APACHE OFFSHORE INVESTMENT PARTNERSHIP - FORM 10-Q - November 1, 2018

Attached files

file filename
EX-32.1 - EXHIBIT 32.1 - APACHE OFFSHORE INVESTMENT PARTNERSHIPaoipq32018ex321.htm
EX-31.2 - EXHIBIT 31.2 - APACHE OFFSHORE INVESTMENT PARTNERSHIPaoipq32018ex312.htm
EX-31.1 - EXHIBIT 31.1 - APACHE OFFSHORE INVESTMENT PARTNERSHIPaoipq32018ex311.htm


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
  ________________________________________________________________
FORM 10-Q
  ________________________________________________________________
(Mark One)
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2018
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
(Exact name of registrant as specified in its charter)
Delaware
 
41-1464066
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
One Post Oak Central, 2000 Post Oak Boulevard, Suite 100, Houston, Texas 77056-4400
(Address of principal executive offices)
Registrant’s telephone number, including area code: (713) 296-6000
 ________________________________________________________________
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ý    No  ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  ý    No  ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer
¨
Accelerated filer
¨
Non-accelerated filer
¨ (Do not check if a smaller reporting company)
Smaller reporting company
ý
 
 
Emerging growth company
¨
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨ 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  ý
Number of registrant's units outstanding as of September 30, 2018
1,022









Forward-Looking Statements and Risk
This report includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included or incorporated by reference in this report, including, without limitation, statements regarding our future financial position, business strategy, budgets, projected revenues, projected costs and plans, and objectives of management for future operations, are forward-looking statements. Such forward-looking statements are based on our examination of historical operating trends, the information that was used to prepare our estimate of proved reserves as of December 31, 2017, and other data in our possession or available from third parties. In addition, forward-looking statements generally can be identified by the use of forward-looking terminology such as “may,” “will,” “expect,” “intend,” “project,” “estimate,” “anticipate,” “believe,” or “continue” or similar terminology. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will prove to have been correct. Important factors that could cause actual results to differ materially from our expectations include, but are not limited to, our assumptions about:
•
the market prices of oil, natural gas, NGLs and other products or services;
•
the supply and demand for oil, natural gas, NGLs and other products or services;
•
pipeline and gathering system capacity;
•
production and reserve levels;
•
drilling risks;
•
economic and competitive conditions;
•
the availability of capital resources;
•
capital expenditure and other contractual obligations;
•
weather conditions;
•
inflation rates;
•
the availability of goods and services;
•
legislative or regulatory changes, including environmental regulation;
•
terrorism and cyber-attacks;
•
capital markets and related risks such as general credit, liquidity, market, and interest-rate risks; and
•
other factors disclosed under Item 1A – “Risk Factors,” Item 2 – “Properties — Estimated Proved Reserves and Future Net Cash Flows,” Item 7 – “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” Item 7A – “Quantitative and Qualitative Disclosures About Market Risk” and elsewhere in our most recently filed Form 10-K.
All subsequent written and oral forward-looking statements attributable to the Partnership, or persons acting on its behalf, are expressly qualified in their entirety by the cautionary statements. We assume no duty to update or revise our forward-looking statements based on changes in internal estimates or expectations or otherwise.




PART I — FINANCIAL INFORMATION

ITEM 1.    FINANCIAL STATEMENTS

APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF CONSOLIDATED OPERATIONS
(Unaudited)
 
For the Quarter Ended September 30,
 
For the Nine Months Ended September 30,
 
2018
 
2017
 
2018
 
2017
REVENUES:
 
 
 
 
 
 
 
Oil and gas sales
$
383,112

 
$
239,513

 
$
1,094,632

 
$
723,404

Interest income
22,843

 
10,024

 
55,787

 
20,833

 
405,955

 
249,537

 
1,150,419

 
744,237

EXPENSES:
 
 
 
 
 
 
 
Depreciation, depletion and amortization
75,787

 
67,187

 
234,894

 
207,451

Asset retirement obligation accretion
23,050

 
26,473

 
75,936

 
78,278

Lease operating expenses
105,772

 
113,133

 
353,108

 
421,583

Gathering and transportation costs
4,270

 
(5,111
)
 
