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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 10-Q
 
☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2020
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: 001-38212

Oasis Midstream Partners LP
(Exact name of registrant as specified in its charter)

Delaware   47-1208855
(State or other jurisdiction of
incorporation or organization) 		  (I.R.S. Employer
Identification No.)
1001 Fannin Street, Suite 1500
Houston, Texas
  77002
(Address of principal executive offices)   (Zip Code)
(281) 404-9500
(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the act:
Title of each class Trading Symbol(s) Name of each exchange on which registered
Common units representing limited partner interests OMP The NASDAQ Stock Market LLC

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  ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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 such files).    Yes ☒  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 ☐ Smaller reporting company ☐
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 ☒

At July 31, 2020, there were 33,811,366 units representing limited partner interests (consisting of 20,061,366 common units and 13,750,000 subordinated units) outstanding.



OASIS MIDSTREAM PARTNERS LP
TABLE OF CONTENTS
  Page
1
1
1
Condensed Consolidated Statements of Operations for the Three and Six Months Ended June 30, 2020 and 2019
2
3
4
5
5
6
8
9
10
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13
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18
32
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42



PART I — FINANCIAL INFORMATION
Item 1. — Financial Statements (Unaudited)
OASIS MIDSTREAM PARTNERS LP
CONDENSED CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
June 30, 2020 December 31, 2019
(In thousands, except unit data)
ASSETS
Current assets
Cash and cash equivalents $ 27,141    $ 4,168   
Accounts receivable 7,448    5,969   
Accounts receivable – Oasis Petroleum 51,518    77,571   
Inventory 7,608    —   
Prepaid expenses 2,697    1,923   
Other current assets 1,674    138   
Total current assets 98,086    89,769   
Property, plant and equipment 1,182,552    1,155,503   
Less: accumulated depreciation, amortization and impairment (222,771)   (98,982)  
Total property, plant and equipment, net 959,781    1,056,521   
Operating lease right-of-use assets 3,709    5,207   
Other assets 2,616    3,172   
Total assets $ 1,064,192    $ 1,154,669   
LIABILITIES AND EQUITY
Current liabilities
Accounts payable $ 843    $ 2,478   
Accounts payable – Oasis Petroleum 24,010    27,139   
Accrued liabilities 26,399    50,210   
Accrued interest payable 28,496    508   
Current operating lease liabilities 2,524    3,005   
Other current liabilities 629    594   
Total current liabilities 82,901    83,934   
Long-term debt 487,500    458,500   
Asset retirement obligations 1,788    1,747   
Operating lease liabilities 1,210    2,216   
Other liabilities 5,094    3,644   
Total liabilities 578,493    550,041   
Equity
Limited partners
Common units (20,061,366 and 20,045,196 issued and outstanding at June 30, 2020 and December 31, 2019, respectively)
167,292    225,339   
Subordinated units (13,750,000 units issued and outstanding at June 30, 2020 and December 31, 2019)
26,109    66,005   
General Partner 1,027    1,026   
Total partners’ equity
194,428    292,370   
Non-controlling interests 291,271    312,258   
Total equity 485,699    604,628   
Total liabilities and equity $ 1,064,192    $ 1,154,669   
The accompanying notes are an integral part of these condensed consolidated financial statements.
1
OASIS MIDSTREAM PARTNERS LP
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
Three Months Ended June 30, Six Months Ended June 30,
2020
2019(1)
2020
2019(1)
(In thousands, except per unit data)
Revenues
Midstream services – Oasis Petroleum $ 56,946    $ 74,211    $ 138,939    $ 151,274   
Midstream services – third parties 5,242    1,825    9,088    2,952   
Product sales – Oasis Petroleum 3,869    24,348    24,657    40,000   
Product sales – third parties 6    19    6    29   
Total revenues 66,063    100,403    172,690    194,255   
Operating expenses
Costs of product sales 2,215    12,022    10,647    20,087   
Operating and maintenance 14,508    17,276    31,348    36,966   
Depreciation and amortization 11,881    8,691    22,078    17,682   
Impairment 216    —    101,983    —   
General and administrative 9,286    7,834    17,737    16,557   
Total operating expenses 38,106    45,823    183,793    91,292   
Operating income (loss) 27,957    54,580    (11,103)   102,963   
Other expenses
Interest expense, net of capitalized interest (5,186)   (4,330)   (35,443)   (8,299)  
Other expenses (101)   (4)   (143)   (4)  
Total other expenses (5,287)   (4,334)   (35,586)   (8,303)  
Net income (loss) 22,670    50,246    (46,689)   94,660   
Less: Net income attributable to Delaware Predecessor —    1,211    —    2,286   
Less: Net income attributable to non-controlling interests 10,796    22,837    12,836    44,633   
Net income (loss) attributable to Oasis Midstream Partners LP 11,874    26,198    (59,525)   47,741   
Less: Net income attributable to General Partner 1,027    491    2,034    729   
Net income (loss) attributable to limited partners $ 10,847    $ 25,707    $ (61,559)   $ 47,012   
Earnings (loss) per limited partner unit (Note 12)
Common units – basic $ 0.32    $ 0.76    $ (1.82)   $ 1.39   
Common units – diluted 0.32    0.76    (1.82)   1.39   
Weighted average number of limited partners units outstanding (Note 12)
Common units – basic 20,045    20,024    20,043    20,020   
Common units – diluted 20,045    20,034    20,043    20,037   
__________________
(1)Retrospectively adjusted for the transfer of net assets between entities under common control. See Note 2 to our unaudited condensed consolidated financial statements.






The accompanying notes are an integral part of these condensed consolidated financial statements.
2
OASIS MIDSTREAM PARTNERS LP
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
(UNAUDITED)
Partnership
Delaware Predecessor Common Units Subordinated Units General Partner Non-controlling Interests Total
(In thousands)
Balance as of December 31, 2019 $ —    $ 225,339    $ 66,005    $ 1,026    $ 312,258    $ 604,628   
Contributions from non-controlling interests —    —    —    —    6,167    6,167   
Distributions to non-controlling interests —    —    —    —    (25,964)   (25,964)  
Distributions to unitholders —    (10,833)   (7,425)   (1,007)   —    (19,265)  
Equity-based compensation —    66    —    —    —    66   
Net income (loss) —    (42,947)   (29,460)   1,008    2,040    (69,359)  
Balance as of March 31, 2020 —    171,625    29,120    1,027    294,501    496,273   
Contributions from non-controlling interests —    —    —    —    309    309   
Distributions to non-controlling interests —    —    —    —    (14,335)   (14,335)  
Distributions to unitholders —    (10,833)   (7,425)   (1,027)   —    (19,285)  
Equity-based compensation —    67    —    —    —    67   
Net income —    6,433    4,414    1,027    10,796    22,670   
Balance as of June 30, 2020 $ —    $ 167,292    $ 26,109    $ 1,027    $ 291,271    $ 485,699   
Balance as of December 31, 2018 $ 6,227    $ 192,581    $ 45,937    $ 112    $ 312,815    $ 557,672   
Delaware Predecessor capital contributions, net(1)
4,902    —    —    —    —    4,902   
Contributions from non-controlling interests —    —    —    —    2,532    2,532   
Distributions to non-controlling interests —    —    —    —    (21,922)   (21,922)  
Distributions to unitholders —    (9,020)   (6,188)   (112)   —    (15,320)  
Equity-based compensation —    119    —    —    —    119   
Other —    2,881    (79)   —    (2,977)   (175)  
Net income(1)
1,075    12,630    8,675    238    21,796    44,414   
Balance as of March 31, 2019 12,204    199,191    48,345    238    312,244    572,222   
Delaware Predecessor capital contributions, net(1)
2,529    —    —    —    —    2,529   
Contributions from non-controlling interests —    —    —    —    1,709    1,709   
Distributions to non-controlling interests —    —    —    —    (21,659)   (21,659)  
Distributions to unitholders —    (9,421)   (6,463)   (238)   —    (16,122)  
Equity-based compensation —    100    —    —    —    100   
Other —    (102)   (115)   —    —    (217)  
Net income(1)
1,211    15,241    10,466    491    22,837    50,246   
Balance as of June 30, 2019 $ 15,944    $ 205,009    $ 52,233    $ 491    $ 315,131    $ 588,808   
__________________
(1)Retrospectively adjusted for the transfer of net assets between entities under common control. See Note 2 to our unaudited condensed consolidated financial statements.



The accompanying notes are an integral part of these condensed consolidated financial statements.
3
OASIS MIDSTREAM PARTNERS LP
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
Six Months Ended June 30,
2020
2019(1)
(In thousands)
Cash flows from operating activities:
Net income (loss) $ (46,689)   $ 94,660   
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 22,078    17,682   
Impairment 101,983    —   
Equity-based compensation expenses 133    219   
Deferred financing costs amortization and other 541    417   
Working capital and other changes:
Change in accounts receivable 24,575    (2,747)  
Change in inventory (7,637)   —   
Change in prepaid expenses (774)   150   
Change in accounts payable and accrued liabilities 18,915    5,722   
Change in other assets and liabilities, net 20    (399)  
Net cash provided by operating activities 113,145    115,704   
Cash flows from investing activities:
Capital expenditures (46,740)   (141,868)  
Net cash used in investing activities (46,740)   (141,868)  
Cash flows from financing activities:
Capital contributions from Delaware Predecessor, net —    7,431   
Capital contributions from non-controlling interests 6,476    4,241   
Distributions to non-controlling interests (40,299)   (43,581)  
Distributions to unitholders (38,550)   (31,442)  
Deferred financing costs —    (440)  
Proceeds from revolving credit facility 29,000    95,000   
Principal payments on revolving credit facility —    (5,000)  
Other (59)   (448)  
Net cash provided by (used in) financing activities (43,432)   25,761   
Increase (decrease) in cash and cash equivalents 22,973    (403)  
Cash:
Beginning of period 4,168    6,649   
End of period $ 27,141    $ 6,246   
Supplemental non-cash transactions:
Change in accrued capital expenditures $ (19,502)   $ (2,046)  
Change in asset retirement obligations 40    63   
__________________
(1)Retrospectively adjusted for the transfer of net assets between entities under common control. See Note 2 to our unaudited condensed consolidated financial statements.



