<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, 1997,
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 1998
annual meeting of shareholders have been incorporated by reference into Part III
hereof.
- -------------------------------------------------------------------------------
<PAGE> 2
TABLE OF CONTENTS
DESCRIPTION
Item Page
- ---- ----
PART I
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......................... 11
9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE........................................ 25
PART III
10. DIRECTORS AND EXECUTIVE OFFICERS OF THE PARTNERSHIP................. 25
11. EXECUTIVE COMPENSATION.............................................. 25
12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT...... 25
13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS...................... 25
PART IV
14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K.... 26
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 is a Delaware general partnership
organized in October 1983, with Apache Corporation (Apache), a Delaware
corporation, as Managing Partner and public investors as Investing Partners. The
Investing Partners purchased Units of Partnership Interests (Units) at $150,000
per Unit with five percent down and the balance in payments as called by the
Partnership. As of December 31, 1997, a total of $85,000 had been called for
each Unit. In 1989, the 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 Partnership invested,
and will continue to invest, its entire capital as the sole limited partner in
Apache Offshore Petroleum Limited Partnership, a Delaware limited partnership of
which Apache is the sole general partner. The limited partnership conducts
operations on behalf of the Partnership. The term "Partnership", as used
hereafter, refers to either the general partnership or 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 1.61 percent to 7.08 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 members' 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 access to additional financing to fund its proportionate share of the
acquisition and participated only to the extent of 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.
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.
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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.
1997 Business Development
The Partnership spud eight new wells in 1997. Three developmental wells were
drilled in 1997 at South Timbalier Block 295. One of these wells was completed
and began producing in 1997. The second well was sidetracked and abandoned while
the third was in progress at year-end. Additionally, a water-injection well spud
in 1996 at South Timbalier Block 295 was drilled to total depth in 1997 and is
awaiting completion in 1998.
One exploratory well was drilled, completed and began production in 1997 at
Ship Shoal Block 258/259. A developmental well was also drilled and is planned
to be completed in 1998.
The Partnership commenced drilling a sidetrack developmental well at South
Pass Block 83 in 1997. Two additional developmental wells are approved for
drilling in 1998. The Partnership expects all three wells to commence production
during 1998.
In 1997, one developmental well was drilled, completed, and began production
at the Roberto Prospect. An exploratory well was drilled at Matagorda Island
Block 705 in 1997 and is expected to be completed in 1998.
Since inception, the Partnership has acquired an interest in 49 Prospects.
As of December 31, 1997, 40 prospects have been surrendered or sold.
The status of the Partnership's 49 original prospects is shown in the
following table:
As of December 31,
----------------------
Prospect Status 1997 1996
-------------------------------- -------- --------
Producing-Fully Developed 6 10
Producing-Partially Developed 3 1
----- -----
Total Discoveries 9 11
Surrendered/Sold 40 38
----- -----
Total 49 49
===== =====
As of December 31, 1997, 109 wells have been drilled on the nine remaining
prospects. Of the 109 wells, 85 were indicated productive and of those, 84 are
currently producing. Sixteen of the Partnership's producing wells are dual
completions. The Partnership had, at December 31, 1997, estimated proved oil and
gas reserves of 18.0 Bcfe, of which 69 percent was natural gas.
During 1997, the Partnership sold its interest in the Glenda Prospect (High
Island Block A-6) and sold its interest in a farmout, which was operated by
Forest Oil Corporation, on the Roberto Prospect (Matagorda Island Block
670/682). The Matagorda Island Block 681 and 682 portions of the Roberto
Prospect remain with the Partnership. In January 1998, the Partnership sold its
interest in the Krypton Prospect (West Cameron Block 368).
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 full cost accounting rules, capitalized costs of
oil and gas properties may not exceed the present value of estimated future net
revenues from proved 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 due to ceiling test limitations during 1997.
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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 1997, 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).
Apache held a 48 percent interest in ProEnergy at December 31, 1997. The
Partnership expects to receive prevailing spot market prices at the relevant
delivery points on an ongoing basis.
See Note (5) to the Partnership's financial statements "Major Customer
Information" under Item 8 below. 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 and ProEnergy 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, 1997, is set forth below:
<TABLE>
<CAPTION>
Producing
Oil/Gas Acres
Wells Average -----------------
------------- Working Dev. Undev.