13,530

 
(2,342
)
Administrative
80,799

 
78,849

 
242,401

 
236,543

 
289,678

 
280,531

 
919,869

 
941,513

NET INCOME (LOSS)
$
116,277

 
$
(30,994
)
 
$
230,550

 
$
(197,276
)
NET INCOME (LOSS) ALLOCATED TO:
 
 
 
 
 
 
 
Managing Partner
$
33,373

 
$
5,279

 
$
80,827

 
$
(3,041
)
Investing Partners
82,904

 
(36,273
)
 
149,723

 
(194,235
)
 
$
116,277

 
$
(30,994
)
 
$
230,550

 
$
(197,276
)
NET INCOME (LOSS) PER INVESTING PARTNER UNIT
$
81

 
$
(36
)
 
$
147

 
$
(190
)
WEIGHTED AVERAGE INVESTING PARTNER UNITS OUTSTANDING
1,021.5

 
1,021.5

 
1,021.5

 
1,021.5

The accompanying notes to consolidated financial statements
are an integral part of this statement.

1


APACHE OFFSHORE INVESTMENT PARTNERSHIP
STATEMENT OF CONSOLIDATED CASH FLOWS
(Unaudited)
 
For the Nine Months Ended September 30,
 
2018
 
2017
CASH FLOWS FROM OPERATING ACTIVITIES:
 
 
 
Net income (loss)
$
230,550

 
$
(197,276
)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
 
 
 
Depreciation, depletion and amortization
234,894

 
207,451

Asset retirement obligation accretion
75,936

 
78,278

Changes in operating assets and liabilities:
 
 
 
Accrued revenues receivable
(36,255
)
 
27,979

Receivable from/payable to Apache Corporation
2,128

 
3,631

Accrued operating expenses
(9,441
)
 
(5,800
)
Asset retirement obligation
(268,212
)
 
(1,319
)
Net cash provided by operating activities
229,600

 
112,944

CASH FLOWS FROM INVESTING ACTIVITIES:
 
 
 
Additions to oil and gas properties
(158,445
)
 
(36,113
)
Net cash used in investing activities
(158,445
)
 
(36,113
)
CASH FLOWS FROM FINANCING ACTIVITIES:
 
 
 
Distributions to Managing Partner
(46,831
)
 
(16,333
)
Net cash used in financing activities
(46,831
)
 
(16,333
)
NET INCREASE IN CASH AND CASH EQUIVALENTS
24,324

 
60,498

CASH AND CASH EQUIVALENTS, BEGINNING OF YEAR
5,117,485

 
5,035,668

CASH AND CASH EQUIVALENTS, END OF PERIOD
$
5,141,809

 
$
5,096,166

The accompanying notes to consolidated financial statements
are an integral part of this statement.

2


APACHE OFFSHORE INVESTMENT PARTNERSHIP
CONSOLIDATED BALANCE SHEET
(Unaudited) 
 
September 30, 2018
 
December 31, 2017
ASSETS
 
 
 
CURRENT ASSETS:
 
 
 
Cash and cash equivalents
$
5,141,809

 
$
5,117,485

Accrued revenues receivable
129,136

 
92,881

 
5,270,945

 
5,210,366

OIL AND GAS PROPERTIES, on the basis of full cost accounting:
 
 
 
Proved properties
195,327,296

 
195,005,011

Less – Accumulated depreciation, depletion and amortization
(191,132,750
)
 
(190,897,856
)
 
4,194,546

 
4,107,155

 
$
9,465,491

 
$
9,317,521

LIABILITIES AND PARTNERS’ CAPITAL
 
 
 
CURRENT LIABILITIES:
 
 
 
Payable to Apache Corporation
$
5,529

 
$
3,401

Asset retirement obligation
479,249

 
544,939

Accrued operating expenses
91,414

 
100,855

Accrued development costs
87,892

 
141,373

 
664,084

 
790,568

ASSET RETIREMENT OBLIGATION
1,335,063

 
1,244,328

PARTNERS’ CAPITAL:
 
 
 
Managing Partner
453,572

 
419,576

Investing Partners (1,021.5 units outstanding)
7,012,772

 
6,863,049

 
7,466,344

 
7,282,625

 
$
9,465,491

 
$
9,317,521

The accompanying notes to consolidated financial statements
are an integral part of this statement.