The accompanying notes are an integral part of these condensed consolidated financial statements.
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OASIS MIDSTREAM PARTNERS LP
Notes to Condensed Consolidated Financial Statements (Unaudited)
1. Organization and Nature of Operations
Organization. Oasis Midstream Partners LP (the “Partnership”) is a growth-oriented, fee-based master limited partnership formed by its sponsor, Oasis Petroleum Inc. (together with its wholly-owned subsidiaries, “Oasis Petroleum”) to own, develop, operate and acquire a diversified portfolio of midstream assets in North America that are integral to the crude oil and natural gas operations of Oasis Petroleum and are strategically positioned to capture volumes from other producers.
The Partnership conducts its business through its ownership of development companies: Bighorn DevCo LLC (“Bighorn DevCo”), Bobcat DevCo LLC (“Bobcat DevCo”), Beartooth DevCo LLC (“Beartooth DevCo”) and Panther DevCo LLC (“Panther DevCo” and collectively with Bighorn DevCo, Bobcat DevCo and Beartooth DevCo, the “DevCos”). Bobcat DevCo and Beartooth DevCo are jointly-owned with Oasis Petroleum through its wholly-owned subsidiary Oasis Midstream Services LLC (“OMS”).
As of June 30, 2020, the Partnership’s assets and ownership interests in the DevCos were as follows:
DevCo Areas Served Service Lines Partnership Ownership
Bighorn DevCo Wild Basin
–Natural gas processing
–Crude oil stabilization
–Crude oil blending
–Crude oil and natural gas liquids storage
–Crude oil transportation
100.0%
Bobcat DevCo Wild Basin
–Natural gas gathering
–Natural gas compression
–Gas lift
–Crude oil gathering
–Produced and flowback water gathering
–Produced and flowback water disposal
35.3%
Beartooth DevCo Alger
Cottonwood
Hebron
Indian Hills
Red Bank
Wild Basin
–Produced and flowback water gathering
–Produced and flowback water disposal
–Freshwater supply and distribution
70.0%
Panther DevCo Delaware Basin
–Crude oil gathering
–Produced and flowback water gathering
–Produced and flowback water disposal

100%
Nature of business. The Partnership generates the majority of its revenues through 15-year, fee-based contractual arrangements with Oasis Petroleum for midstream services. These services include (i) gas gathering, compression, processing, gas lift and natural gas liquids (“NGLs”) storage services; (ii) crude oil gathering, stabilization, blending, storage and transportation services; (iii) produced and flowback water gathering and disposal services; and (iv) freshwater supply and distribution services. The revenue earned from these services is generally directly related to the volume of natural gas, crude oil, produced and flowback water and freshwater that flows through the Partnership’s systems.
The Partnership’s operations are supported by significant acreage dedications from Oasis Petroleum. In addition, the Partnership is party to a number of third-party agreements across all of its DevCos in which the Partnership has the right to provide its full suite of midstream services to support existing and future third-party volumes.
The Partnership is not a taxable entity for United States federal income tax purposes and is not subject to income tax in the majority of states in which the Partnership operates. As taxes are generally borne by its partners through the allocation of taxable income, the Partnership does not record deferred taxes related to the aggregate difference in the basis of its assets for financial and tax reporting purposes. The Partnership is subject to a Texas margin tax due to its operations in the Delaware Basin and recorded a de minimis state income tax provision for the three and six months ended June 30, 2020.
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2. Summary of Significant Accounting Policies
Basis of Presentation
The accompanying condensed consolidated financial statements of the Partnership have not been audited by the Partnership’s independent registered public accounting firm, except that the Condensed Consolidated Balance Sheet at December 31, 2019 is derived from audited financial statements. In the opinion of management, all adjustments, consisting of normal recurring adjustments necessary for fair statement of the Partnership’s financial position have been included. Management has made certain estimates and assumptions that affect reported amounts in the condensed consolidated financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results.
These interim financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Certain disclosures have been condensed or omitted from these financial statements. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the Partnership’s audited consolidated financial statements and notes thereto included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2019 (“2019 Annual Report”).
2019 Delaware Acquisition. On November 1, 2019, the Partnership entered into an agreement with Oasis Petroleum, pursuant to which Oasis Petroleum, through OMS (the “Delaware Predecessor”), agreed to assign to Panther DevCo, certain crude oil gathering and produced and flowback water gathering and disposal assets in the Delaware Basin (the “2019 Delaware Acquisition”). The 2019 Delaware Acquisition was accounted for as a transfer of net assets between entities under common control. As a result, the unaudited condensed consolidated financial statements for the period prior to the effective date of November 1, 2019 have been recast. These unaudited condensed consolidated financial statements include the results of the Delaware Predecessor for the three and six months ended June 30, 2019, which were prepared from Oasis Petroleum’s historical cost-basis accounts and may not necessarily be indicative of the actual results had the Partnership owned the assets during the reported periods.
Consolidation
The Partnership’s condensed consolidated financial statements include its accounts and the accounts of the DevCos, each of which is controlled by the Partnership through its general partner, OMP GP LLC (the “General Partner”). All intercompany balances and transactions have been eliminated upon consolidation.
Variable interest entity. The Partnership determined that Bobcat DevCo is a variable interest entity (“VIE”), since OMS’s equity at risk was established with non-substantive voting rights. As the Partnership has the authority to direct the activities that most significantly affect the economic performance of Bobcat DevCo, the Partnership is considered the primary beneficiary and consolidates Bobcat DevCo in its financial statements under the VIE consolidation model.
The Partnership determined that Bighorn DevCo, Beartooth DevCo and Panther DevCo are not VIEs and consolidates these entities in its financial statements under the voting interest consolidation model.
Non-controlling interests. The non-controlling interests represent OMS’s retained ownership interests in Bobcat DevCo and Beartooth DevCo of 64.7% and 30%, respectively, as of June 30, 2020.
Risks and Uncertainties
Concentrations of market and credit risk. The Partnership has limited direct exposure to risks associated with fluctuating commodity prices due to the nature of its business and its long-term, fixed-fee contractual arrangements with its existing customers, including Oasis Petroleum. However, to the extent that the Partnership’s future contractual arrangements with customers, including Oasis Petroleum or third parties, do not provide for fixed-fee structures, the Partnership may become subject to more substantial direct commodity price risk. In addition, in response to a prolonged low commodity price environment, the Partnership’s customers could seek to amend existing contractual arrangements to reduce the volumetric fees the Partnership charges.
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As a substantial majority of the Partnership’s revenues are derived from Oasis Petroleum, the Partnership is indirectly subject to risks associated with fluctuating commodity prices to the extent that lower commodity prices adversely affect Oasis Petroleum’s production, drilling schedule or financial condition. The markets for crude oil, natural gas and NGLs have been volatile, especially over the last several months and years. During the six months ended June 30, 2020, crude oil and NGL prices weakened to historical lows as a result of the demand impacts from the global novel coronavirus 2019 (“COVID-19”) pandemic, coupled with the supply impacts from actions of Saudi Arabia and Russia. Oasis Petroleum has expressed substantial doubt about its ability to continue to operate as a going concern. The Partnership is largely dependent on Oasis Petroleum as its most significant customer, and financial distress at Oasis Petroleum could have a material adverse effect on the Partnership’s results of operations.
COVID-19. The Partnership considered the impact of the ongoing COVID-19 pandemic on the assumptions and estimates used by management in the unaudited condensed consolidated financial statements for the reporting periods presented. As a result of lower forecasted throughput volumes driven by the significant decline in commodity prices, the Partnership recognized material asset impairment charges during the six months ended June 30, 2020 (see Note 6 — Property, Plant and Equipment). Management’s estimates and assumptions were based on historical data and consideration of future market conditions. Given the uncertainty inherent in any projection, heightened by the possibility of unforeseen additional impacts from COVID-19, actual results may differ from the estimates and assumptions used, or conditions may change, which could materially affect amounts reported in the financial statements in the near term.
Significant Accounting Policies
There have been no material changes to the Partnership’s critical accounting policies and estimates from those disclosed in the 2019 Annual Report, other than as noted below.
Financial instruments — credit losses. On January 1, 2020, the Partnership adopted Accounting Standards Update No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments (“ASU 2016-13”), which replaces the incurred loss impairment methodology with a methodology that reflects estimated credit losses expected over the life of an exposure and requires consideration of historical data, current market conditions and reasonable and supportable forecasts to develop credit loss estimates. In accordance with ASU 2016-13, the Partnership uses the expected credit loss methodology to measure impairment of financial instruments, including accounts receivable, which may result in earlier recognition of credit losses than under previous GAAP. ASU 2016-13 does not apply to receivables between entities under common control. The adoption of ASU 2016-13 did not have a material impact on the Partnership's financial position, cash flows or results of operations.
Recent Accounting Pronouncements
Reference rate reform. In March 2020, the Financial Accounting Standards Board issued Accounting Standards Update 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (“ASU 2020-04”). The amendments provide optional guidance for a limited time to ease the potential burden in accounting for reference rate reform. The new guidance provides optional expedients and exceptions for applying GAAP guidance to contracts, hedging relationships and other transactions affected by reference rate reform if certain criteria are met. The amendments apply only to contracts and hedging relationships that reference the London Interbank Offered Rate or another reference rate expected to be discontinued due to reference rate reform. These amendments are effective immediately and may be applied prospectively to contract modifications made and hedging relationships entered into or evaluated on or before December 31, 2022. The Partnership is currently evaluating its contracts and the optional expedients provided by ASU 2020-04 and the impact the new standard will have on its condensed consolidated financial statements and related disclosures.
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3. Revenue Recognition
Disaggregation of Revenues
The following table presents revenues associated with contracts with customers for the periods presented:
Three Months Ended June 30, Six Months Ended June 30,
2020
2019(1)
2020
2019(1)
(In thousands)
Service revenues
Crude oil, natural gas and NGL revenues $ 41,112    $ 45,314    $ 95,089    $ 93,932   
Produced and flowback water revenues 21,076    30,722    52,938    60,294   
Total service revenues 62,188    76,036    148,027    154,226   
Product revenues
Crude oil, natural gas and NGL revenues 2,866    16,641    17,302    26,858   
Freshwater revenues 1,009    7,726    7,361    13,171   
Total product revenues 3,875    24,367    24,663    40,029   
Total revenues $ 66,063    $ 100,403    $ 172,690    $ 194,255   
___________________
(1)Retrospectively adjusted for the transfer of net assets between entities under common control.
Prior Period Performance Obligations
The Partnership records revenue when the performance obligations under the terms of its customer contracts are satisfied. The Partnership measures the satisfaction of its performance obligations using the output method based upon the volume of crude oil, natural gas or water that flow through its systems. In certain cases, the Partnership is required to estimate these volumes during a reporting period and record any differences between the estimated volumes and actual volumes in the following reporting period. Such differences have historically not been significant. For the three and six months ended June 30, 2020 and 2019, revenue recognized related to performance obligations satisfied in prior reporting periods was not material.
Contract Balances
Contract balances are the result of timing differences between revenue recognition, billings and cash collections. Contract assets relate to revenue recognized for accrued deficiency fees associated with minimum volume commitments where the Partnership believes it is probable there will be a shortfall payment and that a significant reversal of revenue recognized will not occur once the related performance period is completed and the customer is billed. Revenue recognized for accrued deficiency fees associated with minimum volume commitments is recorded under midstream services – third parties on the Partnership’s Condensed Consolidated Statement of Operations. Contract liabilities relate to aid in construction payments received from customers, which are recognized as revenue over the expected period of future benefit. The Partnership does not recognize contract assets or contract liabilities under its customer contracts for which invoicing occurs once the Partnership’s performance obligations have been satisfied and payment is unconditional. Contract balances are classified as current or long-term based on the timing of when the Partnership expects to receive cash for contract assets or recognize revenue for contract liabilities. Contract assets are recorded under other current assets on the Partnership’s Condensed Consolidated Balance Sheet. Contract liabilities are recorded under other current liabilities and other liabilities on the Partnership’s Condensed Consolidated Balance Sheet.
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The following table summarizes the changes in contract assets for the six months ended June 30, 2020:
(In thousands)
Balance as of December 31, 2019 $ —   
Revenue recognized 1,538   
Balance as of June 30, 2020 $ 1,538   

