
holder value and cash distributions, the Managing Partner plans to re-evaluate
the future of the Partnership following this year's capital investments.
IMPACT OF THE YEAR 2000 ISSUE
The inability of some computer programs and embedded computer chips to
distinguish between the year 1900 and the year 2000 (the Year 2000 issue) posed
a serious threat of business disruption to any organization that utilizes
computer technology and computer chip technology in their business systems or
equipment. To address this issue, Apache formed a Year 2000 Task Force with
representation from major business units to inventory and assess the risk of
hardware, software, telecommunications systems, office equipment, embedded chip
controls and systems, process control systems, facility control systems and
dependencies on external trading partners. The project was completed prior to
December 31, 1999, and to date, Apache has not experienced any Year 2000 related
computer failures or problems.
The costs to achieve Year 2000 compliance were borne by Apache and did not
have any impact on the financial results of the Partnership.
FORWARD-LOOKING STATEMENTS AND RISK
Certain statements in this report, including statements of the future
plans, objectives, and expected performance of the Partnership, are
forward-looking statements that are dependent upon certain events, risks and
uncertainties that may be outside the Partnership's control, and which could
cause actual results to differ materially from those anticipated.
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<PAGE> 11
Some of these include, but are not limited to, the market prices of oil and gas,
economic and competitive conditions, inflation rates, legislative and regulatory
changes, financial market conditions, political and economic uncertainties of
foreign governments, future business decisions, and other uncertainties, all of
which are difficult to predict.
There are numerous uncertainties inherent in estimating quantities of
proved oil and gas reserves and in projecting future rates of production and the
timing of development expenditures. The total amount or timing of actual future
production may vary significantly from reserves and production estimates. The
drilling of exploratory wells can involve significant risks, including those
related to timing, success rates and cost overruns. Lease and rig availability,
complex geology and other factors can affect these risks. Fluctuations in oil
and gas prices, or a prolonged continuation of the current low price of crude
oil, may substantially adversely affect the Partnership's financial position,
results of operations and cash flows.
9
<PAGE> 12
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
APACHE OFFSHORE INVESTMENT PARTNERSHIP
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE
NUMBER
------
<S> <C>
Report of Independent Public Accountants.......................................................... 11
Balance Sheet as of December 31, 1999 and 1998.................................................... 12
Statement of Income for each of the three years in the period ended December 31, 1999............. 13
Statement of Cash Flows for each of the three years in the period ended December 31, 1999 ........ 14
Statement of Changes in Partners' Capital for each of the three years in the period ended
December 31, 1999............................................................................. 15
Notes to Financial Statements..................................................................... 16
Supplemental Oil and Gas Disclosures.............................................................. 22
</TABLE>
Schedules -
All financial statement schedules have been omitted because they are either
not required, not applicable or the information required to be presented is
included in the financial statements or related notes thereto.
10
<PAGE> 13
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Partners of Apache Offshore Investment Partnership:
We have audited the accompanying balance sheet of Apache Offshore
Investment Partnership (a Delaware partnership) as of December 31, 1999 and
1998, and the related statements of income, cash flows and changes in partners'
capital for each of the three years in the period ended December 31, 1999. These
financial statements are the responsibility of the Partnership'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 Apache Offshore Investment
Partnership as of December 31, 1999 and 1998, and the results of its operations
and its cash flows for each of the three years in the period ended December 31,
1999, in conformity with accounting principles generally accepted in the United
States.
/s/ ARTHUR ANDERSEN LLP
ARTHUR ANDERSEN LLP
Houston, Texas
March 1, 2000
11
<PAGE> 14
APACHE OFFSHORE INVESTMENT PARTNERSHIP
BALANCE SHEET
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------------------
1999 1998
-------------- --------------
ASSETS
<S> <C> <C>
CURRENT ASSETS:
Cash and cash equivalents $ 2,748,812 $ 1,324,949
Accrued revenues receivable 635,826 1,297,999
-------------- --------------
3,384,638 2,622,948
-------------- --------------
OIL AND GAS PROPERTIES, on the basis of full cost accounting:
Proved properties 169,496,346 168,331,700
Less - Accumulated depreciation, depletion and amortization (164,158,568) (161,114,094)
-------------- --------------
5,337,778 7,217,606
-------------- --------------
$ 8,722,416 $ 9,840,554
============== ==============
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accrued exploration and development $ 596,851 $ 591,920
Accrued operating expenses payable 172,071 98,367
Payable to Apache Corporation 198,631 69,973
-------------- --------------
967,553 760,260
-------------- --------------
PARTNERS' CAPITAL:
Managing Partner 238,079 597,060
Investing Partners (1,132.5 and 1,141.0 Units
outstanding, respectively) 7,516,784 8,483,234
-------------- --------------
7,754,863 9,080,294
-------------- --------------
$ 8,722,416 $ 9,840,554
============== ==============
</TABLE>
The accompanying notes to financial statements are
an integral part of this statement.