3


APACHE OFFSHORE INVESTMENT PARTNERSHIP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Apache Offshore Investment Partnership, a Delaware general partnership (the Investment Partnership), was formed on October 31, 1983, consisting of Apache Corporation, a Delaware corporation (Apache or the Managing Partner), as Managing Partner and public investors (the Investing Partners). The Investment Partnership invested its entire capital in Apache Offshore Petroleum Limited Partnership, a Delaware limited partnership (the Operating Partnership). The primary business of the Investment Partnership is to serve as the sole limited partner of the Operating Partnership. The accompanying financial statements include the accounts of both the Investment Partnership and the Operating Partnership. The term “Partnership,” as used herein, refers to the Investment Partnership or the Operating Partnership, as the case may be.
These financial statements have been prepared by the Partnership, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). They reflect all adjustments that are, in the opinion of management, necessary for a fair statement of the results for the interim periods, on a basis consistent with the annual audited financial statements, with the exception of recently adopted accounting pronouncements discussed below. All such adjustments are of a normal, recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (U.S. GAAP) have been omitted pursuant to such rules and regulations, although the Partnership believes that the disclosures are adequate to make the information presented not misleading. These financial statements should be read in conjunction with the Partnership’s Annual Report on Form 10-K for the fiscal year ended December 31, 2017, which contains a summary of the Partnership’s significant accounting policies and other disclosures.
1.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
As of September 30, 2018, the Partnership’s significant accounting policies are consistent with those discussed in Note 2 of its consolidated financial statements contained in the Annual Report on Form 10-K for the fiscal year ended December 31, 2017, with the exception of Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers (Topic 606)” (see “Revenue Recognition” section in this Note 1 below).
Use of Estimates
The preparation of financial statements in conformity with U.S. GAAP 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. 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 and the assessment of asset retirement obligations. Actual results could differ from those estimates.
Oil and Gas Property
The Partnership follows the full-cost method of accounting for its oil and gas property. Under this method of accounting, all costs incurred for both successful and unsuccessful exploration and development activities, and oil and gas property acquisitions are capitalized. The net book value of oil and gas properties may not exceed a calculated “ceiling.” The ceiling limitation is the estimated future net cash flows from proved oil and gas reserves, discounted at 10 percent per annum. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months, held flat for the life of the production, except where prices are defined by contractual arrangements. For a discussion of the calculation of estimated future net cash flows, please refer to Note 10—Supplemental Oil and Gas Disclosures to the consolidated financial statements contained in the Partnership’s Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Any excess of the net book value of proved oil and gas properties over the ceiling is charged to expense and reflected as “Additional depreciation, depletion and amortization” in the accompanying statement of consolidated operations. Such limitations are tested quarterly. The Partnership had no write-downs of the carrying value of its proved oil and gas properties during the third quarter and first nine months of 2018 and 2017.

4


Revenue Recognition
On January 1, 2018, the Partnership adopted Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers (ASC 606),” using the modified retrospective method. The Partnership elected to evaluate all contracts at the date of initial application. There was no impact to the opening balance of retained earnings as a result of the adoption, and the new standard is not anticipated to impact the Partnership’s net earnings on an ongoing basis.

The Partnership applies the provisions of ASC 606 for revenue recognition to contracts with customers. Sales of crude oil, natural gas, and natural gas liquids (NGLs) are included in revenue when production is sold to a customer in fulfillment of performance obligations under the terms of agreed contracts. Performance obligations primarily comprise delivery of oil, gas, or NGLs at a delivery point, as negotiated within each contract. Each barrel of oil, MMBtu of natural gas, or other unit of measure is separately identifiable and represents a distinct performance obligation to which the transaction price is allocated. Performance obligations are satisfied at a point in time once control of the product has been transferred to the customer. The Partnership considers a variety of facts and circumstances in assessing the point of control transfer, including but not limited to: whether the purchaser can direct the use of the hydrocarbons, the transfer of significant risks and rewards, the Partnership’s right to payment, and transfer of legal title. In each case, the term between delivery and when payments are due is not significant. For the three and nine months ended September 30, 2018, revenues from customers totaled $383,112 and $1,094,632, respectively.