The following table summarizes the changes in contract liabilities for the six months ended June 30, 2020:
(In thousands)
Balance as of December 31, 2019 $ 3,681   
Cash received 1,769   
Revenue recognized (295)  
Balance as of June 30, 2020
$ 5,155   

Remaining Performance Obligations
The following table presents estimated revenue allocated to remaining performance obligations for contracted revenues that are unsatisfied (or partially satisfied) as of June 30, 2020:
(In thousands)
2020 (excluding six months ended June 30, 2020)
$ 10,084   
2021 17,731   
2022 17,862   
2023 12,366   
2024 11,874   
Thereafter 2,768   
Total $ 72,685   
The partially and wholly unsatisfied performance obligations presented in the table above are generally limited to customer contracts which have fixed pricing and fixed volume terms and conditions, which generally include customer contracts with minimum volume commitment payment obligations.
The Partnership has elected practical expedients, pursuant to Accounting Standards Codification 606, Revenue from Contracts with Customers, to exclude from the presentation of remaining performance obligations: (i) contracts with index-based pricing or variable volume attributes in which such variable consideration is allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer a distinct service that forms part of a series of distinct services and (ii) contracts with an original expected duration of one year or less.
4. Transactions with Affiliates
Revenues. The Partnership generates the majority of its revenues through 15-year, fee-based contractual arrangements with wholly-owned subsidiaries of Oasis Petroleum for midstream services as described in Note 1 — Organization and Nature of Operations. In addition, the Partnership sells the residue gas and NGLs recovered from its gas processing plants attributable to its third-party natural gas purchase agreements to Oasis Petroleum to market and sell to non-affiliated purchasers.
Oasis Petroleum has expressed substantial doubt about its ability to continue to operate as a going concern, and financial distress at Oasis Petroleum could have a material adverse effect on the Partnership’s results of operations (See Note 2 — Summary of Significant Accounting Policies — Risks and Uncertainties).
Expenses. Oasis Petroleum provides substantial labor and overhead support to the Partnership pursuant to a 15-year services and secondment agreement. Oasis Petroleum performs centralized corporate, general and administrative services for the Partnership, such as legal, corporate recordkeeping, planning, budgeting, regulatory, accounting, billing, business development, treasury, insurance administration and claims processing, risk management, health, safety and environmental, information technology, human resources, investor relations, cash management and banking, payroll, internal audit, tax and engineering. Oasis Petroleum has also seconded to the Partnership certain of its employees to operate, construct, manage and maintain the
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Partnership’s assets. The expenses of executive officers and non-executive employees of Oasis Petroleum are allocated to the Partnership based on the amount of time spent managing its business and operations. The Partnership reimburses Oasis Petroleum for direct and allocated general and administrative expenses incurred by Oasis Petroleum for the provision of these services. The Partnership’s general and administrative expenses includes $8.1 million and $7.0 million from affiliate transactions with Oasis Petroleum for the three months ended June 30, 2020 and 2019, respectively, and $15.7 million and $14.8 million from affiliate transactions with Oasis Petroleum for the six months ended June 30, 2020 and 2019, respectively.
Additionally, for the periods prior to the 2019 Delaware Acquisition, interest expense was recognized by the Delaware Predecessor related to its funding activity with Oasis Petroleum based on capital expenditures for the period using the weighted average effective interest rate for Oasis Petroleum’s long-term indebtedness. Interest expense, net of capitalized interest, includes $0.1 million and $0.3 million related to the Delaware Predecessor for the three and six months ended June 30, 2019, respectively.
5. Accrued Liabilities
Accrued liabilities consist of the following:
June 30, 2020 December 31, 2019
(In thousands)
Accrued capital costs $ 13,603    $ 33,105   
Accrued operating expenses 11,965    12,149   
Other accrued liabilities 831    4,956   
Total accrued liabilities $ 26,399    $ 50,210   