Lease Block Prospect State Gross Net Interest Gross Gross
- ----------------------- -------- ----- ----- ----- -------- ------ ------
<S> <C> <C> <C> <C> <C> <C> <C>
Ship Shoal 258, 259 Genesis LA 13 .8 .0628698 10,141 --
South Timbalier 276,
295 Grover LA 28 2.0 .0708333 10,000 --
North Padre Island 969,
976 Rosita TX 11 .8 .0708333 11,520 --
Matagorda Island 681,
682 Roberto TX 16 1.0 .0628698 11,520 --
Matagorda Island 588 Cortez TX 2 -- ORRI 5,760 --
Matagorda Island 705 Matagorda Island TX -- -- .0160999 -- 360
West Cameron 368 Krypton LA 1 .1 .0708333 5,000 --
South Pass 83, 74 Manx LA 7 .5 .0678914 7,500 --
East Cameron 60 East Aragonite LA 1 .1 .0944444 5,000 --
Vermillion 95 Topaz LA 1 -- ORRI 5,000 --
Ship Shoal 201, 202 Bromeliad LA 4 -- ORRI 10,000 --
--- --- ------ ------
84 5.3 81,441 360
=== === ====== ======
</TABLE>
During 1997, the Partnership's interest in High Island Block A-6 was sold
and a non-producing lease on East Cameron Block 51 (a portion of the East
Aragonite Prospect) expired. In January 1998, the Partnership sold its interest
in the Krypton Prospect (West Cameron Block 368). See Note (4), "Oil and Gas
Properties", and the Partnership's Supplemental Oil and Gas Disclosures under
Item 8 below for costs incurred in oil and gas development and production
activities and related reserve information. On a net revenue basis, the
Partnership owns 5.3 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.
Production Average Sales Prices
-------------- Average --------------------
Year Ended Oil Gas Production Oil Gas
December 31, (Mbbls) (MMcf) Cost per Mcfe (per Bbl) (per Mcf)
- ----------- ------ ------ ------------- -------- --------
1997 125 3,878 $ .10 $ 19.30 $ 2.49
1996 164 5,651 .18 20.73 2.50
1995 210 6,052 .19 16.97 1.58
As 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, continued declines in
production can be expected due to natural depletion.
See the Supplemental Oil and Gas Disclosures under Item 8 below 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 1997.
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PART II
ITEM 5. MARKET FOR THE PARTNERSHIP'S SECURITIES AND RELATED SECURITY
HOLDER MATTERS
As of December 31, 1997, there were 1,184.2 of the Partnership's Units
outstanding held by approximately 964 investors of record. There is no other
class of security outstanding or authorized. The Units are not traded on any
security market. Cash distributions totaled approximately $5.4 million, or
$4,500 per Unit, during each of 1997 and 1996.
As discussed in Item 7 below, 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,
1997, should be read in conjunction with the Partnership's financial statements
and related notes included under Item 8 below.
<TABLE>
<CAPTION>
At or For the Years Ended December 31,
----------------------------------------------------
1997 1996 1995 1994 1993
-------- -------- -------- -------- --------
(In thousands, except per Unit amounts)
<S> <C> <C> <C> <C> <C>
Total assets $ 10,524 $ 12,252 $ 13,486 $ 14,291 $ 19,521
========= ========= ========= ========= =========
Long-term debt $ -- $ 1,998 $ 7,310 $ 9,435 $ 14,790
========= ========= ========= ========= =========
Partners' capital $ 8,647 $ 8,498 $ 5,472 $ 4,175 $ 3,334
========= ========= ========= ========= =========
Oil and gas sales $ 12,067 $ 17,511 $ 13,138 $ 16,926 $ 18,730
========= ========= ========= ========= =========
Net income $ 8,244 $ 11,127 $ 6,214 $ 10,116 $ 10,185
========= ========= ========= ========= =========
Net income allocated to:
Managing Partner $ 1,967 $ 2,652 $ 1,800 $ 2,519 $ 2,635
Investing Partners 6,277 8,475 4,414 7,597 7,550
--------- --------- --------- --------- ---------
$ 8,244 $ 11,127 $ 6,214 $ 10,116 $ 10,185
========= ========= ========= ========= =========
Net income per
Investing Partner Unit $ 5,260 $ 7,032 $ 3,584 $ 5,974 $ 5,838
========= ========= ========= ========= =========
Cash distributions per
Investing Partner Unit $ 4,500 $ 4,500 $ 2,250 $ 4,500 $ 2,000
========= ========= ========= ========= =========
</TABLE>
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
In 1997, the Partnership realized lower net income per Investing Partner
Unit than in 1996. Reduced production volumes for both natural gas and crude oil
was the most significant cause of lower net income. The average natural gas
price was slightly lower than the record high average price in 1996, while the
average crude oil price declined seven percent from 1996. Lease operating
expense (LOE) and depreciation, depletion and amortization (DD&A) expense were
lower in 1997, which resulted in a significant reduction in total operating
expenses. On January 31, 1997, the Partnership repaid the outstanding debt
balance and terminated its revolving credit facility. Thus, only one month of
interest expense was recorded in 1997. Overall, 1997 distributions per Investing
Partner Unit were consistent with distributions made in 1996.
RESULTS OF OPERATIONS
Net Income and Revenue
The Partnership reported net income of $8.2 million for 1997 versus $11.1
million in 1996. Net income per Investing Partner Unit decreased 25 percent, to
$5,260 from $7,032. The impact of lower production volumes and lower crude oil
prices on net income during 1997 was partially offset by lower LOE and DD&A
expense.