Apache, as Managing Partner of the Partnership, markets the Partnership’s share of oil production from South Timbalier 295, the Partnership’s largest source of production. Apache primarily markets to major oil companies, marketing and transportation companies, and refiners at current index prices, adjusted for quality, transportation, and market reflective differentials. The Partnership markets all other production under the joint operating agreements with the operator of its properties. The operator seeks and negotiates oil and gas marketing arrangements with various marketers and purchasers. These contracts provide for sales that are priced at prevailing market prices.

The Partnership records trade accounts receivable for its unconditional rights to consideration arising under sales contracts with customers. The carrying value of such receivables, net of the allowance for doubtful accounts, represents estimated net realizable value. The Partnership routinely assesses the collectability of all material trade and other receivables. The Partnership accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Receivables from contracts with customers, net of allowance for doubtful accounts, totaled $129,136 and $92,881 as of September 30, 2018, and December 31, 2017, respectively.

The Partnership has concluded that disaggregating revenue by product appropriately depicts how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. The table below presents the total oil, gas, and NGLs revenues of the Partnership for the three and nine months ended September 30, 2018 and 2017:
 
 
For the Quarter Ended September 30,
 
For the Nine Months Ended September 30,
 
 
2018
 
2017
 
2018
 
2017
Oil
 
$
340,907

 
$
203,243

 
$
978,408

 
$
592,870

Gas
 
29,635

 
31,005

 
84,969

 
119,552

NGLs
 
12,570

 
5,265

 
31,255

 
10,982

Total Oil and Gas Revenue
 
$
383,112

 
$
239,513

 
$
1,094,632

 
$
723,404


Practical Expedients and Exemptions

The Partnership does not disclose the value of unsatisfied performance obligations for contracts with an original expected length of one year or less or contracts for which variable consideration is allocated entirely to a wholly unsatisfied performance obligation.

The Partnership will utilize the practical expedient to expense incremental costs of obtaining a contract if the expected amortization period is one year or less. Costs to obtain a contract with expected amortization periods of greater than one year will be recorded as an asset and will be recognized in accordance with ASC 340, “Other Assets and Deferred Costs.” Currently, the Partnership does not have contract assets related to incremental costs to obtain a contract.

5


New Pronouncements Issued But Not Yet Adopted
In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842),” requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018. Early adoption is permitted; however, the Partnership does not intend to early adopt. In January 2018, the FASB issued ASU 2018-01, which permits an entity an optional election to not evaluate under ASU 2016-02 those existing or expired land easements that were not previously accounted for as leases prior to the adoption of ASU 2016-02. In July 2018, the FASB issued ASU 2018-11, which adds a transition option permitting entities to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the consolidated financial statements. Under this transition option, comparative reporting would not be required and the provisions of the standard would be applied prospectively to leases in effect at the date of adoption. The Partnership intends to elect both transitional practical expedients. The Partnership does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.
2.    RECEIVABLE FROM / PAYABLE TO APACHE CORPORATION
The receivable from/payable to Apache represents the net result of the Investing Partners’ revenue received and expenditures paid in the current month. Generally, cash in this amount will be paid by Apache to the Partnership or transferred to Apache in the month after the Partnership’s transactions are processed and the net results of operations are determined.
3.    RIGHT OF PRESENTMENT
As provided in the Partnership Agreement, as amended (the “Amended Partnership Agreement”), a first right of presentment valuation was computed during the first quarter of 2018. The per-unit value was determined to be $10,342 based on the valuation date of December 31, 2017. A second right of presentment valuation was computed during October 2018, and the per-unit value was determined to be $9,752 based on a valuation date of June 30, 2018. The Partnership did not repurchase any Investing Partner Units (Units) during the first nine months of 2018, and is not expected to purchase any Units in the fourth quarter of 2018. The per-unit right of presentment value computed during the first quarter of 2017 was determined to be $9,242 based on the valuation date of December 31, 2016, and the second per-unit right of presentment in 2017 was $8,794 based on a valuation date of June 30, 2017. The Partnership also did not repurchase any Units during the first nine months of 2017. Pursuant to the Amended Partnership Agreement, the Partnership has no obligation to purchase any Units presented to the extent it determines that it has insufficient funds for such purchases.
4.    ASSET RETIREMENT OBLIGATIONS
The following table describes the changes to the Partnership’s asset retirement obligation liability for the first nine months of 2018:
Asset retirement obligation at December 31, 2017
$
1,789,267