12
<PAGE> 15
APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF INCOME
<TABLE>
<CAPTION>
FOR THE YEAR ENDED DECEMBER 31,
---------------------------------------------------
1999 1998 1997
--------------- --------------- --------------
<S> <C> <C> <C>
REVENUES:
Oil and gas sales $ 8,521,418 $ 7,827,380 $ 12,066,643
Interest income 92,084 55,691 69,755
Other income - - 89,249
--------------- --------------- --------------
8,613,502 7,883,071 12,225,647
--------------- --------------- --------------
OPERATING EXPENSES:
Depreciation, depletion and amortization 3,044,474 2,721,180 2,983,020
Lease operating 673,216 1,000,708 445,651
Administrative 544,760 540,000 540,000
Interest expense - - 12,818
--------------- --------------- --------------
4,262,450 4,261,888 3,981,489
--------------- --------------- --------------
NET INCOME $ 4,351,052 $ 3,621,183 $ 8,244,158
=============== =============== ==============
Net income allocated to:
Managing Partner $ 1,268,895 $ 1,061,052 $ 1,967,386
Investing Partners 3,082,157 2,560,131 6,276,772
--------------- --------------- --------------
$ 4,351,052 $ 3,621,183 $ 8,244,158
=============== =============== ==============
NET INCOME PER INVESTING PARTNER UNIT $ 2,707 $ 2,193 $ 5,260
=============== =============== ==============
WEIGHTED AVERAGE INVESTING PARTNER
UNITS OUTSTANDING 1,138.4 1,167.4 1,193.3
=============== =============== ==============
</TABLE>
The accompanying notes to financial statements are
an integral part of this statement.
13
<PAGE> 16
APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF CASH FLOWS
<TABLE>
<CAPTION>
FOR THE YEAR ENDED DECEMBER 31,
---------------------------------------------------
1999 1998 1997
-------------- -------------- --------------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $ 4,351,052 $ 3,621,183 $ 8,244,158
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion and amortization 3,044,474 2,721,180 2,983,020
Changes in operating assets and liabilities:
Decrease in accrued revenues receivable 662,173 239,452 1,508,734
Increase (decrease) in accrued operating
expenses payable 73,704 (13,896) (286,635)
Increase (decrease) in payable to/receivable from
Apache Corporation 128,658 288,702 (1,061,813)
-------------- -------------- --------------
Net cash provided by operating activities 8,260,061 6,856,621 11,387,464
-------------- -------------- --------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas properties (1,376,072) (2,331,287) (4,007,934)
Proceeds from sales of oil and gas properties 211,426 396,674 488,750
Non-cash portion of oil and gas property additions 4,931 (1,172,997) 1,250,969
(Increase) decrease in drilling advances - 72,020 (72,020)
-------------- -------------- --------------
Net cash used in investing activities (1,159,715) (3,035,590) (2,340,235)
-------------- -------------- --------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Repurchase of Partnership Units (69,386) (487,313) (179,523)
Distributions to Investing Partners (3,979,221) (1,731,539) (5,362,339)
Distributions to Managing Partner, net (1,627,876) (969,027) (2,553,540)
Payments of long-term debt - - (1,997,500)
-------------- -------------- --------------
Net cash used in financing activities (5,676,483) (3,187,879) (10,092,902)
-------------- -------------- --------------
NET INCREASE (DECREASE) IN CASH AND CASH
EQUIVALENTS 1,423,863 633,152 (1,045,673)
CASH AND CASH EQUIVALENTS, BEGINNING
OF YEAR 1,324,949 691,797 1,737,470
-------------- -------------- --------------
CASH AND CASH EQUIVALENTS, END OF YEAR $ 2,748,812 $ 1,324,949 $ 691,797
============== ============== ==============
SUPPLEMENTAL DISCLOSURES OF CASH FLOW
INFORMATION:
Cash paid during the year for interest $ - $ - $ 11,073
============== ============== ==============
</TABLE>
The accompanying notes to financial statements are
an integral part of this statement.
14
<PAGE> 17
APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF CHANGES IN PARTNERS' CAPITAL
<TABLE>
<CAPTION>
MANAGING INVESTING
PARTNER PARTNERS TOTAL
-------------- -------------- --------------
<S> <C> <C> <C>
BALANCE, DECEMBER 31, 1996 $ 1,091,189 $ 7,407,045 $ 8,498,234
Distributions, net (2,553,540) (5,362,339) (7,915,879)
Repurchase of Partnership Units - (179,523) (179,523)
Net income 1,967,386 6,276,772 8,244,158
-------------- -------------- --------------
BALANCE, DECEMBER 31, 1997 505,035 8,141,955 8,646,990
Distributions, net (969,027) (1,731,539) (2,700,566)
Repurchase of Partnership Units - (487,313) (487,313)
Net income 1,061,052 2,560,131 3,621,183
-------------- -------------- --------------
BALANCE, DECEMBER 31, 1998 597,060 8,483,234 9,080,294
Distributions, net (1,627,876) (3,979,221) (5,607,097)
Repurchase of Partnership Units - (69,386) (69,386)
Net income 1,268,895 3,082,157 4,351,052
-------------- -------------- --------------
BALANCE, DECEMBER 31, 1999 $ 238,079 $ 7,516,784 $ 7,754,863
============== ============== ==============
</TABLE>
The accompanying notes to financial statements are
an integral part of this statement.
15
<PAGE> 18
APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO FINANCIAL STATEMENTS
(1) ORGANIZATION
NATURE OF OPERATIONS -
Apache Offshore Investment Partnership was formed as a Delaware
general partnership on October 31, 1983, consisting of Apache Corporation
(Apache) as Managing Partner and public investors as Investing Partners.
The general partnership invested its entire capital in Apache Offshore
Petroleum Limited Partnership, a Delaware limited partnership formed to
conduct oil and gas exploration, development and production operations. The
accompanying financial statements include the accounts of both the limited
and general partnerships. Apache is the general partner of both the limited
and general partnerships, and holds approximately five percent of the
1,132.5 Investing Partner Units (Units) outstanding at December 31, 1999.
The term "Partnership", as used hereafter, refers to the limited or the
general partnership, as the case may be.
The Partnership purchased, at cost, an 85 percent interest in offshore
leasehold interests acquired by Apache as a co-venturer in a series of oil
and gas exploration, development and production activities on 87 federal
lease tracts (12 remain as of December 31, 1999) in the Gulf of Mexico,
offshore Louisiana and Texas. The remaining 15 percent interest was
purchased by an affiliated partnership or retained by Apache. The
Partnership acquired an increased net revenue interest in Matagorda Island
Blocks 681 and 682 in November 1992, when the Partnership and Apache formed
a joint venture to acquire a 92.6 percent working interest in the blocks.