Revenues decreased 30 percent, from $17.5 million in 1996, to $12.2 million
in 1997. Natural gas and crude oil sales contributed 79 percent and 20 percent,
respectively, to the Partnership's total revenue in 1997, with the remainder
attributable to interest and other income. 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
1997 1996 (Decrease)
------- ------- ---------
<S> <C> <C> <C>
Gas volumes - Mcf per day 10,625 15,441 (31) %
Average gas price - per Mcf $ 2.49 $ 2.50 --
Oil volume - Barrels per day 341 447 (24) %
Average oil price - per barrel $ 19.30 $ 20.73 (7) %
</TABLE>
As 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, continued declines in
production can be expected due to natural depletion.
1997 Compared to 1996
- ----------------------
Natural gas sales for 1997 totaled $9.7 million, 31 percent lower than in
1996. The decrease was driven by lower production volumes due to normal declines
in production, which decreased revenues by $4.4 million, downtime for drilling
at South Timbalier Block 295, and downtime for drilling and compressor
installation work at Ship Shoal Block 259. Also contributing to the decline was
the Partnership taking less than its entitlement at South Pass Block 83 and
North Padre Island Block 969, where make-up volumes were taken by under-produced
working interest owners.
The Partnership's crude oil sales for the year totaled $2.4 million, a 29
percent decrease from 1996. The average realized price for 1997 decreased seven
percent when compared to 1996, reducing revenues by $.2 million. In addition to
the decrease in crude oil prices was a 106 bopd decline in production versus
1996, which reduced sales by $.8 million. The decrease in oil production
resulted primarily from natural decline at East Cameron Block 60 and downtime
for drilling operations at South Timbalier Block 295.
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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.
In 1997, approximately $70,000 of interest income was earned on the
Partnership's investment account resulting from cash accumulated to fund cash
distributions to Investing Partners and for the purchase of Units offered by
Investing Partners under the right of presentment.
In 1997, the Partnership received approximately $89,000 of other income from
a settlement related to High Island Block A-6.
Operating Expenses
Primarily as a result of lower oil and gas production, DD&A expense for 1997
decreased 31 percent from last year, while the Partnership's DD&A rate,
expressed as a percentage of sales, was 25 percent during each of 1997 and 1996.
LOE of $.4 million decreased by $.8 million, or 63 percent, during 1997 when
compared to 1996. The reduction in LOE in 1997 was the result of lower workover
activity and credits received from an internal review by Shell and a joint
venture audit.
Interest expense for 1997 includes only one month of interest as the
Partnership repaid the outstanding debt balance and terminated its revolving
credit facility on January 31, 1997.
1996 Compared to 1995
- ---------------------
Natural gas sales for 1996 totaled $14.1 million, 47 percent higher than
those recorded in 1995. The increase was driven by higher average realized
natural gas prices, which favorably impacted revenue by $5.2 million. Partially
offsetting this increase was a 1,140 Mcfd decline in natural gas production for
1996 when compared to 1995, which reduced revenues by $.6 million. The decline
in production from 1995 was primarily driven by natural declines at Roberto
(-665 Mcfd) and High Island Block A-6 (-387 Mcfd). Also contributing to the gas
production decline was the make-up of previously over-produced gas and natural
decline at South Pass Block 83 (-423 Mcfd).
The Partnership's crude oil sales for the year totaled $3.4 million, a five
percent decrease from 1995. The average realized price for 1996 increased 22
percent when compared to 1995, which favorably impacted revenues by $.6 million.
Offsetting the benefit of higher crude oil prices was a 128 bopd decline in
production versus 1995, which reduced sales by $.8 million. The decrease in oil
production resulted primarily from natural decline at South Timbalier Block 295.
In 1996, approximately $25,000 of interest income was earned on the
Partnership's investment account resulting from cash accumulated to fund cash
distributions to Investing Partners and for the purchase of Units offered by
Investing Partners under the right of presentment.
Operating Expenses
DD&A expense for 1996 decreased two percent from 1995, while the
Partnership's DD&A rate, expressed as a percentage of sales, was 25 percent
during 1996, compared to 34 percent in 1995. The rate decrease reflected higher
price realizations and upward reserve revisions.
LOE of $1.2 million decreased by $.2 million, or 11 percent, during 1996
when compared to 1995. The reduction in LOE in 1996 was the result of lower
workover activity.
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<PAGE> 10
Interest expense decreased 43 percent in 1996. The decrease was primarily a
result of a 73 percent reduction in debt from $7.3 million at December 31, 1995,
to $2.0 million at December 31, 1996. Also contributing to the decrease was a
slight decline in interest rates from 6.5 percent at December 31, 1995, to 6.4
percent at December 31, 1996.
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's interest expense decreased to $13,000 for 1997
from $339,000 for 1996 as a result of the debt extinguishment. The Partnership
used cash from operating activities in 1997, 1996 and 1995 to reduce debt by
$2.0 million, $5.3 million and $2.1 million, respectively.