Accretion expense
75,936

Liabilities settled
(356,106
)
Revisions in estimated liabilities
305,215

Asset retirement obligation at September 30, 2018
1,814,312

Less current portion
(479,249
)
Asset retirement obligation, long-term
$
1,335,063

Decommissioning and abandonment activity has begun as a result of the 2018 lease expiration at Ship Shoal 258/259, and is expected to be completed within the next two years. The operator has experienced challenges related to the plugging of the wells at Ship Shoal 258/259, and the Partnership has revised the field’s estimated abandonment obligation based on projected costs and current accumulated costs as of September 30, 2018.
5.    FAIR VALUE MEASUREMENTS
Certain assets and liabilities are reported at fair value on a recurring basis in the Partnership’s consolidated balance sheet. As of September 30, 2018 and December 31, 2017, the carrying amounts of the Partnership’s current assets and current liabilities approximated fair value because of the short-term nature or maturity of these instruments.
The Partnership did not use derivative financial instruments or otherwise engage in hedging activities during the nine months ended September 30, 2018 and 2017.

6


ITEM 2.    MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion relates to Apache Offshore Investment Partnership (the Partnership) and should be read in conjunction with the Partnership’s consolidated financial statements and accompanying notes included under Part I, Item 1, “Financial Statements” of this Quarterly Report on Form 10-Q, as well as its consolidated financial statements, accompanying notes and related Management’s Discussion and Analysis of Financial Condition and Results of Operations, included in the Partnership’s Annual Report on Form 10-K for the fiscal year ended December 31, 2017.
The Partnership’s business is participation in oil and gas development and production activities on federal lease tracts in the Gulf of Mexico, offshore Louisiana.
Results of Operations
Net Income and Revenue
The Partnership reported net income of $116,277 ($81 per Investing Partner Unit) for the third quarter of 2018 compared to a net loss of $30,994 ($36 per Investing Partner Unit) in the third quarter of 2017. For the first nine months of 2018, the Partnership reported net income of $230,550 ($147 per Investing Partner Unit) compared to a net loss of $197,276 ($190 per Investing Partner Unit) in the first nine months of 2017.
Total revenues in the third quarter of 2018 increased 63 percent from the third quarter of 2017 on higher oil production and prices. Total revenues in the first nine months of 2018 increased 55 percent from the first nine months of 2017 on higher oil production and prices. The Partnership’s crude oil, natural gas, and NGL production volume and price information is summarized in the following table (gas volumes are presented in thousand cubic feet (Mcf) per day):
 
 
For the Quarter Ended September 30,
 
For the Nine Months Ended September 30,
 
2018
 
2017
 
Increase
(Decrease)
 
2018
 
2017
 
Increase
(Decrease)
Gas volume – Mcf per day
107

 
111

 
(4
)%
 
103

 
121

 
(15
)%
Average gas price – per Mcf
$
3.01

 
$
3.04

 
(1
)%
 
$
3.03

 
$
3.61

 
(16
)%
Oil volume – barrels per day
53

 
48

 
10
 %
 
54

 
46

 
17
 %
Average oil price – per barrel
$
70.45

 
$
45.92

 
53
 %
 
$
66.42

 
$
47.34

 
40
 %
NGL volume – barrels per day
4

 
3

 
33
 %
 
4

 
2

 
100
 %
Average NGL price – per barrel
$
34.65

 
$
19.32

 
79
 %
 
$
26.94

 
$
22.72

 
19
 %
Oil and Gas Sales
The Partnership’s crude oil sales for the third quarter of 2018 totaled $340,907 compared to $203,243 in the third quarter of 2017. The Partnership’s average realized oil price in the third quarter of 2018 increased $24.53 per barrel from the third quarter of 2017, increasing sales by $108,577. Crude oil volumes increased to 53 barrels per day in the third quarter of 2018, compared to 48 barrels per day in the prior year period as a result of a re-completed well coming on-line at South Timbalier 295 during the first quarter of 2018 and the completion of pipeline reroute work at South Timbalier 295 that began during the second quarter of 2017. The increase in production raised oil sales by $29,087.
Natural gas sales of $29,635 were recognized in the third quarter of 2018, down 4 percent from the amount realized for the equivalent 2017 period. The Partnership’s average realized natural gas price for the quarter decreased $0.03 per Mcf, or 1 percent, from the third quarter of 2017, decreasing sales by $288. Natural gas volumes also decreased 4 percent from the third quarter of 2017, reducing sales by $1,082. The decrease in production is the result of natural depletion.
Crude oil sales for the first nine months of 2018 totaled $978,408 compared to $592,870 from the first nine months of 2017. The Partnership’s average realized oil price for the first nine months of 2018 increased $19.08 per barrel from the first nine months of 2017, increasing sales by $238,958. The Partnership’s crude oil volumes increased to 54 barrels per day during the first nine months of 2018, compared to 46 barrels per day in the prior year period as a result of a re-completed well coming on-line at South Timbalier 295 during the first quarter of 2018 and the completion of pipeline reroute work at South Timbalier 295 that began during the second quarter of 2017. The increase in production raised oil sales by $146,580.