6. Property, Plant and Equipment
Property, plant and equipment consists of the following:
June 30, 2020 December 31, 2019
(In thousands)
Pipelines $ 534,822    $ 523,576   
Natural gas processing plants 300,832    296,609   
Produced and flowback water facilities 124,655    121,797   
Compressor stations 184,607    143,276   
Other property and equipment 34,264    34,231   
Construction in progress 3,372    36,014   
Total property, plant and equipment 1,182,552    1,155,503   
Less: accumulated depreciation, amortization and impairment (222,771)   (98,982)  
Total property, plant and equipment, net $ 959,781    $ 1,056,521   
Long-lived asset impairment. Property, plant and equipment is stated at the lower of historical cost less accumulated depreciation or fair value if impaired. The Partnership routinely evaluates the existence of triggering events which could indicate the carrying amount of its property, plant and equipment may not be recoverable. Impairment indicators include, but are not limited to, sustained decreases in commodity prices, a decline in customer well results and lower throughput forecasts, changes in customer development plans and/or increases in construction or operating costs.
As a result of lower forecasted throughput volumes due to changes in customers’ development plans associated with expected sustained significant decreases in commodity prices, the Partnership reviewed the carrying amounts of its asset groups for recoverability during the first quarter of 2020. The Partnership completed a Step 1 impairment analysis by comparing the undiscounted future cash flows to the carrying amounts for each of its crude oil, natural gas, freshwater and produced and flowback water asset groups in the Williston Basin and the Delaware Basin. During the six months ended June 30, 2020, the Partnership recorded an impairment charge of $101.8 million to reduce the carrying value of its property, plant and equipment to the estimated fair value. In the Williston Basin, the Partnership recorded an impairment charge of $35.8 million related to its crude oil asset group and $33.1 million related to its freshwater asset group. In the Delaware Basin, the Partnership recorded an impairment charge of $17.9 million related to its crude oil asset group and $15.0 million related to its produced and flowback water asset group.
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The Partnership determined no impairment indicators existed as of June 30, 2020 and did not record an impairment charge for the three months ended June 30, 2020.
If commodity prices continue to decline or remain at depressed levels for a prolonged period of time, if there are shut-ins of production from customers’ existing producing wells or if there are significant changes in customers’ future development plans, including Oasis Petroleum, to the extent they affect the Partnership’s operations, such circumstances may necessitate assessment of the carrying amount of the Partnership’s affected assets for recoverability and may result in additional impairment charges in the future. In addition, if the United States oil and gas industry continues to experience an imbalance of supply and demand as it endured during the six months ended June 30, 2020, the Partnership’s operations could be adversely affected and future impairment charges could be incurred.
Fair value measurements. Impairment expense was measured as the excess of the asset group’s carrying amount over its estimated fair value. Fair value was measured using a discounted cash flow model using Level 3 inputs. The inputs used are subject to management’s judgment and expertise and include, but are not limited to, estimated throughput volumes, estimated fixed and variable operating costs, estimated capital costs, estimated useful life of the asset group and discount rate. The estimated future cash flows were discounted at a market-based weighted average cost of capital of 10.4%. Fair value determinations require considerable judgment and are sensitive to changes in underlying assumptions and factors. As a result, there can be no assurance that the estimates and assumptions made for purposes of the impairment analysis will prove to be an accurate prediction of the future.
7. Long-Term Debt
The Partnership has a revolving credit facility among OMP Operating LLC (“OMP Operating”) as borrower, Wells Fargo Bank, N.A., as Administrative Agent (the “Administrative Agent”) and the lenders party thereto (as amended, the “Revolving Credit Facility”), which matures on September 25, 2022. The Revolving Credit Facility is available to fund working capital and to finance acquisitions and other capital expenditures of the Partnership. As of June 30, 2020, the aggregate commitments under the Revolving Credit Facility were $575.0 million.
At June 30, 2020, the Partnership had $487.5 million of borrowings outstanding under the Revolving Credit Facility, at a weighted average interest rate of 1.9% and a de minimis outstanding letter of credit, resulting in an unused borrowing capacity of $87.5 million. At December 31, 2019, the Partnership had $458.5 million of borrowings outstanding under the Revolving Credit Facility, at a weighted average interest rate of 3.8%, and a $1.7 million outstanding letter of credit.
The unused portion of the Revolving Credit Facility is subject to a commitment fee ranging from 0.375% to 0.500%. The fair value of the Revolving Credit Facility approximates book value since borrowings under the Revolving Credit Facility bear interest at rates which are tied to current market rates.
As a result of ongoing internal oversight processes during the six months ended June 30, 2020, the Partnership identified that a Control Agreement (as defined in the Revolving Credit Facility) had not been executed for a certain bank account (the “JPM Account”) held at JPMorgan Chase Bank, N.A. (“JPMorgan”), who is a lender under the Revolving Credit Facility. The Control Agreement serves to establish a lien in favor of the lenders under the Revolving Credit Facility with respect to the JPM Account. On May 11, 2020, the Partnership and OMP Operating executed a Control Agreement with both the Administrative Agent and JPMorgan, thereby completing the documentation required under the Revolving Credit Facility. Despite the Control Agreement’s execution, the failure to have had it in place before the JPM Account was initially funded with cash represented a past Event of Default (as defined in the Revolving Credit Facility). On May 15, 2020, the Partnership entered into a limited waiver (the “Limited Waiver”) of this past Event of Default with the Majority Lenders (as defined in the Revolving Credit Facility), which provides forbearance of additional interest owed arising from this past Event of Default until the earlier of (i) November 10, 2020 and (ii) an Event of Default. Pursuant to the Limited Waiver, the Partnership recorded additional interest charges of $2.1 million and $28.0 million during the three and six months ended June 30, 2020, respectively. The Limited Waiver excludes the additional interest from the calculation of the interest coverage ratio financial covenant. The Partnership was in compliance with the covenants under the Revolving Credit Facility at June 30, 2020.
8. Inventory
Inventory consists primarily of spare parts and equipment related to the Partnership’s midstream infrastructure. Inventory is stated at the lower of cost and net realizable value with cost determined on an average cost method. The Partnership assesses the carrying value of inventory and uses estimates and judgment when making any adjustments necessary to reduce the carrying value to net realizable value. Due to lower market prices, the Partnership recorded a write-down of its inventory of $0.2 million for the three and six months ended June 30, 2020.
The carrying value of the Partnership’s inventory was $7.6 million at June 30, 2020. The Partnership had no inventory at December 31, 2019.
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9. Commitments and Contingencies
The Partnership has various contractual obligations in the normal course of its operations. Included below is a description of the Partnership’s various future commitments as of June 30, 2020.
Volume commitment agreements. As of June 30, 2020, the Partnership had certain agreements with an aggregate requirement to either deliver or purchase a minimum quantity of approximately 11.4 million barrels of water and approximately 25.6 million barrels of crude oil, prior to any applicable volume credits, within specified timeframes, all of which are 10 years or less. The estimable future commitments under these agreements were approximately $21.1 million as of June 30, 2020. The commitments under these arrangements are not recorded in the accompanying Condensed Consolidated Balance Sheet as of June 30, 2020.
Litigation. The Partnership is party to various legal and/or regulatory proceedings from time to time arising in the ordinary course of business. When the Partnership determines that a loss is probable of occurring and is reasonably estimable, the Partnership accrues an undiscounted liability for such contingencies based on its best estimate using information available at the time. The Partnership discloses contingencies where an adverse outcome may be material, or where in the judgment of management, the matter should otherwise be disclosed.
Mirada litigation. On March 23, 2017, Mirada Energy, LLC, Mirada Wild Basin Holding Company, LLC and Mirada Energy Fund I, LLC (collectively, “Mirada”) filed a lawsuit against Oasis Petroleum, Oasis Petroleum North America LLC (“OPNA”), and OMS, seeking monetary damages in excess of $100 million, declaratory relief, attorneys’ fees and costs (Mirada Energy, LLC, et al. v. Oasis Petroleum North America LLC, et al.; in the 334th Judicial District Court of Harris County, Texas; Case Number 2017-19911). Mirada asserts that it is a working interest owner in certain acreage owned and operated by Oasis Petroleum in Wild Basin. Specifically, Mirada asserts that Oasis Petroleum has breached certain agreements by: (1) failing to allow Mirada to participate in Oasis Petroleum’s midstream operations in Wild Basin; (2) refusing to provide Mirada with information that Mirada contends is required under certain agreements and failing to provide information in a timely fashion; (3) failing to consult with Mirada and failing to obtain Mirada’s consent prior to drilling more than one well at a time in Wild Basin; and (4) overstating the estimated costs of proposed well operations in Wild Basin. Mirada seeks a declaratory judgment that Oasis Petroleum be removed as operator in Wild Basin at Mirada’s election and that Mirada be allowed to elect a new operator; certain agreements apply to Oasis Petroleum and Mirada and Wild Basin with respect to this dispute; Oasis Petroleum be required to provide all information within its possession regarding proposed or ongoing operations in Wild Basin; and Oasis Petroleum not be permitted to drill, or propose to drill, more than one well at a time in Wild Basin without obtaining Mirada’s consent. Mirada also seeks a declaratory judgment with respect to Oasis Petroleum’s current midstream operations in Wild Basin. Specifically, Mirada seeks a declaratory judgment that Mirada has a right to participate in Oasis Petroleum’s Wild Basin midstream operations, consisting of produced and flowback water disposal, crude oil gathering and natural gas gathering and processing; that, upon Mirada’s election to participate, Mirada is obligated to pay its proportionate costs of Oasis Petroleum’s midstream operations in Wild Basin; and that Mirada would then be entitled to receive a share of revenues from the midstream operations and would not be charged any amount for its use of these facilities for production from the “Contract Area.”
On June 30, 2017, Mirada amended its original petition to add a claim that Oasis Petroleum has breached certain agreements by charging Mirada for midstream services provided by its affiliates and to seek a declaratory judgment that Mirada is entitled to be paid its share of total proceeds from the sale of hydrocarbons received by OPNA or any affiliate of OPNA without deductions for midstream services provided by OPNA or its affiliates.
On February 2, 2018 and February 16, 2018, Mirada filed a second and third amended petition, respectively. In these filings, Mirada alleged new legal theories for being entitled to enforce the underlying contracts, and added Bighorn DevCo, Bobcat DevCo and Beartooth DevCo as defendants, asserting that these entities were created in bad faith in an effort to avoid contractual obligations owed to Mirada.
On March 2, 2018, Mirada filed a fourth amended petition that described Mirada’s alleged ownership and assignment of interests in assets purportedly governed by agreements at issue in the lawsuit. On August 31, 2018, Mirada filed a fifth amended petition that added the Partnership as a defendant, asserting that it was created in bad faith in an effort to avoid contractual obligations owed to Mirada.
On July 2, 2019, Oasis Petroleum, OPNA, OMS, the Partnership, Bighorn DevCo, Bobcat DevCo and Beartooth DevCo (collectively “Oasis Entities”) counterclaimed against Mirada for a judgment declaring that Oasis Entities are not obligated to purchase, manage, gather, transport, compress, process, market, sell or otherwise handle Mirada’s proportionate share of oil and gas produced from OPNA-operated wells. The counterclaim also seeks attorney’s fees, costs and expenses.
On November 1, 2019, Mirada filed a sixth amended petition that stated that Mirada seeks in excess of $200 million in damages and asserted that OMS is an agent of OPNA and OPNA, OMS, the Partnership, Bighorn DevCo, Bobcat DevCo and Beartooth DevCo are agents of Oasis Petroleum. Mirada also changed its allegation that it may elect a new operator for the subject wells to instead allege that Mirada may remove Oasis Petroleum as operator.
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On November 1, 2019, the Oasis Entities amended their counterclaim against Mirada for a judgment declaring that a provision in one of the agreements does not incorporate by reference any provisions in a certain participation agreement and joint operating agreement. The additional counterclaim also seeks attorney’s fees, costs and expenses. On the same day, the Oasis Entities filed an amended answer asserting additional defenses against Mirada’s claims.
On March 13, 2020, Mirada filed a seventh amended petition that did not assert any new causes of action and did not add any new parties. Mirada did add an allegation that Oasis Petroleum breached its implied duty of good faith and fair dealing with respect to certain contracts.
On April 30, 2020, Mirada abandoned its prior claims related to overstating the estimated costs of proposed well operations in Wild Basin. At this point, it is unclear what impact this has on damages because Mirada asserts that its information and failure to consult and obtain consent claims result in the same damages as its abandoned estimated costs claim.
Oasis Petroleum and the Partnership believe that Mirada’s claims are without merit, that Oasis Petroleum has complied with its obligations under the applicable agreements and that some of Mirada’s claims are grounded in agreements that do not apply to Oasis Petroleum. Oasis Petroleum filed answers denying all of Mirada’s claims and intends and continues to vigorously defend against Mirada’s claims.
Discovery is ongoing, and each of the parties has made a number of procedural filings and motions, and additional filings and motions can be expected over the course of the claim. Trial is scheduled for October 2020. Neither the Partnership nor Oasis Petroleum can predict or guarantee the ultimate outcome or resolution of such matter. If such matter were to be determined adversely to the Partnership’s or Oasis Petroleum’s interests, or if the Partnership or Oasis Petroleum were forced to settle such matter for a significant amount, such resolution or settlement could have a material adverse effect on the Partnership's business, financial condition, results of operations and cash flows. Such an adverse determination could materially impact Oasis Petroleum’s ability to operate its properties in Wild Basin or develop its identified drilling locations in Wild Basin on its current development schedule. A determination that Mirada has a right to participate in Oasis Petroleum’s midstream operations could materially reduce the interests of Oasis Petroleum and the Partnership in the Partnership’s current assets and future midstream opportunities and related revenues in Wild Basin. Under the Omnibus Agreement the Partnership entered into with Oasis Petroleum in connection with the closing of the initial public offering, Oasis Petroleum agreed to indemnify the Partnership for any losses resulting from this litigation. However, the Partnership cannot guarantee that such indemnity will fully protect the Partnership from the adverse consequences of any adverse ruling.
Solomon litigation. On or about August 28, 2019, Oasis Petroleum LLC, a wholly-owned subsidiary of Oasis Petroleum (“OP LLC”), was named as a defendant in the lawsuit styled Andrew Solomon, on behalf of himself and those similarly situated v. Oasis Petroleum, LLC, pending in the United States District Court for the District of North Dakota. The lawsuit alleged violations of the federal Fair Labor Standards Act (the “FLSA”) and Title 29 of the North Dakota Century Code (“Title 29”) as the result of OP LLC’s alleged practice of paying the plaintiff and similarly situated current and former employees overtime at rates less than required by applicable law, or failing to pay for certain overtime hours worked. The lawsuit requested that: (i) its federal claims be advanced as a collective action, with a class of all operators, technicians and all other employees in substantially similar positions employed by OP LLC who were paid hourly for at least one week during the three year period prior to the commencement of the lawsuit, who worked 40 or more hours in at least one workweek and/or eight or more hours on at least one workday; and (ii) its state claims be advanced as a class action, with a class of all operators, technicians, and all other employees in substantially similar positions employed by OP LLC in North Dakota during the two year period prior to the commencement of the lawsuit, who worked 40 or more hours in at least one workweek and/or worked eight or more hours in a day on at least one workday. No motion has been filed for class certification, and the Partnership cannot predict whether such a motion will be filed or a class certified.
Oasis Petroleum believes that Mr. Solomon’s claims are without merit and that OP LLC has complied with its obligations under the FLSA and Title 29. OP LLC has filed an answer denying all of Mr. Solomon’s claims and intends to vigorously defend against the claims. The Partnership cannot predict or guarantee the ultimate outcome or resolutions of such matter. If such matter were to be determined adversely to Oasis Petroleum’s interests, or if Oasis Petroleum were forced to settle such matter for a significant amount, such resolution or settlement could have a material adverse effect on the Partnership’s business, financial condition, results of operations or cash flows.
10. Equity-Based Compensation
The Oasis Midstream Partners LP 2017 Long Term Incentive Plan (“LTIP”) provides for the grant, at the discretion of the Board of Directors of the General Partner, of options, unit appreciation rights, restricted units, phantom units, and other unit or cash-based awards. The purpose of awards under the LTIP is to provide additional incentive compensation to individuals providing services to the Partnership and to align the economic interests of such individuals with the interests of the Partnership’s unitholders. As of June 30, 2020, the aggregate number of common units that may be issued pursuant to any and all awards under the LTIP was equal to 2,793,360 common units.
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Restricted unit awards. The Partnership has granted to independent directors of the General Partner restricted unit awards under the LTIP, which vest over a one year period. These awards are accounted for as equity-classified awards since the awards will settle in common units upon vesting. Equity-based compensation expense is accounted for under the fair value method in accordance with GAAP. Under the fair value method for equity-classified awards, equity-based compensation expense is measured at the grant date based on the fair value of the award and is recognized over the vesting period.
During the six months ended June 30, 2020, the Partnership granted 16,170 restricted unit awards to certain independent directors at a weighted-average grant date fair value of $16.69 per common unit, which vest over a one year period. The Partnership recorded equity-based compensation expense of $0.1 million for the three and six months ended June 30, 2020 and $0.1 million and $0.2 million for the three and six months ended June 30, 2019, respectively. Equity-based compensation expense is recorded under general and administrative expenses on the Partnership’s Condensed Consolidated Statements of Operations.
As of June 30, 2020, unrecognized equity-based compensation expense for outstanding restricted unit awards was $0.2 million, which is expected to be recognized over a weighted average period of 0.6 years.
11. Partnership Equity and Distributions
The following table details the distributions paid in respect of each period in which the distributions were earned for the following periods:
Distributions
Limited Partners General Partner
Period Record Date Distribution Date Distribution per limited partner unit Common units Subordinated units IDRs
(In thousands)
Q1 2019 May 17, 2019 May 29, 2019 $0.470 $ 9,421    $ 6,463    $ 238   
Q2 2019 August 16, 2019 August 28, 2019 $0.490 9,822    6,738    463   
Q3 2019 November 15, 2019 November 27, 2019 $0.515 10,323    7,081    745   
Q4 2019 February 13, 2020 February 27, 2020 $0.540 10,833    7,425    1,027   
Q1 2020 May 28, 2020 June 8, 2020 $0.540 10,833    7,425    1,027   
Cash distributions. On August 4, 2020, the Board of Directors of the General Partner declared the quarterly cash distribution for the second quarter of 2020 of $0.54 per unit. In addition, the General Partner will receive a cash distribution of $1.0 million attributable to the incentive distribution rights related to earnings for the second quarter of 2020.  These distributions will be payable on August 27, 2020, to unitholders of record as of August 14, 2020.
Incentive distribution rights. The General Partner owns all of the Partnership’s incentive distribution rights (“IDRs”), which entitle it to increasing percentages, up to a maximum of 50.0%, of the cash the Partnership distributes in excess of $0.4313 per unit per quarter. The maximum distribution of 50.0% does not include any distributions that Oasis Petroleum may receive on common units or subordinated units that it owns.
12. Earnings (Loss) Per Limited Partner Unit
Earnings (loss) per limited partner unit is computed by dividing the respective limited partners’ interest in earnings (loss) attributable to the Partnership by the weighted average number of common and subordinated units outstanding. Because there is more than one class of participating securities, the Partnership uses the two-class method when calculating earnings (loss) per limited partner unit. The classes of participating securities include common units, subordinated units and IDRs.
Diluted earnings (loss) per limited partner unit reflects the potential dilution that could occur if securities or agreements to issue common units, such as awards under the LTIP, were exercised, settled or converted into common units. When it is determined that potential common units should be included in diluted net income (loss) per limited partner unit calculation, the impact is reflected by applying the treasury stock method. There are no adjustments made to net income (loss) attributable to Oasis Midstream Partners LP in the calculation of diluted earnings (loss) per unit. Diluted weighted average limited partner units outstanding includes the dilutive effect of unvested restricted unit awards (see Note 10 — Equity-Based Compensation). For the three and six months ended June 30, 2020, the diluted loss per share calculation excludes the anti-dilutive effect of unvested restricted unit awards.
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The following is a calculation of the basic and diluted weighted average units outstanding for the periods presented:
Three Months Ended June 30, Six Months Ended June 30,
2020 2019 2020 2019
(In thousands)
Basic weighted average common units outstanding 20,045    20,024    20,043    20,020   
Dilutive effect of restricted awards —    10    —    17   
Diluted weighted average common units outstanding 20,045    20,034    20,043    20,037   