Since inception, the Partnership has participated in 14 federal
offshore lease sales in which 49 prospects were acquired (through the same
date 42 of those prospects have been surrendered/sold). The Partnership's
working interests in the seven remaining venture prospects range from 6.29
percent to 9.44 percent.
The Partnership's future financial condition and results of operations
will depend largely upon prices received for its oil and natural gas
production and the costs of acquiring, finding, developing and producing
reserves. A substantial portion of the Partnership's production is sold
under market-sensitive contracts. Prices for oil and natural gas are
subject to fluctuations in response to changes in supply, market
uncertainty and a variety of factors beyond the Partnership's control.
These factors include worldwide political instability (especially in the
Middle East), the foreign supply of oil and natural gas, the price of
foreign imports, the level of consumer demand, and the price and
availability of alternative fuels. With natural gas accounting for 80
percent of the Partnership's 1999 production and 69 percent of total proved
reserves, on an energy equivalent basis, the Partnership is affected more
by fluctuations in natural gas prices than in oil prices.
Under the terms of the Partnership Agreements, the Investing Partners
receive 80 percent and Apache receives 20 percent of revenue. The Investing
Partners generally pay for 90 percent and Apache generally pays for 10
percent of exploration and development costs and expenses incurred by the
Partnership. However, intangible drilling costs, interest costs and fees or
expenses related to the loans incurred by the Partnership are allocated 99
percent to the Investing Partners and one percent to Apache until such time
as the amount so allocated to the Investing Partners equals 90 percent of
the total amount of such costs, including such costs incurred by Apache
prior to the formation of the Partnerships.
16
<PAGE> 19
APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO FINANCIAL STATEMENTS - (CONTINUED)
RIGHT OF PRESENTMENT -
An amendment to the Partnership Agreement adopted in February 1994,
created a right of presentment under which all Investing Partners have a
limited and voluntary right to offer their Units to the Partnership twice
each year to be purchased for cash. During 1999, the Investing Partners
sold a total of 8.49 Units to the Partnership for a total of approximately
$69,000 in cash. The first right of presentment was based upon a valuation
date of December 31, 1998 for a purchase price of $8,410 per Unit, plus
interest to the date of payment. The second presentment offer was based on
a valuation date of June 30, 1999 for a purchase price of $6,769 per Unit,
plus interest to the payment date. During 1998 and 1997, the Partnership
paid the Investing Partners approximately $487,000 and $180,000,
respectively, to acquire a total of 56.89 Units.
The Partnership is not in a position to predict how many Units will be
presented for repurchase during 2000, however, no more than 10 percent of
the outstanding Units may be purchased under the right of presentment in
any year. The Partnership has no obligation to purchase any Units presented
to the extent that it determines that it has insufficient funds for such
purchases.
The table below sets forth the total repurchase price and the
repurchase price per Unit for all outstanding Units at each presentment
period, based on the right of presentment valuation formula defined in the
amendment to the Partnership Agreement. The right of presentment offers,
made twice annually, are based on a discounted Unit value formula. The
discounted Unit value will be not less than the Investing Partner's share
of: (a) the sum of (i) 70 percent of the discounted estimated future net
revenues from proved reserves, discounted at a rate of 1.5 percent over
prime or First National Bank of Chicago's base rate in effect at the time
the calculation is made, (ii) cash on hand, (iii) prepaid expenses, (iv)
accounts receivable less a reasonable reserve for doubtful accounts, (v)
oil and gas properties other than proved reserves at cost less any amounts
attributable to drilling and completion costs incurred by the Partnership
and included therein, and (vi) the book value of all other assets of the
Partnership, less the debts, obligations and other liabilities of all kinds
(including accrued expenses) then allocable to such interest in the
Partnership, all determined as of the valuation date, divided by (b) the
number of Units, and fractions thereof, outstanding as of the valuation
date. The discounted Unit value does not purport to be, and may be
substantially different from, the fair market value of a Unit.
<TABLE>
<CAPTION>
RIGHT OF PRESENTMENT TOTAL REPURCHASE REPURCHASE PRICE
VALUATION DATE PRICE PER UNIT
-------------------- ----------------- ----------------
<S> <C> <C>
December 31, 1996 $ 17,514,216 $ 13,621
June 30, 1997 17,188,997 10,946
December 31, 1997 13,216,700 11,161
June 30, 1998 13,072,171 9,824
December 31, 1998 10,451,244 8,410
June 30, 1999 10,812,281 6,769
</TABLE>
CAPITAL CONTRIBUTIONS -
A total of $85,000 per Unit, or approximately 57 percent, of investor
subscription had been called through December 31, 1999. The Partnership
determined the full purchase price of $150,000 per Unit was not needed, and
upon completion of the last subscription call in November 1989, released
the Investing Partners from their remaining liability. As a result of
investors defaulting on cash calls and repurchases under the presentment
offer discussed above, the original 1,500 Units have been reduced to
1,132.5 Units at December 31, 1999.
17
<PAGE> 20
APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO FINANCIAL STATEMENTS - (CONTINUED)
(2) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
STATEMENT PRESENTATION -
The accounts of the Partnership are maintained on a tax basis method
of accounting in accordance with the Articles of Partnership and methods of
reporting allowed for federal income tax purposes.
Financial statements included in reports that the Partnership files
with the Securities and Exchange Commission (SEC) are required to be
prepared in conformity with generally accepted accounting principles.
Accordingly, the accompanying financial statements were prepared to reflect
memorandum entries to convert from tax basis to the accrual basis method in
conformity with accounting principles generally accepted in the United
States.