7


Natural gas sales of $84,969 were recognized in the first nine months of 2018, down 29 percent from the amount realized for the equivalent 2017 period. The Partnership’s average realized natural gas price for the first nine months decreased $0.58, or 16 percent, from the first nine months of 2017, decreasing sales by $19,189. A decrease in natural gas volumes of 18 Mcf per day, or 15 percent, during the first nine months of 2018 compared to the same period a year ago reduced sales by $15,395. The Partnership’s decrease in gas production in the first nine months of 2018 primarily reflected the third-party pipeline shut-down at Ship Shoal 258/259, which began at the end of the first quarter of 2017. During the first quarter of 2018, the lease at Ship Shoal 258/259 expired. The third-party operator determined that it was uneconomical to bring production back on-line and, therefore, has decided to not renew the lease.
NGL sales for the first nine months of 2018 increased $20,274, or 185 percent, compared to the same prior year period, as a result of higher NGL prices and production. NGL prices averaged $26.94, up 19 percent compared to the first nine months of 2017. The Partnership sold 4 barrels per day of NGLs in the first nine months of 2018, up from 2 barrels per day in the first nine months of 2017.
Since the Partnership does not anticipate acquiring additional acreage or conducting exploratory drilling on leases in which it currently holds an interest, declines in oil and gas production can be expected in future periods as a result of natural depletion. Also, given the small number of producing wells owned by the Partnership and exposure to inclement weather and pipeline interruptions in the Gulf of Mexico, the Partnership’s production during the remainder of 2018 and beyond may be subject to more volatility than those companies with a larger or more diversified property portfolio.
Operating Expenses
The Partnership’s recurring depreciation, depletion and amortization (DD&A) expense for both the third quarter and first nine months of 2018 increased 13 percent compared to the same prior year periods. DD&A expense increased as a result of a higher DD&A rate from increased oil production, primarily associated with shut-in production at South Timbalier 295 during the prior year. Recurring DD&A expense expressed as a percentage of oil and gas sales was approximately 20 percent and 21 percent for the third quarter and first nine months of 2018, respectively, and 28 percent and 29 percent for the third quarter and first nine months of 2017, respectively.
Under the full cost method of accounting, the Partnership is required to review the carrying value of its proved oil and gas properties each quarter. Under these rules, capitalized costs of oil and gas properties, net of accumulated DD&A, may not exceed the present value of estimated future net cash flows from proved oil and gas reserves discounted at 10 percent per annum. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months, held flat for the life of the production, except where prices are defined by contractual arrangements. The Partnership had no write-downs of the carrying value of its oil and gas properties during the third quarter and first nine months of 2018 and 2017. If commodity prices experience declines to levels lower than prices realized in the previous 12 months, the Partnership may be required to recognize non-cash write-downs of the carrying value of its oil and gas properties in future periods, which would be reflected as additional DD&A expense on the statement of consolidated operations.
Lease operating expenses (LOE) for the third quarter of 2018 of $105,772 decreased 7 percent from the third quarter of 2017, reflecting the impact of the expired lease at Ship Shoal 258/259. LOE for the first nine months of 2018 of $353,108 decreased 16 percent from the same prior year period. Gathering and transportation costs for the delivery of oil and gas have normalized following prior year pipeline interruptions at South Timbalier 295, totaling $4,270 and $13,530 in the third quarter and first nine months of 2018, respectively.