The following tables present the calculation of earnings (loss) per limited partner unit under the two-class method for each period presented:

Six Months Ended June 30, 2020
General Partner Limited Partners
IDRs Common units Subordinated units Total
(In thousands, except per unit data)
Net income (loss) attributable to Oasis Midstream Partners LP
Distribution declared $ 2,054    $ 21,666    $ 14,850    $ 38,570   
Undistributed loss attributable to Oasis Midstream Partners LP —    (58,182)   (39,913)   (98,095)  
Net income (loss) attributable to Oasis Midstream Partners LP $ 2,054    $ (36,516)   $ (25,063)   $ (59,525)  
Weighted average limited partners units outstanding
Basic 20,043   
Diluted 20,043   
Net loss attributable to Oasis Midstream Partners LP per limited partner unit
Basic $ (1.82)  
Diluted (1.82)  
Anti-dilutive restricted units 9   

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Six Months Ended June 30, 2019
General Partner Limited Partners
IDRs Common units Subordinated units Total
(In thousands, except per unit data)
Net income attributable to Oasis Midstream Partners LP
Distribution declared $ 729    $ 19,243    $ 13,201    $ 33,173   
Undistributed earnings attributable to Oasis Midstream Partners LP —    8,637    5,931    14,568   
Net income attributable to Oasis Midstream Partners LP $ 729    $ 27,880    $ 19,132    $ 47,741   
Weighted average limited partners units outstanding
Basic 20,020   
Diluted 20,037   
Net income attributable to Oasis Midstream Partners LP per limited partner unit
Basic $ 1.39   
Diluted 1.39   
Anti-dilutive restricted units 7   

Three Months Ended June 30, 2020
General Partner Limited Partners
IDRs Common units Subordinated units Total
(In thousands, except per unit data)
Net income attributable to Oasis Midstream Partners LP
Distribution declared $ 1,027    $ 10,833    $ 7,425    $ 19,285   
Undistributed earnings attributable to Oasis Midstream Partners LP —    (4,396)   (3,015)   (7,411)  
Net income attributable to Oasis Midstream Partners LP $ 1,027    $ 6,437    $ 4,410    $ 11,874   
Weighted average limited partners units outstanding
Basic 20,045   
Diluted 20,045   
Net income attributable to Oasis Midstream Partners LP per limited partner unit
Basic $ 0.32   
Diluted 0.32   
Anti-dilutive restricted units 16   

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Three Months Ended June 30, 2019
General Partner Limited Partners
IDRs Common units Subordinated units Total
(In thousands, except per unit data)
Net income attributable to Oasis Midstream Partners LP
Distribution declared $ 491    $ 9,822    $ 6,738    $ 17,051   
Undistributed earnings attributable to Oasis Midstream Partners LP —    5,423    3,724    9,147   
Net income attributable to Oasis Midstream Partners LP $ 491    $ 15,245    $ 10,462    $ 26,198   
Weighted average limited partners units outstanding
Basic 20,024   
Diluted 20,034   
Net income attributable to Oasis Midstream Partners LP per limited partner unit
Basic $ 0.76   
Diluted 0.76   
Anti-dilutive restricted units 11   