CASH EQUIVALENTS -
The Partnership considers all highly liquid debt instruments purchased
with an original maturity of three months or less to be cash equivalents.
These investments are carried at cost which approximates market.
OIL AND GAS PROPERTIES -
The Partnership uses the full cost method of accounting for financial
statement purposes. Under this method, the Partnership capitalizes all
acquisition, exploration and development costs incurred for the purpose of
finding oil and gas reserves. The amounts capitalized under this method
include dry hole costs, leasehold costs, engineering, geological,
exploration, development and other similar costs. Costs associated with
production and administrative functions are expensed in the period
incurred. Unless a significant portion of the Partnership's reserve volumes
are sold (greater than 25 percent), proceeds from the sale of oil and gas
properties are accounted for as reductions to capitalized costs, and gains
or losses are not recognized.
Capitalized costs of oil and gas properties are amortized on the
future gross revenue method whereby depreciation, depletion and
amortization (DD&A) expense is computed quarterly by dividing current
period oil and gas sales by estimated future gross revenue from proved oil
and gas reserves (including current period oil and gas sales) and applying
the resulting rate to the net cost of evaluated oil and gas properties,
including estimated future development costs. The amortizable base includes
estimated dismantlement, restoration and abandonment costs, net of
estimated salvage values.
The Partnership limits the capitalized costs of proved oil and gas
properties, net of accumulated DD&A, to the estimated future net cash flows
from proved oil and gas reserves discounted at 10 percent, plus the lower
of cost or fair value of unproved properties included in the costs being
amortized, if any. If capitalized costs exceed this limit, the excess is
charged to DD&A expense. The Partnership has not recorded any write-downs
of capitalized costs for the three years presented.
REVENUE RECOGNITION -
The Partnership uses the sales method of accounting for natural gas
revenues. Under this method, revenues are recognized based on actual
volumes of gas sold to purchasers. The volumes of gas sold may differ from
the volumes to which the Partnership is entitled based on its interests in
the properties. Revenue is deferred and a liability is recorded for those
properties where the estimated remaining reserves will not be sufficient to
enable the underproduced owner to recoup its entitled share through
production.
NET INCOME PER INVESTING UNIT -
The net income per Investing Partner Unit is calculated by dividing
the aggregate Investing Partners' net income for the period by the number
of weighted average Investing Partner Units outstanding for that period.
18
<PAGE> 21
APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO FINANCIAL STATEMENTS - (CONTINUED)
INCOME TAXES -
The profit or loss of the Partnership for federal income tax reporting
purposes is included in the income tax returns of the partners.
Accordingly, no recognition has been given to income taxes in the
accompanying financial statements.
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 and
disclosure of contingent 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 those
estimates. Significant estimates with regard to these financial statements
include the estimate of proved oil and gas reserve quantities and the
related present value of estimated future net cash flows therefrom. See
"Supplemental Oil and Gas Disclosures" below.
PAYABLE TO/RECEIVABLE FROM APACHE -
Payable to/receivable from Apache represents the net result of the
Investing Partners' revenue and expenditure transactions in the current
month. Generally, this amount will be transferred to or funded by Apache,
as appropriate, in the month after the Partnership's transactions are
processed and the net results from operations are determined.
MAINTENANCE AND REPAIRS -
Maintenance and repairs are charged to expense as incurred.
Recompletions and replacements that improve or extend the life of existing
properties are capitalized.
(3) COMPENSATION TO APACHE
Apache is entitled to the following types of compensation and
reimbursement for costs and expenses.
<TABLE>
<CAPTION>
TOTAL REIMBURSED BY THE INVESTING
PARTNERS FOR THE YEAR ENDED DECEMBER 31,
-----------------------------------------
1999 1998 1997
---------- ---------- ----------
<S> <C> <C> <C> <C>
a. Apache is reimbursed for general, administrative and
overhead expenses incurred in connection with the
management and operation of the Partnership's business $ 436 $ 432 $ 432
========== ========== ==========
b. Apache is reimbursed for exploration and development
overhead costs incurred in the Partnership's operations.
These costs are based on exploration and development
activities and are capitalized to oil and gas properties $ 73 $ 140 $ 222
========== ========== ==========
</TABLE>
Apache operates certain Partnership properties. Billings to the
Partnership are made on the same basis as to unaffiliated third parties or
at prevailing industry rates.
19
<PAGE> 22
APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(4) OIL AND GAS PROPERTIES
The following tables contain direct cost information and changes in
the Partnership's oil and gas properties for each of the years ended
December 31. All costs of oil and gas properties are currently being
amortized.
<TABLE>
<CAPTION>
1999 1998 1997
------------ ------------- ------------
(In thousands)
<S> <C> <C> <C>
Oil and Gas Properties
----------------------
Balance, beginning of year $ 168,332 $ 166,397 $ 162,878
Costs incurred during the year:
Leasehold additions -
Investing Partners - 17 5
Managing Partner - 2 1
Development -
Investing Partners 1,367 2,257 3,906
Managing Partner 9 56 96
Property sales proceeds (1) -
Investing Partners (191) (357) (440)
Managing Partner (21) (40) (49)
------------ ------------ ------------
Balance, end of year $ 169,496 $ 168,332 $ 166,397
============ ============ ============
</TABLE>
(1) The 1999 property sale proceeds reflect the sale of the Partnership's
interest in Matagorda Island Block 705 (Roberto Prospect) and the southwest
quadrant of North Padre Island Block 976 (Rosita Prospect). The 1998
property sales proceeds are a result of the sale of West Cameron Block 368
(Krypton Prospect). The 1997 property sales proceeds reflect the sale of
High Island Block A-6 (Glenda Prospect) and the sale of the Partnership's
interest in a farmout on Matagorda Island Block 670/682 (Roberto Prospect).