8


Capital Resources and Liquidity
The Partnership’s primary capital resource is net cash provided by operating activities. During the first nine months of 2018 and 2017, the Partnership had $229,600 and $112,944, respectively, of positive cash flows from operating activities. The increase reflected the impact of higher oil production and prices.
At September 30, 2018, the Partnership had approximately $5.1 million in cash and cash equivalents, slightly up from December 31, 2017. The Partnership’s goal is to maintain cash and cash equivalents at least sufficient to cover the undiscounted value of its future asset retirement obligation liability. The Partnership also plans to reserve funds for repairs which may disrupt the Partnership’s production and for future recompletion operations.
The Partnership’s future financial condition, results of operations, and cash from operating activities will largely depend upon prices received for its oil and natural gas production. 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 and economic conditions, the foreign and domestic supply of oil and natural gas, the price of foreign imports, the level of consumer demand, weather, and the price and availability of alternative fuels.
The Partnership’s oil and gas reserves and production will also significantly impact future results of operations and cash from operating activities. The Partnership’s production is subject to fluctuations in response to remaining quantities of oil and gas reserves, weather, pipeline capacity, consumer demand, mechanical performance and workover, recompletion and drilling activities. Declines in oil and gas production can be expected in future years as a result of normal depletion and the non-participation in acquisition or exploration activities by the Partnership. Based on production estimates from independent engineers and current market conditions, the Partnership forecasts it will be able to meet its liquidity needs for routine operations in 2018 and 2019. The Partnership will reduce capital expenditures and distributions to partners as cash from operating activities declines.
In the event that future short-term operating cash requirements are greater than the Partnership’s financial resources, the Partnership may seek short-term, interest-bearing advances from the Managing Partner as needed. The Managing Partner, however, is not obligated to make loans to the Partnership.


9


Capital Commitments
The Partnership’s primary needs for cash are for operating expenses, drilling and recompletion expenditures, future dismantlement and abandonment costs, distributions to Investing Partners, and the purchase of Units offered by Investing Partners under the right of presentment. To the extent there is discretion, the Partnership allocates available capital to investment in the Partnership’s properties so as to maximize production and resultant cash flow. The Partnership had no outstanding debt or lease commitments at September 30, 2018. The Partnership did not have any contractual obligations as of September 30, 2018, other than the liability for decommissioning and abandonment costs of its oil and gas properties. The Partnership has recorded a separate liability for the present value of this asset retirement obligation as discussed in the notes to the financial statements included in the Partnership’s latest annual report on Form 10-K.
During the first nine months of 2018, the Partnership had cash outlays for capital expenditures totaling $158,445, primarily for pipeline reroute and recompletion projects at South Timbalier 295. Based on information supplied by the operators of the properties, the Partnership anticipates total capital expenditures of less than $100,000 during the remainder of 2018 for activity at South Timbalier 295. Additionally, approximately $500,000 of current abandonment obligations are estimated to be spent within the next twelve months to remove platforms and abandon shut-in wells at Ship Shoal 258/259 and to remove the platforms at North Padre Island 969/976. Decommissioning and abandonment activity has begun at Ship Shoal 258/259 and is expected to be completed within the next two years. The operator has experienced challenges related to the plugging of the wells at Ship Shoal 258/259, and the Partnership has revised the field’s estimated abandonment obligation based on projected costs and current accumulated costs as of September 30, 2018. The abandonment activity at North Padre Island 969/976 was originally scheduled to commence in 2016, but has been deferred to 2019 pending approval from regulators. Such estimates may change based on realized oil and gas prices, drilling and recompletion results, rates charged by contractors, or changes by the operator to their development or abandonment plans.
Because of fluctuations in production levels over the past year, the expiration of the lease at Ship Shoal 258/259, and the need to reserve cash for future asset retirement obligations, no distributions were made to Investing Partners during the first nine months of 2018. The Partnership also made no distribution to Investing Partners during the first nine months of 2017 as a result of low commodity prices and third-party pipeline interruptions.
The amount of future distributions will be dependent on actual and expected production levels, realized and anticipated oil and gas prices, expected recompletion expenditures, and prudent cash reserves for future dismantlement and abandonment costs that will be incurred after the Partnership’s reserves are depleted. The Partnership’s goal is to maintain cash and cash equivalents in the Partnership at least sufficient to cover the undiscounted value of its future asset retirement obligations. The Partnership will review available cash balances, any development or abandonment plans submitted by the operators of the Partnership’s properties, and the factors noted above to determine whether there are sufficient funds to make a distribution to Investing Partners during the first half of 2019.
As provided in the Amended Partnership Agreement, a first right of presentment valuation was computed during the first quarter of 2018. The per-unit value was determined to be $10,342 based on the valuation date of December 31, 2017. A second right of presentment valuation was computed during October 2018, and the per-unit value was determined to be $9,752 based on a valuation date of June 30, 2018. The Partnership did not repurchase any Investing Partner Units (Units) during the first nine months of 2018 as a result of the Partnership’s limited amount of cash available for discretionary purposes, and is not expected to purchase any Units in the fourth quarter of 2018. Pursuant to the Amended Partnership Agreement, the Partnership has no obligation to repurchase any Units presented to the extent it determines that it has insufficient funds for such purchases.