During 1997, the Partnership's oil and gas property additions totaled $4.0
million. The 1997 additions include drilling activity on a water-injection well
and three developmental wells at South Timbalier Block 295. In addition, one
developmental well and one exploratory well (farmout) were drilled at Ship Shoal
Block 258/259, and one sidetrack developmental well was drilled at South Pass
Block 83. At Matagorda Island Block 681/682, one sidetrack developmental well
was drilled and one exploratory well was also drilled on the Matagorda Island
Block 705.
Additions to oil and gas properties totaled $1.1 million and $3.2 million in
1996 and 1995, respectively. The Partnership anticipates capital expenditures
will total approximately $2.8 million in 1998, based on preliminary information
provided by the operators of the properties in which the Partnership has
interests. The anticipated capital expenditures relate primarily to completions
at South Timbalier Block 295, Ship Shoal Block 258/259, Matagorda Island Block
705 and South Pass Block 83. In addition, two sidetrack wells are planned to be
spud on South Pass Block 83 and a recompletion is planned to be performed at
Ship Shoal Block 258/259. Additional capital expenditures may be proposed by the
operators in the future.
During 1997, the Partnership paid distributions to Investing Partners
totaling approximately 5.4 million or $4,500 per Unit, which is consistent with
the per unit distribution in 1996. The Partnership does not expect to make a
distribution in March 1998. Apache, as the Managing Partner, will review the
possibility of a distribution in October 1998. Future distributions will be
dependent on actual and expected production levels, realized and expected oil
and gas prices and actual and anticipated capital expenditures.
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 1996 and 1995, Investing Partners were paid $162,000 and $279,000,
respectively, for a total of 40.48 Units.
In 1997, the first right of presentment offer of $13,621 per Unit, plus
interest to the date of payment, was made to Investing Partners based on a
December 31, 1996 valuation date. The second right of presentment offer of
$10,946 per Unit, plus interest to the date of payment, was made to the
Investing Partners based on a valuation date of June 30, 1997. As a result, the
Partnership acquired 13.67 Units for a total of $180,000 in cash.
There will be two rights of presentment in 1998, 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.
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<PAGE> 11
Capital Resources and Liquidity
The Partnership's primary capital resource is net cash provided by operating
activities, which was $11.4 million for 1997, a decrease of 29 percent from
1996, reflecting oil and gas production declines and lower crude oil prices.
Future cash flows will be influenced by oil and gas prices and production and
are not presently ascertainable.
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
84 percent of the Partnership's 1997 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.
Private Securities Litigation Reform Act Disclosure
Certain forward-looking information contained in this report is being
provided in reliance upon the "safe harbor" provisions of the Private Securities
Litigation Reform Act of 1995, as set forth in Section 27A of the Securities Act
of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as
amended. Such information includes, without limitation, discussions as to
estimates, expectations, beliefs, plans and objectives concerning the
Partnership's future financial and operating performance. Such forward-looking
information is subject to assumptions and beliefs based on current information
known to the Partnership and factors that could yield actual results differing
materially from those anticipated. Such factors include, without limitation, the
prices received for the Partnership's oil and natural gas production, the costs
of acquiring, finding, developing and producing reserves, the rates of
production of the Partnership's hydrocarbon reserves, the Partnership's success
in acquiring or finding additional reserves, unforeseen operational hazards,
significant changes in tax or regulatory environments, and the political and
economic uncertainties of foreign oil and gas supplies.
Impact of the Year 2000 Issue
The "Year 2000 Issue" is the result of computer software being written
using two digits rather than four to define the applicable year. Apache, as
Managing Partner, manages the Partnership's operations. Apache uses a portion of
its staff 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. Any of the Managing Partner's computer
programs that have date-sensitive software may recognize a date using "00" as
the year 1900 rather than the year 2000. If left unremedied, this could result
in a system failure or miscalculations causing disruptions of operations
including, among other things, a temporary inability to process transactions or
engage in similar normal business activities.
9
<PAGE> 12
The Managing Partner is in the process of replacing significant portions of
its software to more effectively and efficiently meet its business needs.
Replacement computer systems selected by the Managing Partner will properly
recognize dates beyond December 31, 1999. The Managing Partner presently
believes that with conversions to new software, the Year 2000 Issue will be
eliminated. However, if such conversions are not made, or are not completed
timely, the Year 2000 Issue could have a material impact on the operations of
the Partnership. The Managing Partner plans to replace substantially all of its
existing systems within 15 months or not later than March 31, 1999.
The date on which the Managing Partner plans to complete installation of
its new system is based on management's best estimates, which were derived using
numerous assumptions of future events including the continued availability of
certain resources. However, there can be no guarantee that these estimates will
be achieved and actual results could differ materially from those plans.
Specific factors that might cause such material differences include, but are not
limited to, the availability and cost of personnel trained in this area and
similar uncertainties.