<TABLE>
<CAPTION>
MANAGING INVESTING
PARTNER PARTNERS TOTAL
------------- ------------- -------------
(In thousands)
<S> <C> <C> <C>
Accumulated Depreciation, Depletion and Amortization
----------------------------------------------------
Balance, December 31, 1996 $ 19,640 $ 135,770 $ 155,410
Provision 265 2,718 2,983
------------- ------------- -------------
Balance, December 31, 1997 19,905 138,488 158,393
Provision 196 2,525 2,721
------------- ------------- -------------
Balance, December 31, 1998 20,101 141,013 161,114
Provision 197 2,847 3,044
------------- ------------- -------------
Balance, December 31, 1999 $ 20,298 $ 143,860 $ 164,158
============= ============= =============
</TABLE>
The Partnership's aggregate DD&A expense as a percent of oil and gas
sales for 1999, 1998 and 1997 was 36 percent, 35 percent and 25 percent,
respectively.
20
<PAGE> 23
APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(5) MAJOR CUSTOMER INFORMATION
Revenues received from major third party customers that exceeded 10
percent of oil and gas sales are discussed below. No other third party
customers individually accounted for more than ten percent of oil and gas
sales.
Beginning in April 1996, Producers Energy Marketing LLC (ProEnergy),
an affiliate of Apache until June 1998, became the principal purchaser of
the Partnership's natural gas production. Sales to ProEnergy accounted for
74 percent, 82 percent, and 75 percent of the Partnership's oil and gas
sales in 1999, 1998 and 1997, respectively. In June 1998, Apache formed a
strategic alliance with Cinergy Corp. (Cinergy) to market substantially all
of Apache's natural gas production from North America and sold its 57
percent interest in ProEnergy to Cinergy. ProEnergy, renamed Cinergy
Marketing & Trading, LLC in June 1999, will continue to market Apache's
North American natural gas production for 10 years, with an option to
terminate after six years, under an amended and restated gas purchase
agreement effective July 1, 1998. The prices the Partnership received for
its gas production prior to the sale of ProEnergy were, in the opinion of
Apache, comparable to the prices that would have been received from a
non-affiliated party. The prices the Partnership received after the sale of
ProEnergy and will continue to receive for its gas production, in the
opinion of Apache, approximate market prices.
Sales of oil and condensate to Plains Petroleum Operating Co.
accounted for 26 percent, 17 percent and 20 percent of the Partnership's
oil and gas sales in 1999, 1998 and 1997, respectively.
Effective November 1992, with Apache's and the Partnership's
acquisition of an additional net revenue interest in Matagorda Island
Blocks 681 and 682, a wholly-owned subsidiary of Apache purchased from
Shell Oil Company (Shell) a 14.4 mile natural gas and condensate pipeline
connecting Matagorda Island Block 681 to onshore markets. The Partnership
paid the Apache subsidiary transportation fees totaling $.1 million in each
of 1999 and 1998, and $.2 million in 1997 for the Partnership's share of
gas. The fees, which are netted against oil and gas sales on the income
statement, were at the same rates and terms as previously paid to Shell.
The Partnership's revenues are derived principally from
uncollateralized sales to customers in the oil and gas industry; therefore,
customers may be similarly affected by changes in economic and other
conditions within the industry. The Partnership has not experienced
material credit losses on such sales.
(6) DEBT
In July 1992, through Apache, the Partnership obtained a line of
credit. Proceeds from this revolving bank facility were used to repay a
limited recourse note which had previously been issued to finance offshore
leasehold in the Partnership. The $2.0 million of outstanding debt at
December 31, 1996, was due in 1998; however, on January 31, 1997, the
Partnership repaid the loan in its entirety and terminated the facility.
It is expected that cash flows from operating activities will be
sufficient to meet the Partnership's liquidity needs for routine operations
over the next two years. However, in the event future short-term operating
cash requirements are greater than the Partnership's financial resources,
the Partnership will seek short-term, interest-bearing advances from the
Managing Partner as needed.
(7) FINANCIAL INSTRUMENTS
The carrying amount of cash and cash equivalents, accrued revenues
receivables and other financial instruments included in the accompanying
balance sheet approximated their fair values at December 31, 1999 and 1998.
The Partnership did not engage in hedging activities during the three-year
period ended December 31, 1999.
21
<PAGE> 24
APACHE OFFSHORE INVESTMENT PARTNERSHIP
SUPPLEMENTAL OIL AND GAS DISCLOSURES
(UNAUDITED)
OIL AND GAS RESERVE INFORMATION -
Proved oil and gas reserve quantities are based on estimates prepared
by Ryder Scott Company, L.P., Petroleum Consultants, independent petroleum
engineers, in accordance with guidelines established by the SEC. These
reserves are subject to revision due to the inherent imprecision in
estimating reserves, and are revised as additional information becomes
available. All the Partnership's reserves are located offshore Texas and
Louisiana.
There are numerous uncertainties inherent in estimating quantities of
proved reserves and projecting future rates of production and timing of
development expenditures. The following reserve data represents estimates
only and should not be construed as being exact.