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Item 2. — Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in our Annual Report on Form 10-K for the year ended December 31, 2019 (“2019 Annual Report”), as well as the unaudited condensed consolidated financial statements and notes thereto included in this Quarterly Report on Form 10-Q.
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This Quarterly Report on Form 10-Q contains forward-looking statements. These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control. Forward-looking statements give our current expectations, contain projections of results of operations or of financial condition or provide forecasts of future events. Words such as “may,” “assume,” “forecast,” “position,” “predict,” “strategy,” “expect,” “intend,” “plan,” “estimate,” “anticipate,” “believe,” “project,” “budget,” “potential,” “continue” and other similar expressions are used to identify forward-looking statements.
Forward-looking statements can be affected by the assumptions used or by known or unknown risks or uncertainties. Consequently, no forward-looking statements can be guaranteed. When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements discussed below and detailed under Part II, Item 1A. “Risk Factors” in this Quarterly Report on Form 10-Q. Actual results may vary materially. Although forward-looking statements reflect our good faith beliefs at the time they are made, you are cautioned not to place undue reliance on any forward-looking statements. You should also understand that it is not possible to predict or identify all such factors and you should not consider the following list to be a complete statement of all potential risks and uncertainties. In addition, our forward-looking statements address the various risks and uncertainties associated with the extraordinary market environment and impacts resulting from the novel coronavirus 2019 (“COVID-19”) pandemic and the actions of foreign oil producers (most notably Saudi Arabia and Russia) to increase crude oil production and the expected impact on our businesses, operations, earnings and results. Factors that could cause our actual results to differ materially from the results contemplated by such forward-looking statements include but are not limited to:
•the continuation of a swift and material decline in global crude oil demand and crude oil prices for an uncertain period of time that correspondingly may lead to a significant reduction of domestic crude oil and natural gas production, which in turn could result in significant declines in the actual or expected volumes transported through our pipelines and/or the reduction of commercial opportunities that might otherwise be available to us;
•developments in the global economy as well as the public health crisis related to the COVID-19 virus and resulting demand and supply for crude oil and natural gas;
•uncertainty regarding the length of time it will take for the U.S. and the rest of the world to slow the spread of the COVID-19 virus to the point where applicable authorities are comfortable easing current restrictions on various commercial and economic activities; such restrictions are designed to protect public health but also have the effect of significantly reducing demand for crude oil and natural gas;
•uncertainty regarding the future actions of foreign oil producers such as Saudi Arabia and Russia and the risk that they take actions that will prolong or exacerbate the current over-supply of crude oil;
•uncertainty regarding the timing, pace and extent of an economic recovery in the U.S. and elsewhere, which in turn will likely affect demand for crude oil and natural gas and therefore the demand for the midstream services we provide and the commercial opportunities available to us;
•the effect of an overhang of significant amounts of crude oil and natural gas inventory stored in the U.S. and elsewhere and the impact that such inventory overhang ultimately has on the timing of a return to market conditions that support increased drilling and production activities in the U.S.;
•the existence of substantial unresolved doubt about the ability of Oasis Petroleum to continue as a going concern;
•an inability of Oasis Petroleum or our other customers to meet their operational and development plans on a timely basis or at all;
•the execution of our business strategies;
•the demand for and price of crude oil and natural gas, on an absolute basis and in comparison to the price of alternative and competing fuels;
•the fees we charge, and the margins we realize, from our midstream services;
•the cost of achieving organic growth in current and new markets;
•our ability to make acquisitions of other midstream infrastructure assets or other assets that complement or diversify our operations;
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•our ability to make acquisitions of other assets on economically acceptable terms from Oasis Petroleum;
•our inability to perform our obligations under our contracts, whether due to non-performance by third parties, including our customers or other counterparties, market constraints, third-party constraints, legal constraints (including governmental orders or guidance), or other factors;
•the lack of asset and geographic diversification;
•the suspension, reduction or termination of our commercial agreements with Oasis Petroleum;
•labor relations and government regulations;
•competition and actions taken by third party producers, operators, processors and transporters;
•outcomes of litigation and regulatory investigations, proceedings or inquiries;
•the demand for, and the costs of developing and conducting, our midstream infrastructure services;
•interruptions in service and fluctuations in tariff provisions of third party connecting pipelines;
•general economic conditions, including the risk of a prolonged economic slowdown or decline, or the risk of delay in a recovery, which can affect the long-term demand for natural gas and crude oil and related services;
•the price and availability of equity and debt financing;
•operating hazards, natural disasters, weather-related delays, casualty losses and other matters beyond our control;
•potential effects arising from cyber threats, terrorist attacks and any consequential or other hostilities;
•interruption of our operations due to social, civil or political events or unrest;
•changes in environmental, safety and other laws and regulations;
•the effects of accounting pronouncements issued periodically during the periods covered by forward-looking statements;
•changes in our tax status;
•uncertainty regarding our future operating results; and
•certain factors discussed elsewhere in this Quarterly Report on Form 10-Q, in our 2019 Annual Report and in our other SEC filings.
All forward-looking statements speak only as of the date of this Quarterly Report on Form 10-Q. We disclaim any obligation to update or revise these statements unless required by securities law. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this Quarterly Report on Form 10-Q are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved. Some of the key factors which could cause actual results to vary from our expectations include, but are not limited to, commodity price volatility, inflation, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in projecting future throughput volumes, cash flow and access to capital, the timing of development expenditures and the other risks described under Part II, Item 1A. “Risk Factors” in this Quarterly Report on Form 10-Q.
Overview
We are a growth-oriented, fee-based master limited partnership formed by our sponsor, Oasis Petroleum Inc. (“Oasis Petroleum”) (Nasdaq: OAS), to own, develop, operate and acquire a diversified portfolio of midstream assets in North America that are integral to the crude oil and natural gas operations of Oasis Petroleum and are strategically positioned to capture volumes from other producers. Our midstream operations are performed within the Williston Basin and the Delaware Basin. We generate the majority of our revenues through long-term, fixed-fee contracts pursuant to which we provide crude oil, natural gas and water-related midstream services for Oasis Petroleum. We expect to grow acquisitively through accretive, dropdown acquisitions, as well as organically as Oasis Petroleum continues to develop its acreage. We also expect to grow by continuing to offer our services to third parties and through acquisitions of midstream assets from third parties.
In the Williston Basin, we divide our operations into two primary areas with developed midstream infrastructure, both of which are supported by significant acreage dedications from Oasis Petroleum. In Wild Basin, we have acreage dedications from Oasis Petroleum in which we have the right to provide crude oil, natural gas and water services to support Oasis Petroleum’s existing and future volumes. Outside of Wild Basin, we have acreage dedications from Oasis Petroleum for produced and flowback water services and freshwater services. In the Delaware Basin, we have acreage dedications from Oasis Petroleum for crude oil gathering and produced and flowback water gathering and disposal services. We have also received commitments and acreage dedications from third parties in the Williston Basin and the Delaware Basin, in which we have the right to provide crude oil, natural gas and water services to support existing and future third party volumes.
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We conduct our business through our ownership of our DevCos, two of which are jointly-owned with Oasis Petroleum. As of June 30, 2020, we own a 100% equity interest in Bighorn DevCo LLC (“Bighorn DevCo”), a 35.3% equity interest in Bobcat DevCo LLC (“Bobcat DevCo”), a 70% equity interest in Beartooth DevCo LLC (“Beartooth DevCo”) and a 100% equity interest in Panther DevCo LLC (“Panther DevCo”). As of June 30, 2020, Oasis Petroleum owns a 64.7% and 30% non-controlling equity interest in Bobcat DevCo and Beartooth DevCo, respectively.
We are party to long-term, fixed-fee contracts with wholly-owned subsidiaries of Oasis Petroleum for natural gas services (gathering, compression, processing, gas lift and natural gas liquids (“NGLs”) storage), crude oil services (gathering, stabilization, blending and storage), produced and flowback water services (gathering and disposal) and freshwater services (fracwater and flushwater supply and distribution). We are also a party to the long-term, Federal Energy Regulatory Commission (“FERC”) regulated transportation services agreement governing the transportation of crude oil via pipeline from the Wild Basin area to Johnson’s Corner. The amount of revenue we generate primarily depends on the volume of crude oil, natural gas and water for which we provide midstream services. We generate a substantial majority of our revenues through these contracts, which minimizes our direct exposure to commodity prices.
While we have increased our customer diversification by entering into multiple agreements and transactions with third parties to provide midstream services, we are largely dependent on Oasis Petroleum as our most significant customer. Based on the current commodity price environment, Oasis Petroleum has expressed substantial doubt about its ability to continue to operate as a going concern, and financial distress at Oasis Petroleum could have a material adverse effect on the Partnership’s results of operations (see Item 1. “Financial Statements (Unaudited) — Notes to Condensed Consolidated Financial Statements — Note 2 — Summary of Significant Accounting Policies — Risks and Uncertainties”). However, an event of default or bankruptcy of Oasis Petroleum would not trigger an automatic acceleration of indebtedness under our Revolving Credit Facility, as there are not any cross-acceleration or cross-default provisions between the Oasis Petroleum credit agreement and our Revolving Credit Facility.
Our operating and financial results are substantially dependent on our ability to maintain or increase existing throughput volumes on our systems. Throughput volumes are affected by changes in the supply of and demand for crude oil and natural gas in the markets served directly or indirectly by our assets. During the first half of 2020, commodity prices experienced significant volatility. Beginning in the first quarter of 2020, commodity prices declined significantly as a result of macroeconomic factors, including demand impacts due to global disruptions resulting from COVID-19 and supply impacts related to production increases by members of the Organization of Petroleum Exporting Countries (“OPEC”) and other non-OPEC, oil producing countries, including Russia. In response to these events, U.S. onshore producers, including Oasis Petroleum, have implemented plans which adversely impact our ability to maintain or increase existing throughput volumes, including reductions to capital spending, changes to development plans and delays in production. We cannot predict whether or when crude oil production and economic activities will return to normalized levels. The commodity price environment is expected to remain depressed based on over-supply, decreasing demand and a global economic recession, as further discussed below. Ultimately, a prolonged period of lower commodity prices may adversely affect our operating results and cash flows through lower throughput volumes on our assets, which could result in future impairment charges. During the second quarter of 2020, certain U.S. onshore producers we provide services to, including Oasis Petroleum, elected to temporarily shut-in production and delay drilling plans, which reduced demand for our services and lowered the quantity of throughput volumes on our systems. If constraints continue such that storage becomes unavailable to our customers, including Oasis Petroleum, or commodity prices remain depressed, our customers may continue to elect to shut-in some or all of their production or delay or discontinue drilling plans, which would result in a further decline in demand for our services. In addition, we generate the majority of our revenues pursuant to fee-based agreements, and producers we provide services to could seek to amend existing contracts to reduce the volumetric fees we charge.
We routinely evaluate the existence of triggering events which could indicate the carrying amount of our property, plant and equipment may not be recoverable. Impairment indicators include, but are not limited to, sustained decreases in commodity prices, a decline in customer well results and lower throughput forecasts, changes in customer development plans and/or increases in construction or operating costs. As a result of lower forecasted throughput volumes resulting from changes to customers’ development plans, we reviewed the carrying amounts of our crude oil, natural gas, freshwater and produced and flowback water asset groups in the Williston Basin and the Delaware Basin for recoverability during the first quarter of 2020. We determined the carrying amounts of our crude oil and freshwater asset groups in the Williston Basin and our crude oil and produced and flowback water asset groups in the Delaware Basin were not recoverable and recorded an impairment charge of $101.8 million during the six months ended June 30, 2020 (see Item 1. “Financial Statements (Unaudited) — Notes to Condensed Consolidated Financial Statements — Note 6 — Property, Plant and Equipment”). We determined no impairment indicators were present as of June 30, 2020 and did not record an impairment charge to the carrying amount of our property, plant and equipment during the three months ended June 30, 2020.
If commodity prices continue to decline or remain at depressed levels for a prolonged period of time, if there are shut-ins of production from our customers’ existing producing wells or if there are significant changes in the future development plans of
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our customers, including Oasis Petroleum, to the extent they affect our operations, such circumstances may necessitate assessment of the carrying amount of our affected assets for recoverability and may result in additional impairment charges in the future. If the United States oil and gas industry continues to experience an imbalance of supply and demand, it is likely that our operations will be so affected and future impairment charges could be incurred.
COVID-19
On March 13, 2020, the United States declared the COVID-19 pandemic a national emergency, and several states, including Texas, North Dakota and Montana, and municipalities have declared public health emergencies. Along with these declarations, there have been extraordinary and wide-ranging actions taken by international, federal, state and local public health and governmental authorities to contain and combat the outbreak and spread of COVID-19 in regions across the United States and the world, including mandates for many individuals to substantially restrict daily activities and for many businesses to curtail or cease normal operations. These containment measures, while aiding in the prevention of further outbreak of COVID-19, have resulted in a severe drop in energy demand and general economic activity. To the extent COVID-19 continues or worsens, governments may impose additional similar restrictions. We have taken, and continue to take, proactive steps to manage any disruption in our business caused by COVID-19. For instance, even though our operations were not required to close, we were early adopters in employing a work-from-home system and have deployed additional safety protocols at our operating sites in order to keep our employees and contractors safe and to keep our operations running without material disruption.
The rapid and unprecedented decreases in energy demand have impacted certain elements of our distribution channels. We are also experiencing impacts from downstream markets, as certain pipelines no longer have the ability to transport production as refineries reduce activity or exercise force majeure clauses. Additionally, inventory surpluses have overwhelmed U.S. storage capacity, leading to a further strain on the supply chain. The constraints to the supply chain could force our customers, including Oasis Petroleum, to shut in production of certain U.S. onshore wells in the future, which would result in a further decline in demand for our services.
Due to a combination of the foregoing COVID-19 pandemic-related pressures and geopolitical pressures on the global supply and demand balance for crude oil and related products, commodity prices have experienced significant volatility in the first half of 2020 and have significantly declined since December 31, 2019. In response, we have revised our planned capital program for 2020 from what we previously disclosed in our 2019 Annual Report, and we will continue to evaluate our level of capital spending throughout the year. Please see “Liquidity and Capital Resources — Cash flows used in investing activities — 2020 Revised Capital Program” below for a further description of our revised 2020 capital program.
Highlights:
•Declared the quarterly cash distribution of $0.54 per unit.
•Net income was $22.7 million and net cash from operating activities was $51.5 million.
•Adjusted EBITDA(1) was $40.0 million and Adjusted EBITDA attributable to Oasis Midstream Partners LP(1) was $25.8 million.
•Distributable cash flow(1) (“DCF”) was $20.4 million and DCF coverage was 1.1x.
•Increased crude oil and produced water volumes from Oasis Petroleum and third parties in the Delaware Basin. Crude oil volumes increased approximately 200% from the first quarter of 2020 to 12.6 Mbopd during the three months ended June 30, 2020. Produced water volumes increased approximately 70% from the first quarter of 2020 to 50.7 Mbowpd during the three months ended June 30, 2020.
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The following table summarizes the throughput volumes, operating income (loss), depreciation, amortization and impairment and capital expenditures of each of our DevCos for the three and six months ended June 30, 2020 and 2019. The amounts shown in the table below are presented on a gross basis.
Three Months Ended June 30, Six Months Ended June 30,
2020 2019 2020 2019
(In thousands, except throughput volumes)
Bighorn DevCo
Crude oil services volumes (MBopd) 26.0    51.8    35.0    51.2   
Natural gas services volumes (MMscfpd) 155.2    201.6    198.8    197.3   
Operating income $ 8,934    $ 13,134    $ 10,259    $ 23,698   
Depreciation, amortization and impairment 5,297    2,959    26,941    6,694   
Capital expenditures 1,673    5,834    5,302    12,789   
Bobcat DevCo
Crude oil services volumes (MBopd) 21.1    41.3    27.1    41.9   
Natural gas services volumes (MMscfpd) 193.0    241.7    236.6    241.4   
Water services volumes (MBowpd) 44.3    52.4    52.8    51.8   
Operating income $ 15,822    $ 25,997    $ 28,244    $ 49,911   
Depreciation, amortization and impairment 4,224    3,252    25,567    6,171   
Capital expenditures 277    63,771    12,053    98,304   
Beartooth DevCo
Water services volumes (MBowpd) 53.7    143.7    93.5    138.4   
Operating income (loss) $ 2,031    $ 14,965    $ (17,872)   $ 28,474   
Depreciation, amortization and impairment 2,263    2,351    37,919    4,626   
Capital expenditures 311    6,989    (264)   15,944   
Panther DevCo
Crude oil services volumes (MBopd) 12.6    0.2    8.3    0.4   
Water services volumes (MBowpd) 50.7    29.4    40.4    27.8   
Operating income (loss) $ 2,352    $ 1,332    $ (29,708)   $ 2,627   
Depreciation, amortization and impairment 313    129    33,634    192   
Capital expenditures 219    6,830    9,829    12,495   
Oasis Midstream Partners LP
DevCo operating income (loss) $ 29,139    $ 55,428    $ (9,077)   $ 104,710   
Public company expenses 1,182    848    2,026    1,748   
Operating income (loss) 27,957    54,580    (11,103)   102,962   
Depreciation, amortization and impairment 12,097    8,691    124,061    17,682   
Equity-based compensation expenses 67    100    133    219   
Capitalized interest 68    240    317    302   
Maintenance capital expenditures 332    7,221    2,336    11,611   
Expansion capital expenditures 2,148    76,203    24,584    127,921   
Total capital expenditures 2,548    83,664    27,237    139,834   