10
<PAGE> 13
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
APACHE OFFSHORE INVESTMENT PARTNERSHIP
INDEX TO FINANCIAL STATEMENTS AND SUPPORTING SCHEDULES
Page
Number
------
Report of Independent Public Accountants ...................... 12
Balance Sheet as of December 31, 1997 and 1996................. 13
Statement of Income for each of the three years in the
period ended December 31, 1997................................ 14
Statement of Cash Flows for each of the three years in the
period ended December 31, 1997 ............................... 15
Statement of Changes in Partners' Capital for each of the
three years in the period ended December 31, 1997............. 16
Notes to Financial Statements.................................. 17
Supplemental Oil and Gas Disclosures........................... 23
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.
11
<PAGE> 14
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, 1997 and 1996, 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, 1997. 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 generally accepted auditing
standards. 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, 1997 and 1996, and the results of its operations
and its cash flows for each of the three years in the period ended December 31,
1997, in conformity with generally accepted accounting principles.
ARTHUR ANDERSEN LLP
Houston, Texas
March 18, 1998
12
<PAGE> 15
APACHE OFFSHORE INVESTMENT PARTNERSHIP
BALANCE SHEET
<TABLE>
<CAPTION>
December 31,
-------------------------------
1997 1996
------------ ------------
<S> <C> <C>
ASSETS
CURRENT ASSETS:
Cash and cash equivalents $ 691,797 $ 1,737,470
Accrued revenues receivable 1,537,451 3,046,185
Receivable from Apache Corporation 218,729 --
Drilling advances 72,020 --
------------ ------------
2,519,997 4,783,655
------------ ------------
OIL AND GAS PROPERTIES, on the basis
of full cost accounting:
Proved properties 166,397,087 162,877,903
Less-Accumulated depreciation,
depletion and amortization (158,392,914) (155,409,894)
------------ ------------
8,004,173 7,468,009
------------ ------------
$ 10,524,170 $ 12,251,664
============ ============
LIABILITIES AND PARTNERS' CAPITAL
CURRENT LIABILITIES:
Accrued exploration and development $ 1,764,917 $ 513,948
Accrued operating expenses payable and other 112,263 398,898
Payable to Apache Corporation -- 843,084
------------ ------------
1,877,180 1,755,930
------------ ------------
LONG-TERM DEBT -- 1,997,500
------------ ------------
PARTNERS' CAPITAL:
Managing Partner 505,035 1,091,189
Investing Partners (1,184.2 and 1,197.9
Units outstanding, respectively) 8,141,955 7,407,045
------------ ------------
8,646,990 8,498,234
------------ ------------
$ 10,524,170 $ 12,251,664
============ ============
</TABLE>
The accompanying notes to financial statements are an
integral part of this statement.
13
<PAGE> 16
APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF INCOME
<TABLE>
<CAPTION>
For the Year Ended December 31,
------------------------------------------------
1997 1996 1995
------------ ------------ ------------
<S> <C> <C> <C>
REVENUES:
Oil and gas sales $ 12,066,643 $ 17,510,612 $ 13,138,358
Interest income 69,755 24,699 --
Other income 89,249 -- --
------------ ------------ ------------
12,225,647 17,535,311 13,138,358
------------ ------------ ------------
OPERATING EXPENSES:
Depreciation, depletion
and amortization 2,983,020 4,320,182 4,410,453
Lease operating 445,651 1,216,844 1,372,517
Administrative 540,000 532,325 529,832
Financing costs:
Interest expense 12,818 339,045 596,572
Amortization of deferred
financing costs -- -- 14,583
------------ ------------ ------------
3,981,489 6,408,396 6,923,957
------------ ------------ ------------
NET INCOME $ 8,244,158 $ 11,126,915 $ 6,214,401
============ ============ ============
Net income allocated to:
Managing Partner $ 1,967,386 $ 2,651,779 $ 1,799,940
Investing Partners 6,276,772 8,475,136 4,414,461
------------ ------------ ------------
$ 8,244,158 $ 11,126,915 $ 6,214,401
============ ============ ============
NET INCOME PER INVESTING PARTNER UNIT $ 5,260 $ 7,032 $ 3,584
============ ============ ============
WEIGHTED AVERAGE INVESTING PARTNER
UNITS OUTSTANDING 1,193.3 1,205.3 1,231.6
============ ============ ============
</TABLE>
The accompanying notes to financial statements are an
integral part of this statement.