(Oil in Mbbls and gas in MMcf)
<TABLE>
<CAPTION>
1999 1998 1997
---------------- --------------- ----------------
OIL GAS OIL GAS OIL GAS
------ ------ ----- ------ ----- ------
<S> <C> <C> <C> <C> <C> <C>
Proved Reserves
---------------
Beginning of year 832 10,269 922 12,511 1,065 16,396
Extensions, discoveries and other
additions 4 163 3 2,080 92 289
Revisions of previous estimates (27) 1,684 17 (997) 281 (150)
Production (122) (2,938) (106) (3,127) (125) (3,878)
Sales of reserves in-place - (186) (4) (198) (391) (146)
------ ------ ----- ----- ----- ------
End of year 687 8,992 832 10,269 922 12,511
====== ====== ===== ===== ===== ======
Proved Developed
----------------
Beginning of year 792 8,585 883 10,824 917 14,223
====== ====== ===== ===== ==== ======
End of year 613 8,679 792 8,585 883 10,824
====== ====== ===== ===== ==== ======
</TABLE>
22
<PAGE> 25
APACHE OFFSHORE INVESTMENT PARTNERSHIP
SUPPLEMENTAL OIL AND GAS DISCLOSURES - (CONTINUED)
(UNAUDITED)
FUTURE NET CASH FLOWS -
The following table sets forth unaudited information concerning future
net cash flows from proved oil and gas reserves. Future cash inflows are
based on year-end prices. Operating costs and future development costs are
based on current costs with no escalation. As the Partnership pays no
income taxes, estimated future income tax expenses are omitted. This
information does not purport to present the fair value of the Partnership's
oil and gas assets, but does present a standardized disclosure concerning
possible future net cash flows that would result under the assumptions
used.
Discounted Future Net Cash Flows Relating to Proved Reserves
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------------------------
1999 1998 1997
------------ ------------- ------------
(In thousands)
<S> <C> <C> <C>
Future cash inflows $ 37,964 $ 27,473 $ 46,733
Future production and development costs (7,219) (8,744) (10,739)
------------ ------------ ------------
Net cash flows 30,745 18,729 35,994
10 percent annual discount rate (9,483) (5,001) (9,137)
------------ ------------ ------------
Discounted future net cash flows $ 21,262 $ 13,728 $ 26,857
============ ============ ============
</TABLE>
The following table sets forth the principal sources of change in the
discounted future net cash flows:
<TABLE>
<CAPTION>
FOR THE YEAR ENDED DECEMBER 31,
----------------------------------------------
1999 1998 1997
----------- ----------- -----------
(In thousands)
<S> <C> <C> <C>
Sales, net of production costs $ (7,848) $ (6,827) $ (11,621)
Net change in prices and production costs 10,868 (9,548) (31,310)
Extensions, discoveries and other additions 483 2,662 1,751
Development costs incurred 885 1,278 -
Revisions of quantities 2,919 (1,029) 2,616
Accretion of discount 1,373 2,686 6,208
Changes in future development costs 24 (132) 617
Sales of reserves in-place (214) (192) (468)
Changes in production rates and other (956) (2,027) (3,014)
----------- ----------- -----------
$ 7,534 $ (13,129) $ (35,221)
=========== =========== ===========
</TABLE>
23
<PAGE> 26
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE PARTNERSHIP
All management functions are performed by Apache, the Managing Partner
of the Partnership. The Partnership itself has no officers or directors.
Information concerning the officers and directors of Apache set forth under
the captions "Nominees for Election as Directors", "Continuing Directors",
"Executive Officers of the Company", and "Securities Ownership and
Principal Holders" in the proxy statement relating to the 2000 annual
meeting of shareholders of Apache (the Apache Proxy) is incorporated herein
by reference.
ITEM 11. EXECUTIVE COMPENSATION
See Note (3), "Compensation to Apache" of the Partnership's financial
statements, under Item 8 above, for information regarding compensation to
Apache as Managing Partner. The information concerning the compensation
paid by Apache to its officers and directors set forth under the captions
"Summary Compensation Table", "Option/SAR Grants Table", "Option/SAR
Exercises and Year-End Value Table", "Employment Contracts and Termination
of Employment and Change-in-Control Arrangements", and "Director
Compensation" in the Apache Proxy is incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Apache, as an Investing Partner and the General Partner, owns 53
Units, or 4.7 percent of the outstanding Units of the Partnership, as of
December 31, 1999. Directors and officers of Apache own 9.7 Units, slightly
less than one percent of the Partnership's Units, as of December 31, 1999.
Apache owns a one-percent General Partner interest (15 equivalent Units).
To the knowledge of the Partnership, no Investing Partner owns, of record
or beneficially, more than five percent of the Partnership's outstanding
Units.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Effective November 1992, with Apache's and the Partnership's
acquisition of an additional net revenue interest in Matagorda Island
Blocks 681 and 682, a wholly-owned subsidiary of Apache purchased from
Shell a 14.4 mile-long natural gas and condensate pipeline connecting
Matagorda Island Block 681 to onshore markets. The Partnership paid the
Apache subsidiary transportation fees totaling $.1 million in each of 1999
and 1998 and $.2 million in 1997 for Partnership's share of gas. The fees,
which are netted against oil and gas sales on the income statement, were at
the same rates and terms as previously paid to Shell.
Apache markets the Partnership's natural gas production through
ProEnergy. In June 1998, Apache formed a strategic alliance with Cinergy to
market substantially all of Apache's natural gas production from North
America and sold its 57 percent interest in ProEnergy to Cinergy.
ProEnergy, renamed Cinergy Marketing & Trading, LLC in June 1999, will
continue to market Apache's North American natural gas production for 10
years, with an option to terminate after six years, under an amended and
restated gas purchase agreement effective July 1, 1998. The prices the
Partnership received for its gas production prior to the sale of ProEnergy
were, in the opinion of Apache, comparable to the prices that would have
been received from a non-affiliated party. The prices the Partnership
received after the sale of ProEnergy and will continue to receive for its
gas production, in the opinion of Apache, approximate market prices.
24
<PAGE> 27
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
a.(1) Financial Statements - See accompanying index to financial statements
in Item 8 above.
(2) Financial Statement Schedules - See accompanying index to financial
statements in Item 8 above.