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Items Affecting Comparability
2019 Delaware Acquisition. On November 1, 2019, we entered into an agreement with Oasis Petroleum to acquire certain crude oil gathering and produced and flowback water gathering and disposal assets in the Delaware Basin (the “2019 Delaware Acquisition”). The 2019 Delaware Acquisition was accounted for as a transfer of net assets between entities under common control. As a result, the financial information for the period prior to the effective date of November 1, 2019 has been recast. See Note 2 to our unaudited condensed consolidated financial statements.
Results of Operations
Revenues
We categorize our revenues as either service revenues or product sales to the respective line items described below.
•Midstream services - Oasis Petroleum. We record service revenues for fee-based arrangements with Oasis Petroleum for midstream services, including: (i) natural gas gathering, compression, processing, gas lift and NGL storage services; (ii) crude oil gathering, stabilization, blending, storage and transportation services; and (iii) produced and flowback water gathering and disposal services.
•Midstream services - third parties. We record service revenues for fee-based arrangements with third parties for crude oil and produced and flowback water services provided to non-affiliated customers.
•Product sales - Oasis Petroleum. We record product sales from Oasis Petroleum for the sale of crude oil and residue gas and NGLs to certain subsidiaries of Oasis Petroleum, which we generate from purchase agreements with third parties. We also record product sales from Oasis Petroleum for the supply and distribution of freshwater to Oasis Petroleum.
•Product sales - third parties. We record product sales from third parties for the supply and distribution of freshwater to non-affiliated customers.
The following table summarizes our revenues for the periods presented:
Three Months Ended June 30, Six Months Ended June 30,
2020 2019 Change 2020 2019 Change
(In thousands)
Revenues
Midstream services – Oasis Petroleum $ 56,946    $ 74,211    $ (17,265)   $ 138,939    $ 151,274    $ (12,335)  
Midstream services – third parties 5,242    1,825    3,417    9,088    2,952    6,136   
Product sales – Oasis Petroleum 3,869    24,348    (20,479)   24,657    40,000    (15,343)  
Product sales – third parties 6    19    (13)   6    29    (23)  
Total revenues $ 66,063    $ 100,403    $ (34,340)   $ 172,690    $ 194,255    $ (21,565)  

Three months ended June 30, 2020 as compared to three months ended June 30, 2019
Total midstream revenues decreased $34.3 million to $66.1 million during the three months ended June 30, 2020 as compared to the three months ended June 30, 2019. This decrease was driven by a $20.5 million decrease in product sales and a $13.8 million decrease in service revenues.
The $20.5 million decrease in product sales was driven by a $13.9 million decrease in natural gas product sales to Oasis Petroleum driven by lower residue gas and NGLs prices and fewer volumes from third party producers, coupled with a $6.7 million decrease in freshwater product sales due to a decrease in freshwater deliveries to Oasis Petroleum.
The $13.8 million decrease in service revenues was driven by a $9.6 million decrease in produced and flowback water service revenues due to a decrease in produced and flowback water volumes in the Williston Basin, coupled with $4.2 million decrease in crude oil and natural gas service revenues due to a decrease in natural gas and crude oil volumes in the Williston Basin.
Six months ended June 30, 2020 as compare to six months ended June 30, 2019
Total midstream revenues decreased $21.6 million to $172.7 million during the six months ended June 30, 2020 as compared to the six months ended June 30, 2019. This decrease was driven by a $15.4 million decrease in product sales and a $6.2 million decrease in service revenues.
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The $15.4 million decrease in product sales was driven by a $9.7 million decrease in natural gas product sales to Oasis Petroleum driven by lower residue gas and NGLs prices, partially offset by an increase in gas processing volumes from third party producers. In addition, there was a $5.8 million decrease in freshwater product sales due to a decrease in freshwater deliveries to Oasis Petroleum.
The $6.2 million decrease in service revenues was driven by a $7.4 million decrease in produced and flowback water service revenues due to fewer produced and flowback water volumes in the Williston Basin; partially offset by a $1.2 million increase in crude oil and natural gas service revenues primarily related to an increase in crude oil volumes in the Delaware Basin, coupled with approximately $1.5 million in deficiency fees associated with minimum volume commitments from third party producers in the Williston Basin.
Operating expenses and other expenses
The following table summarizes our operating expenses and other expenses for the periods presented:
Three Months Ended June 30, Six Months Ended June 30,
2020 2019 Change 2020 2019 Change
(In thousands)
Operating expenses
Costs of product sales $ 2,215    $ 12,022    $ (9,807)   $ 10,647    $ 20,087    $ (9,440)  
Operating and maintenance 14,508    17,276    (2,768)   31,348    36,966    (5,618)  
Depreciation and amortization 11,881    8,691    3,190    22,078    17,682    4,396   
Impairment 216    —    216    101,983    —    101,983   
General and administrative 9,286    7,834    1,452    17,737    16,557    1,180   
Total operating expenses 38,106    45,823    (7,717)   183,793    91,292    92,501   
Operating income (loss) 27,957    54,580    (26,623)   (11,103)   102,963    (114,066)  
Other expenses
Interest expense, net of capitalized interest (5,186)   (4,330)   (856)   (35,443)   (8,299)   (27,144)  
Other expenses (101)   (4)   (97)   (143)   (4)   (139)  
Total other expenses (5,287)   (4,334)   (953)   (35,586)   (8,303)   (27,283)  
Net income (loss) 22,670    50,246    (27,576)   (46,689)   94,660    (141,349)  
Less: Net income attributable to Delaware Predecessor —    1,211    (1,211)   —    2,286    (2,286)  
Less: Net income attributable to non-controlling interests 10,796    22,837    (12,041)   12,836    44,633    (31,797)  
Net income (loss) attributable to Oasis Midstream Partners LP 11,874    26,198    (14,324)   (59,525)   47,741    (107,266)  
Less: Net income attributable to General Partner 1,027    491    536    2,034    729    1,305   
Net income (loss) attributable to limited partners $ 10,847    $ 25,707    $ (14,860)   $ (61,559)   $ 47,012    $ (108,571)  