14
<PAGE> 17
APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF CASH FLOWS
<TABLE>
<CAPTION>
For the Year Ended December 31,
----------------------------------------
1997 1996 1995
----------- ------------ ------------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $ 8,244,158 $ 11,126,915 $ 6,214,401
Adjustments to reconcile net income
to net cash provided by operating activities:
Depreciation, depletion and amortization 2,983,020 4,320,182 4,410,453
Amortization of deferred financing costs -- -- 14,583
Changes in operating assets and liabilities:
(Increase) decrease in accrued revenues
receivable 1,508,734 (301,197) (715,704)
Increase (decrease) in accrued
operating expenses payable (286,635) 191,476 2,340
Increase (decrease) in receivable
from/payable to Apache (1,061,813) 773,260 (248,397)
----------- ------------ ------------
Net cash provided by operating activities 11,387,464 16,110,636 9,677,676
----------- ------------ ------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas properties (4,007,934) (1,073,490) (3,159,530)
Proceeds from sales of oil and gas properties 488,750 17,425 264,072
Non-cash portion of oil and gas property additions 1,250,969 87,018 268,803
(Increase) decrease in drilling advances (72,020) 8,570 (8,570)
----------- ------------ ------------
Net cash used in investing activities (2,340,235) (960,477) (2,635,225)
----------- ------------ ------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Repurchase of Partnership Units (179,523) (161,899) (279,064)
Distributions to Investing Partners (5,362,339) (5,411,224) (2,778,868)
Distributions to Managing Partner, net (2,553,540) (2,527,170) (1,859,519)
Payments of long-term debt (1,997,500) (5,312,500) (2,125,000)
----------- ------------ ------------
Net cash used in financing activities (10,092,902) (13,412,793) (7,042,451)
----------- ------------ ------------
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS (1,045,673) 1,737,366 --
CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR 1,737,470 104 104
----------- ------------ ------------
CASH AND CASH EQUIVALENTS, END OF YEAR $ 691,797 $ 1,737,470 $ 104
=========== ============ ============
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Cash paid during the year for interest $ 11,073 $ 285,000 $ 597,000
=========== ============ ============
</TABLE>
The accompanying notes to financial statements are an
integral part of this statement.
15
<PAGE> 18
APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF CHANGES IN PARTNERS' CAPITAL
<TABLE>
<CAPTION>
Managing Investing
Partner Partners Total
------------ ------------- -------------
<S> <C> <C> <C>
BALANCE, DECEMBER 31, 1994 $ 1,026,159 $ 3,148,503 $ 4,174,662
Distributions, net (1,859,519) (2,778,868) (4,638,387)
Repurchase of Partnership Units -- (279,064) (279,064)
Net income 1,799,940 4,414,461 6,214,401
------------ ------------- -------------
BALANCE, DECEMBER 31, 1995 966,580 4,505,032 5,471,612
Distributions, net (2,527,170) (5,411,224) (7,938,394)
Repurchase of Partnership Units -- (161,899) (161,899)
Net income 2,651,779 8,475,136 11,126,915
------------ ------------- -------------
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
============ ============= =============
</TABLE>
The accompanying notes to financial statements are an
integral part of this statement.
16
<PAGE> 19
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
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 Partnerships and holds
approximately four percent of the 1,184.2 Investing Partner Units (Units)
outstanding at December 31, 1997. 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 (14 remain as of December 31, 1997) 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 40
prospects have been surrendered/sold). The Partnership's working interests
in the nine remaining Venture prospects range from 1.61 percent to 7.08
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 84 percent of the Partnership's 1997 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.
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 1996 and 1995, the Partnership
paid the Investing Partners $162,000 and $279,000, respectively, to acquire
a total of 40.48 Units.
17
<PAGE> 20
During 1997, the Investing Partners sold a total of 13.67 Units to the
Partnership for a total of $180,000 in cash. The first right of presentment
was based upon a valuation date of December 31, 1996 for a purchase price of
$13,621 per Unit, plus interest to the date of payment. The second
presentment offer was based on a valuation date of June 30, 1997 for a
purchase price of $10,946 per Unit, plus interest to the payment date.
The Partnership is not in a position to predict how many Units will be
presented for repurchase during 1998, 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.
(Unaudited)
Total
Right of Presentment Repurchase Repurchase Price
Valuation Date Price Per Unit
-------------------- ------------ ----------------
December 31, 1993 $ 20,980,558 $ 13,226
June 30, 1994 17,540,491 12,562
December 31, 1994 14,725,170 10,391
June 30, 1995 13,345,913 10,114
December 31, 1995 14,181,413 10,698
June 30, 1996 16,881,655 10,572
December 31, 1996 17,514,216 13,621
June 30, 1997 17,188,997 10,946
Capital Contributions -
A total of $85,000 per Unit, or approximately 57 percent of investor
subscriptions, were called through December 31, 1997. 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 1,184.2 Units
at December 31, 1997.
18
<PAGE> 21
(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 which 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 generally accepted accounting principles.
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 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.
Per Unit Calculation -
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.
19
<PAGE> 22
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.
Receivable from/Payable to Apache -
Receivable from/payable to Apache represents the net result of the
Investing Partners' revenue and expenditure transactions in the current
month. Generally, this amount will be funded by or transferred to 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 incurred by the Investing
Partners for the year ended
` December 31,
-----------------------------------
1997 1996 1995
------- ------- -------
(In thousands)
<S> <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 $ 432 $ 426 $ 424
======= ======= =======
b. Apache is reimbursed for exploration
and development overhead costs
incurred in the Partnership's operations,
which costs are based on exploration
and development activities and are
capitalized to oil and gas properties. $ 222 $ 77 $ 142
======= ======= =======
</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.