10


ITEM 3.     QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Commodity Risk
The Partnership’s major market risk exposure is in the pricing applicable to its oil and gas production. Realized pricing is primarily driven by the prevailing worldwide price for crude oil and spot prices applicable to its natural gas production. Prices received for the Partnership’s crude oil, natural gas, and NGLs have historically been and continue to be very volatile because of unpredictable events such as economic growth or retraction, weather, political climate, and global supply and demand. The Partnership did not use derivative financial instruments or otherwise engage in hedging activities during the first nine months of 2018 or 2017.
The information set forth under “Commodity Risk” in Item 7A of the Partnership’s Form 10-K for the year ended December 31, 2017, is incorporated by reference. Information about market risks for the current quarter is not materially different.

ITEM 4.    CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
John J. Christmann IV, the Managing Partner’s Chief Executive Officer and President (in his capacity as principal executive officer), and Stephen J. Riney, the Managing Partner’s Executive Vice President and Chief Financial Officer (in his capacity as principal financial officer), evaluated the effectiveness of the Partnership’s disclosure controls and procedures as of September 30, 2018, the end of the period covered by this report. Based on that evaluation and as of the date of that evaluation, these officers concluded that the Partnership’s disclosure controls and procedures were effective, providing effective means to ensure that the information it is required to disclose under applicable laws and regulations is recorded, processed, summarized and reported within the time periods specified under the Commission’s rules and forms and communicated to our management, including the Managing Partner’s principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure.
Changes in Internal Control over Financial Reporting
There was no change in our internal controls over financial reporting during the period covered by this quarterly report on Form 10-Q that materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.


11


PART II — OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS
None.

ITEM 1A.    RISK FACTORS
During the nine months ended September 30, 2018, there were no material changes from the risk factors as previously disclosed in the Partnership’s Form 10-K for the year ended December 31, 2017.

ITEM 2.    UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.

ITEM 3.    DEFAULTS UPON SENIOR SECURITIES
None.

ITEM 4.    MINE SAFETY DISCLOSURES
None.

ITEM 5.    OTHER INFORMATION
None.

ITEM 6.    EXHIBITS
p3.1
 
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).
p3.2
 
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).
p3.3
 
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).
*31.1
 
*31.2
 
*32.1
 
*101.INS
 
XBRL Instance Document.
*101.SCH
 
XBRL Taxonomy Schema Document.
*101.CAL
 
XBRL Calculation Linkbase Document.
*101.DEF
 
XBRL Definition Linkbase Document.
*101.LAB
 
XBRL Label Linkbase Document.
*101.PRE
 
XBRL Presentation Linkbase Document.
*    Filed herewith.
P    Filed previously in paper format.

12


SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
 
 
APACHE OFFSHORE INVESTMENT PARTNERSHIP
 
 
By:
 
Apache Corporation, Managing Partner
 
 
 
Dated:
November 1, 2018
/s/ Stephen J. Riney
 
 
Stephen J. Riney
 
 
Executive Vice President and Chief Financial Officer
 
 
(principal financial officer) of Apache Corporation,
 
 
Managing Partner
 
 
 
Dated:
November 1, 2018
/s/ Rebecca A. Hoyt
 
 
Rebecca A. Hoyt
 
 
Senior Vice President, Chief Accounting Officer
 
 
and Controller (principal accounting officer)
 
 
of Apache Corporation, Managing Partner

13

APACHE OFFSHORE INVESTMENT PARTNERSHIP Reports