(3) Exhibits
3.1 Partnership Agreement of Apache Offshore Investment
Partnership (incorporated by reference to Exhibit (3)(i) to
Form 10 filed by Partnership with the Commission on April
30, 1985, Commission File No. 0-13546).
3.2 Amendment No. 1, dated February 11, 1994, to the Partnership
Agreement of Apache Offshore Investment Partnership
(incorporated by reference to Exhibit 3.3 to Partnership's
Annual Report on Form 10-K for the year ended December 31,
1993, Commission File No. 0-13546).
3.3 Limited Partnership Agreement of Apache Offshore Petroleum
Limited Partnership (incorporated by reference to Exhibit
(3)(ii) to Form 10 filed by Partnership with the Commission
on April 30, 1985, Commission File No. 0-13546).
10.1 Credit Agreement dated July 24, 1992, between Apache, the
Lenders named therein and the First National Bank of
Chicago, as Agent (incorporated by reference to Exhibit 10.1
to Partnership's Quarterly Report on Form 10-Q for the
quarter ended June 30, 1992, Commission File No. 0-13546).
10.2 Second Amendment, dated as of July 29, 1994, to Credit
Agreement between Apache, the Lenders named therein and the
First National Bank of Chicago, as Agent (incorporated by
reference to Exhibit 10.1 to Partnership's Quarterly Report
on Form 10-Q for the quarter ended September 30, 1994,
Commission File No. 0-13546).
10.3 Third Amendment, dated as of March 31, 1995, to the Credit
Agreement between Apache, the Lenders named therein and the
First National Bank of Chicago, as Agent (incorporated by
reference to Exhibit 10.6 to Partnership's Annual Report on
Form 10-K for the year ended December 31, 1995, Commission
File No. 0-13546).
10.4 Form of Assignment and Assumption Agreement between Apache
Corporation and Apache Offshore Petroleum Limited
Partnership (incorporated by reference to Exhibit 10.2 to
Partnership's Quarterly Report on Form 10-Q for the quarter
ended June 30, 1992, Commission File No. 0-13546).
10.5 Joint Venture Agreement, dated as of November 23, 1992,
between Apache Corporation and Apache Offshore Petroleum
Limited Partnership (incorporated by reference to Exhibit
10.6 to Partnership's Annual Report on Form 10-K for the
year ended December 31, 1992, Commission File No. 0-13546).
10.6 Matagorda Island 681 Field Purchase and Sale Agreement with
Option to Exchange, dated November 24, 1992, between Apache
Corporation, Shell Offshore, Inc. and SOI Royalties, Inc.
(incorporated by reference to Exhibit 10.7 to Partnership's
Annual Report on Form 10-K for the year ended December 31,
1992, Commission File No. 0-13546).
25
<PAGE> 28
*23.1 Consent of Ryder Scott Company, L.P., Petroleum
Consultants.
*27.1 Financial Data Schedule.
99.1 Consent statement of the Partnership, dated January 7, 1994
(incorporated by reference to Exhibit 99.1 to Partnership's
Annual Report on Form 10-K for the year ended December 31,
1993, Commission File No. 0-13546).
99.2 Proxy statement to be dated on or about March 31, 2000,
relating to the 2000 annual meeting of shareholders of
Apache Corporation (incorporated by reference to the
document filed by Apache pursuant to Rule 14A, Commission
File No. 1-4300).
*Filed herewith.
b. Reports filed on Form 8-K.
No reports on Form 8-K were filed during the fiscal quarter ended
December 31, 1999.
26
<PAGE> 29
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Partnership has duly caused this report to be signed
on its behalf by the undersigned, thereunto duly authorized.
APACHE OFFSHORE INVESTMENT PARTNERSHIP
By: Apache Corporation, General Partner
Date: March 23, 2000 By: /s/ Raymond Plank
-----------------
Raymond Plank,
Chairman and Chief Executive Officer
POWER OF ATTORNEY
The officers and directors of Apache Corporation, General Partner of Apache
Offshore Investment Partnership, whose signatures appear below, hereby
constitute and appoint Raymond Plank, G. Steven Farris, Z.S. Kobiashvili and
Roger B. Plank, and each of them (with full power to each of them to act alone),
the true and lawful attorney-in-fact to sign and execute, on behalf of the
undersigned, any amendment(s) to this report and each of the undersigned does
hereby ratify and confirm all that said attorneys shall do or cause to be done
by virtue thereof.
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
Partnership and in the capacities and on the dates indicated.
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
- ---------------------------------------------- -------------------------------------- -------------------
<S> <C> <C>
/s/ Raymond Plank Chairman and Chief Executive March 23, 2000
- ---------------------------------------------- Officer (Principal Executive
Raymond Plank Officer)
/s/ Roger B. Plank Vice President and Chief Financial March 23, 2000
- ---------------------------------------------- Officer (Principal Financial
Roger B. Plank Officer)
/s/ Thomas L. Mitchell Vice President and Controller March 23, 2000
- ---------------------------------------------- (Principal Accounting Officer)
Thomas L. Mitchell
</TABLE>
<PAGE> 30
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
- ---------------------------------------------- -------------------------------------- -------------------
<S> <C> <C>
/s/ Frederick M. Bohen Director March 23, 2000
- ----------------------------------------------
Frederick M. Bohen
/s/ G. Steven Farris Director March 23, 2000
- ----------------------------------------------
G. Steven Farris
/s/ Randolph M. Ferlic Director March 23, 2000
- ----------------------------------------------
Randolph M. Ferlic
/s/ Eugene C. Fiedorek Director March 23, 2000
- ----------------------------------------------
Eugene C. Fiedorek
/s/ A. D. Frazier, Jr. Director March 23, 2000
- ----------------------------------------------
A. D. Frazier, Jr.
Director
- ----------------------------------------------
Stanley K. Hathaway
/s/ John A. Kocur Director March 23, 2000
- ----------------------------------------------
John A. Kocur
/s/ George D. Lawrence Jr. Director March 23, 2000
- ----------------------------------------------
George D. Lawrence Jr.