20
<PAGE> 23
(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>
Oil and Gas Properties 1997 1996 1995
---------------------- -------- -------- --------
(In thousands)
<S> <C> <C> <C>
Balance, beginning of year $ 162,878 $ 161,822 $ 158,926
Costs incurred during the year:
Leasehold additions (retirements) -
Investing Partners 5 23 (3)
Managing Partner 1 3 --
Development -
Investing Partners 3,906 1,020 3,092
Managing Partner 96 27 71
Property sales proceeds(1) -
Investing Partners (440) (13) (234)
Managing Partner (49) (4) (30)
--------- --------- ---------
Balance, end of year $ 166,397 $ 162,878 $ 161,822
========= ========= =========
</TABLE>
(1) The 1997 property sales proceeds are a result of the sale of the Glenda
Prospect (High Island Block A-6) and the sale of the Partnership's
interest in a farmout on the Roberto Prospect (Matagorda Island Block
670/682). The 1996 property sales proceeds are a result of the sale of
the No-See-Um Prospect (Vermillion Block 226/337). The Partnership's
interests sold in 1995 related to non-producing, non-unitized leases.
<TABLE>
<CAPTION>
Accumulated Depreciation, Managing Investing
Depletion and Amortization Partner Partners Total
-------------------------- -------- --------- ---------
(In thousands)
<S> <C> <C> <C>
Balance, December 31, 1994 $ 18,732 $ 127,947 $ 146,679
Provisions 441 3,970 4,411
--------- --------- ---------
Balance, December 31, 1995 19,173 131,917 151,090
Provisions 467 3,853 4,320
--------- --------- ---------
Balance, December 31, 1996 19,640 135,770 155,410
Provisions 265 2,718 2,983
--------- --------- ---------
Balance, December 31, 1997 $ 19,905 $ 138,488 $ 158,393
========= ========= =========
</TABLE>
The Partnership's aggregate DD&A expense was 25 percent, 25 percent and
34 percent of oil and gas sales for 1997, 1996 and 1995, respectively.
(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), a
48 percent owned affiliate of Apache, became the principal purchaser of the
Partnership's natural gas production. Sales to ProEnergy accounted for 87
percent and 73 percent of the Partnership's oil and gas sales in 1997 and
1996, respectively. The prices the Partnership receives for its gas
production are, in the opinion of Apache, comparable to the prices that
would be received from a non-affiliated party.
21
<PAGE> 24
Natural Gas Clearinghouse (NGC) was the principal purchaser of the
Partnership's spot market gas production from April 1990 through September
30, 1995. Sales to NGC accounted for 49 percent of the Partnership's oil and
gas sales in 1995. Sales of oil and condensate to Plains Petroleum Operating
Co. accounted for nine percent, 10 percent, and 28 percent of the
Partnership's oil and gas sales in 1997, 1996 and 1995, 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 an Apache
subsidiary transportation fees totaling $.2 million in each of 1997, 1996
and 1995 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 revenue
receivables and other financial instruments included in the accompanying
balance sheet approximated their fair values at December 31, 1997 and 1996.
The Partnership did not engage in hedging activities during the three-year
period ended December 31, 1997.
22
<PAGE> 25
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 Petroleum Engineers, 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>
1997 1996 1995
----------------- ------------------ ------------------
Proved Reserves Oil Gas Oil Gas Oil Gas
--------------- ------ ------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C> <C>
Beginning of year 1,065 16,396 1,169 20,848 1,237 25,122
Extensions, discoveries
and other additions 92 289 -- 252 8 182
Revisions of
previous estimates 281 (150) 60 957 134 1,596
Production (125) (3,878) (164) (5,651) (210) (6,052)
Sales of reserves in-place (391) (146) -- (10) -- --
------ -------- ------ -------- ------ -------
End of year 922 12,511 1,065 16,396 1,169 20,848
====== ======= ====== ======= ====== =======
Proved Developed
----------------
Beginning of year 917 14,223 1,112 18,798 1,150 22,701
====== ======= ====== ======= ====== =======
End of year 883 10,824 917 14,223 1,112 18,798
====== ======= ====== ======= ====== =======
</TABLE>
23
<PAGE> 26
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.
<TABLE>
<CAPTION>
Discounted Future Net Cash Flows
Relating to Proved Reserves At December 31,
-----------------------------------
1997 1996 1995
--------- ---------- ---------
(In thousands)
<S> <C> <C> <C>
Future cash inflows $ 46,733 $ 97,475 $ 75,770
Future production and development costs (10,739) (14,072) (10,615)
--------- ---------- ----------
Net cash flows 35,994 83,403 65,155
10 percent annual discount rate (9,137) (21,325) (16,040)
--------- ---------- ----------
Discounted future net cash flows $ 26,857 $ 62,078 $ 49,115
========= ========== ==========
</TABLE>
The following table sets forth the principal sources of change in the
discounted future net cash flows:
<TABLE>
<CAPTION>
For the Years Ended December 31,
-------------------------------------
1997 1996 1995
--------- ---------- ---------
(In thousands)
<S> <C> <C> <C>
Sales, net of production costs $ (11,621) $ (16,294) $ (11,766)
Net change in prices and production
costs (31,310) 22,269 15,808
Extensions, discoveries and other
additions 1,751 862 566
Revisions of quantities 2,616 3,920 4,447
Accretion of discount 6,208 4,912 3,523
Changes in future development costs 617 (607) 301
Sales of reserves in-place (468) (18) --
Changes in production rates and other (3,014) (2,081) 1,004
--------- ---------- ----------
$ (35,221) $ 12,963 $ 13,883
========= ========== ==========
</TABLE>
24
<PAGE> 27
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 "Information About Nominees for Election as Directors", "Information
About Continuing Directors", "Executive Officers of the Company", and "Voting
Securities and Principal Holders" in the proxy statement relating to the 1998
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
approximately four percent of the outstanding Units of the Partnership, as of
December 31, 1997. Directors and officers of Apache own 9.7 Units, approximately
one percent of the Partnership's Units, as of December 31, 1997. 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
$.2 million in each of 1997, 1996 and 1995 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,
an affiliate of Apache. At December 31, 1997, Apache held a 48 percent interest
in ProEnergy. The prices the Partnership receives for its gas production are, in
the opinion of Apache, comparable to the prices that would be received from a
non-affiliated party.
25
<PAGE> 28
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. 1-13546).
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 Petroleum Engineers.
*27.1 Financial Data Schedule.
26
<PAGE> 29
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 dated March 30, 1998, relating to the 1998
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, 1997.
27
<PAGE> 30
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, 1998 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, 1998
- ------------------------------ Officer (Principal Executive
Raymond Plank Officer)
/s/ Roger B. Plank Vice President and Chief March 23, 1998
- ------------------------------ Financial Officer (Principal
Roger B. Plank Financial Officer)
/s/ Thomas L. Mitchell Vice President and Controller March 23, 1998
- ----------------------------- (Principal Accounting Officer)
Thomas L. Mitchell
</TABLE>
<PAGE> 31
<TABLE>
<CAPTION>
Signature Title Date
- --------- ----- ----
<S> <C> <C>
/s/ Frederick M. Bohen Director
- ------------------------------
Frederick M. Bohen March 23, 1998
/s/ G. Steven Farris Director
- ------------------------------
G. Steven Farris March 23, 1998
/s/ Randolph M. Ferlic Director
- ------------------------------
Randolph M. Ferlic March 23, 1998
/s/ Eugene C. Fiedorek Director
- ------------------------------
Eugene C. Fiedorek March 23, 1998
/s/ W. Brooks Fields Director
- ------------------------------
W. Brooks Fields March 23, 1998
/s/ A.D. Frazier, Jr. Director
- ------------------------------
A.D. Frazier, Jr. March 23,1998
/s/ Stanley K. Hathaway Director
- ------------------------------
Stanley K. Hathaway March 23, 1998
/s/ John A. Kocur Director
- ------------------------------
John A. Kocur March 23, 1998
/s/ George D. Lawrence Jr. Director
- ------------------------------
George D. Lawrence Jr. March 23, 1998
/s/ Mary Ralph Lowe Director
- ------------------------------
Mary Ralph Lowe March 23, 1998
/s/ F.H. Merelli Director
- ------------------------------
F.H. Merelli March 23, 1998
/s/ Joseph A. Rice Director
- ------------------------------
Joseph A. Rice March 23, 1998
</TABLE>
<PAGE> 1
EXHIBIT 23.1
[Letterhead of Ryder Scott Company]
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, 1998.
/s/ Ryder Scott Company
/s/ Petroleum Engineers
Ryder Scott Company
Petroleum Engineers
Houston, Texas
March 18, 1998
<TABLE> <S> <C>
<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-END> DEC-31-1997
<CASH> 691,797
<SECURITIES> 0
<RECEIVABLES> 1,756,180
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 2,519,997
<PP&E> 166,397,087
<DEPRECIATION> 158,392,914
<TOTAL-ASSETS> 10,524,170
<CURRENT-LIABILITIES> 1,877,180
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 8,646,990
<TOTAL-LIABILITY-AND-EQUITY> 10,524,170
<SALES> 12,066,643
<TOTAL-REVENUES> 12,225,647
<CGS> 3,428,671
<TOTAL-COSTS> 3,428,671
<OTHER-EXPENSES> 552,818
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 12,818
<INCOME-PRETAX> 8,244,158
<INCOME-TAX> 0
<INCOME-CONTINUING> 8,244,158
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 8,244,158
<EPS-PRIMARY> 5,260
<EPS-DILUTED> 5,260
</TABLE>