/s/ Mary Ralph Lowe Director March 23, 2000
- ----------------------------------------------
Mary Ralph Lowe
/s/ F. H. Merelli Director March 23, 2000
- ----------------------------------------------
F. H. Merelli
/s/ Rodman D. Patton Director March 23, 2000
- ----------------------------------------------
Rodman D. Patton
/s/ Joseph A. Rice Director March 23, 2000
- ----------------------------------------------
Joseph A. Rice
</TABLE>
<PAGE> 31
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT NO. DESCRIPTION
- ----------- -----------
<S> <C>
3.1 Partnership Agreement of Apache Offshore Investment Partnership
(incorporated by reference to Exhibit (3)(i) to Form 10 filed by
Partnership with the Commission on April 30, 1985, Commission
File No. 0-13546).
3.2 Amendment No. 1, dated February 11, 1994, to the Partnership
Agreement of Apache Offshore Investment Partnership (incorporated
by reference to Exhibit 3.3 to Partnership's Annual Report on
Form 10-K for the year ended December 31, 1993, Commission File
No. 0-13546).
3.3 Limited Partnership Agreement of Apache Offshore Petroleum
Limited Partnership (incorporated by reference to Exhibit (3)(ii)
to Form 10 filed by Partnership with the Commission on April 30,
1985, Commission File No. 0-13546).
10.1 Credit Agreement dated July 24, 1992, between Apache, the Lenders
named therein and the First National Bank of Chicago, as Agent
(incorporated by reference to Exhibit 10.1 to Partnership's
Quarterly Report on Form 10-Q for the quarter ended June 30,
1992, Commission File No. 0-13546).
10.2 Second Amendment, dated as of July 29, 1994, to Credit Agreement
between Apache, the Lenders named therein and the First National
Bank of Chicago, as Agent (incorporated by reference to Exhibit
10.1 to Partnership's Quarterly Report on Form 10-Q for the
quarter ended September 30, 1994, Commission File No. 0-13546).
10.3 Third Amendment, dated as of March 31, 1995, to the Credit
Agreement between Apache, the Lenders named therein and the First
National Bank of Chicago, as Agent (incorporated by reference to
Exhibit 10.6 to Partnership's Annual Report on Form 10-K for the
year ended December 31, 1995, Commission File No. 0-13546).
10.4 Form of Assignment and Assumption Agreement between Apache
Corporation and Apache Offshore Petroleum Limited Partnership
(incorporated by reference to Exhibit 10.2 to Partnership's
Quarterly Report on Form 10-Q for the quarter ended June 30,
1992, Commission File No. 0-13546).
10.5 Joint Venture Agreement, dated as of November 23, 1992, between
Apache Corporation and Apache Offshore Petroleum Limited
Partnership (incorporated by reference to Exhibit 10.6 to
Partnership's Annual Report on Form 10-K for the year ended
December 31, 1992, Commission File No. 0-13546).
10.6 Matagorda Island 681 Field Purchase and Sale Agreement with
Option to Exchange, dated November 24, 1992, between Apache
Corporation, Shell Offshore, Inc. and SOI Royalties, Inc.
(incorporated by reference to Exhibit 10.7 to Partnership's
Annual Report on Form 10-K for the year ended December 31, 1992,
Commission File No. 0-13546).
*23.1 Consent of Ryder Scott Company, L.P., Petroleum Consultants.
*27.1 Financial Data Schedule.
99.1 Consent statement of the Partnership, dated January 7, 1994
(incorporated by reference to Exhibit 99.1 to Partnership's
Annual Report on Form 10-K for the year ended December 31, 1993,
Commission File No. 0-13546).
99.2 Proxy statement to be dated on or about March 31, 2000, relating
to the 2000 annual meeting of shareholders of Apache Corporation
(incorporated by reference to the document filed by Apache
pursuant to Rule 14A, Commission File No. 1-4300).
</TABLE>
- ----------------
*Filed herewith.
<PAGE> 1
[RYDER SCOTT LETTERHEAD]
EXHIBIT 23.1
CONSENT OF RYDER SCOTT COMPANY, L.P.
As independent petroleum engineers, we hereby consent to the reference in
this Form 10-K of Apache Offshore Investment Partnership to our Firm's name and
our Firm's review of the proved oil and gas reserve quantities of Apache
Offshore Investment Partnership as of January 1, 2000.
<TABLE>
<S> <C>
/s/ Ryder Scott Company, L.P.
Ryder Scott Company, L.P.
Houston, Texas
March 23, 2000
</TABLE>
<TABLE> <S> <C>
<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-END> DEC-31-1999
<CASH> 2,748,812
<SECURITIES> 0
<RECEIVABLES> 635,826
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 3,384,638
<PP&E> 169,496,346
<DEPRECIATION> (164,158,568)
<TOTAL-ASSETS> 8,722,416
<CURRENT-LIABILITIES> 967,553
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 7,754,863
<TOTAL-LIABILITY-AND-EQUITY> 8,722,416
<SALES> 8,521,418
<TOTAL-REVENUES> 8,613,502
<CGS> 3,717,690
<TOTAL-COSTS> 3,717,690
<OTHER-EXPENSES> 544,760
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 4,351,052
<INCOME-TAX> 0
<INCOME-CONTINUING> 4,351,052
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 4,351,052
<EPS-BASIC> 2,707
<EPS-DILUTED> 2,707
</TABLE>