Three months ended June 30, 2020 as compared to three months ended June 30, 2019
Costs of product sales. Costs of product sales decreased $9.8 million to $2.2 million for the three months ended June 30, 2020 as compared to the three months ended June 30, 2019. The decrease was primarily driven by an $8.4 million decrease in natural gas costs of product sales due to lower residue gas and NGLs prices, coupled with a $1.7 million decrease in freshwater costs of product sales due to a reduction in freshwater supply and distribution costs related to fewer freshwater deliveries to Oasis Petroleum.
Operating and maintenance. Operating and maintenance expenses decreased $2.8 million to $14.5 million for the three months ended June 30, 2020. The decrease was primarily driven by a $2.2 million decrease in produced and flowback water operating and maintenance expenses related to lower activity, coupled with a $0.5 million decrease in crude oil and natural gas operating and maintenance expenses associated with lower activity.
Depreciation and amortization. Depreciation and amortization expenses increased $3.2 million to $11.9 million for the three months ended June 30, 2020. This increase was driven by the acceleration of depreciation expense related to mechanical
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refrigeration units which were decommissioned at our gas processing complex in Wild Basin during the three months ended June 30, 2020.
Impairment. We recorded an impairment loss of $0.2 million for the three months ended June 30, 2020 to adjust the carrying value of our spare parts and equipment inventory to its net realizable value. No impairment loss was recorded for the three months ended June 30, 2019.
General and administrative (“G&A”) expenses. G&A expenses increased $1.5 million to $9.3 million for the three months ended June 30, 2020. The increase was primarily a result of an increase in allocated charges from Oasis Petroleum for G&A services related to increased support from Oasis Petroleum due to organizational growth of the midstream business segment.
Interest expense, net of capitalized interest. Interest expense, net of capitalized interest, increased $0.9 million to $5.2 million for the three months ended June 30, 2020 as compared to the three months ended June 30, 2019. The increase was primarily due to an additional interest charge of $2.1 million pursuant to the Limited Waiver (defined below in “Liquidity and Capital Resources — Cash flows provided by (used in) financing activities”), offset by a reduction in the weighted average borrowing rate.
Six months ended June 30, 2020 as compared to six months ended June 30, 2019
Costs of product sales. Cost of product sales decreased $9.4 million to $10.6 million for the six months ended June 30, 2020 as compared to the six months ended June 30, 2019. The decrease was primarily driven by a $9.0 million decrease in natural gas costs of product sales driven by lower residue gas and NGLs prices, coupled with a $0.7 million decrease in freshwater costs of product sales due to a reduction in freshwater supply and distributions costs related to fewer freshwater deliveries to Oasis Petroleum.
Operating and maintenance. Operating and maintenance expenses decreased $5.6 million to $31.3 million for the six months ended June 30, 2020 as compared to the six months ended June 30, 2019. The decrease was primarily driven by a $2.2 million decrease in produced and flowback water operating and maintenance expenses related to lower activity, coupled with a $2.0 million decrease in crude oil operating and maintenance expenses and a $1.4 million decrease in natural gas operating and maintenance expenses.
Depreciation and amortization. Depreciation and amortization expenses increased $4.4 million to $22.1 million for the six months ended June 30, 2020. The increase was a result of additional assets placed into service, coupled with the acceleration of depreciation expense related to mechanical refrigeration units which were decommissioned at our gas processing complex in Wild Basin during the six months ended June 30, 2020.
Impairment. Impairment expense increased to $102.0 million for the six months ended June 30, 2020. We recorded an impairment charge of $101.8 million for the six months ended June 30, 2020 to adjust the carrying value of our property, plant and equipment to fair value. In addition, we recorded an impairment charge of $0.2 million for the six months ended June 30, 2020 to adjust the carrying value of our spare parts and equipment inventory to its net realizable value. No impairment charge was recorded for the six months ended June 30, 2019.
G&A expenses. G&A expenses increased $1.2 million to $17.7 million for the six months ended June 30, 2020. The increase was primarily a result of an increase in allocated charges from Oasis Petroleum for G&A services related to increased support from Oasis Petroleum due to organizational growth of the midstream business segment, coupled with an increase in public company G&A expenses.
Interest expense, net of capitalized interest. Interest expense, net of capitalized interest, increased $27.1 million to $35.4 million for the six months ended June 30, 2020 as compared to the six months ended June 30, 2019. The increase was primarily due to an additional interest charge of $28.0 million pursuant to the Limited Waiver (defined below in “Liquidity and Capital Resources — Cash flows provided by (used in) financing activities”), offset by a reduction in the weighted average borrowing rate.

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Liquidity and Capital Resources
Our primary sources of liquidity are cash flows generated from operations and borrowings under our Revolving Credit Facility. We believe cash generated from these sources will be sufficient to meet our short-term working capital needs, long-term capital expenditure requirements and quarterly cash distributions. We expect to fund future expansion capital expenditures and acquisitions primarily through a combination of borrowings under our Revolving Credit Facility and, if necessary, the issuance of additional equity or debt securities. Our primary uses of cash have been for capital expenditures towards our midstream infrastructure, dropdown acquisitions from Oasis Petroleum, distributions to our unitholders, payment of operating costs and interest payments on outstanding debt. We expect our future cash requirements relating to working capital, maintenance capital expenditures and quarterly cash distributions to our unitholders will be funded from cash flows internally generated from our operations. We expect to have adequate liquidity to meet our future cash requirements; however, extended disruptions in the financial markets and/or energy price volatility that adversely affect our business may have a material adverse effect on our financial position, results of operations or cash flows, as well as our ability to access sources of capital. Please see Part II. Item 1A. “Risk Factors” for more information regarding such risks. 
Oasis Petroleum has expressed substantial doubt about its ability to continue to operate as a going concern. We are largely dependent on Oasis Petroleum as our most significant customer, and the impact of financial distress at Oasis Petroleum could have a material adverse effect on our results of operations. We believe we will continue to provide midstream services pursuant to our commercial agreements with Oasis Petroleum, and we expect to have sufficient liquidity to meet our obligations as they come due during the next twelve months. We do not have any near-term debt maturities, as our Revolving Credit Facility matures on September 25, 2022, and there are not any cross-acceleration or cross-default provisions between the Oasis Petroleum credit agreement and our Revolving Credit Facility. We do not expect a violation of any financial covenants contained in our Revolving Credit Facility during the next twelve months.
Our cash flows for the six months ended June 30, 2020 and 2019 are presented below:
Six Months Ended June 30,
2020 2019
(In thousands)
Net cash provided by operating activities $ 113,145    $ 115,704   
Net cash used in investing activities (46,740)   (141,868)  
Net cash provided by (used in) financing activities (43,432)   25,761   
Increase (decrease) in cash and cash equivalents $ 22,973    $ (403)  
Cash flows provided by operating activities
Net cash provided by operating activities was $113.1 million and $115.7 million for the six months ended June 30, 2020 and 2019, respectively. The $2.6 million decrease in cash flows from operating activities for the six months ended June 30, 2020, as compared to 2019, was primarily due to lower net income, offset by non-cash charges and working capital changes.
Working capital. Our working capital is driven by changes in accounts receivable and accounts payable and other factors, such as credit extended to, and the timing of collections from, our customers. As of June 30, 2020, we had a working capital balance of $15.2 million. As of June 30, 2020, we had $114.6 million of liquidity available, including $27.1 million in cash and cash equivalents and $87.5 million in unused borrowing capacity on our Revolving Credit Facility. Our Revolving Credit Facility matures on September 25, 2022.
We expect to have adequate liquidity to meet our future working capital requirements; however, extended disruptions in the financial markets and/or energy price volatility that adversely affect our business may have a material adverse effect on our financial position, results of operations or cash flows.
Cash flows used in investing activities
Net cash used in investing activities was $46.7 million and $141.9 million for the six months ended June 30, 2020 and 2019, respectively. The $95.1 million decrease in net cash used in investing activities for the six months ended June 30, 2020, as compared to 2019, was primarily attributable to a reduction in capital spending on midstream infrastructure in Wild Basin.
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Capital expenditures.
Our capital expenditures are summarized in the following table, on a gross and net basis, for the period presented:
1Q 2020 2Q 2020 Six Months Ended June 30, 2020
(In thousands)
Capital expenditures Gross Net Gross Net Gross Net
Maintenance capital expenditures $ 2,004    $ 1,433    $ 332    $ 460    $ 2,336    $ 1,893   
Expansion capital expenditures
22,436    15,566    2,148    1,748    24,584    17,314   
Capitalized interest 249    249    68    68    317    317   
Total capital expenditures (1)
$ 24,689    $ 17,248    $ 2,548    $ 2,276    $ 27,237    $ 19,524   
___________________
(1)Capital expenditures reflected in the table above differ from capital expenditures shown in the statement of cash flows in our unaudited condensed consolidated financial statements because amounts reflected in the table above include changes in accrued capital expenditures from the previous reporting period, while amounts presented in the statements of cash flows are presented on a cash basis.
Our capital expenditures by DevCo are summarized in the following table, on a gross and net basis, for the period presented:
  1Q 2020 2Q 2020 Six Months Ended June 30, 2020
  (In thousands)
DevCos
OMP
Ownership(2)
Gross Net Gross Net Gross Net
Bighorn DevCo 100% $ 3,629    $ 3,629    $ 1,673    $ 1,673    $ 5,302    $ 5,302   
Bobcat DevCo 35.3% 11,776    4,163    277    98    12,053    4,261   
Beartooth DevCo(3)
70% (575)   (403)   311    218    (264)   (185)  
Panther DevCo 100% 9,610    9,610    219    219    9,829    9,829   
OMP Operating 100% 249    249    68    68    317    317   
Total(1)
$ 24,689    $ 17,248    $ 2,548    $ 2,276    $ 27,237    $ 19,524   
___________________
(1)Capital expenditures reflected in the table above differ from capital expenditures shown in the statements of cash flows in our unaudited condensed consolidated financial statements because amounts reflected in the table above include changes in accrued capital expenditures from the previous reporting period, while amounts presented in the statements of cash flows are presented on a cash basis.
(2)Ownership interest as of June 30, 2020.
(3)Negative amounts reflect immaterial differences between the estimated capital expenditures accrued in a reporting period and actual capital expenditures recognized in a subsequent reporting period.
2020 Revised Capital Program. We revised our planned capital program from what we disclosed in our 2019 Annual Report as a result of current market conditions. Our revised 2020 capital program, excluding acquisitions, will accommodate a gross capital expenditure level of approximately $36.0 million to $40.0 million, with approximately $25.0 million to $30.0 million attributable to the Partnership. We expect to spend approximately 6% to 8% of EBITDA for maintenance capital expenditures, which is included in our total capital expenditure program. We will continue to evaluate the level of capital spending throughout the year based on the following factors, among others:
•pace of our customers’ development;
•operating and construction costs;
•our ability to achieve material supplier price reductions;
•indebtedness levels; and
•impact of new laws and regulations on our business practices.
We expect to fund our capital expenditures with cash on hand, cash generated from operating activities and borrowings under our Revolving Credit Facility.
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Cash flows provided by (used in) financing activities
Net cash used in financing activities was $43.4 million for the six months ended June 30, 2020 and net cash provided by financing activities was $25.8 million for the six months ended June 30, 2019. The $69.2 million decrease in net cash from financing activities was primarily attributable to a $61.0 million decrease in net borrowings under the Revolving Credit Facility and a $7.1 million increase in distributions to unitholders.
Revolving Credit Facility. At June 30, 2020, we had $575.0 million of commitments under the Revolving Credit Facility. The Revolving Credit Facility is available to fund working capital and to finance acquisitions and other capital expenditures. At June 30, 2020, we had $487.5 million of borrowings outstanding under the Revolving Credit Facility and a de minimis outstanding letter of credit. At June 30, 2020, the weighted average interest rate related to outstanding borrowings under the Revolving Credit Facility was 1.9%. The unused borrowing capacity on the Revolving Credit Facility was $87.5 million as of June 30, 2020.
The Revolving Credit Facility requires the Partnership to maintain the following financial covenants as of the end of each fiscal quarter:
Consolidated Total Leverage Ratio: Prior to the date on which one or more of the credit parties have issued an aggregate principal amount of at least $150.0 million of senior notes (as permitted under the Revolving Credit Facility) (such date the “Covenant Changeover Date”) and commencing with the fiscal quarter ended December 31, 2017, the Partnership and OMP Operating’s ratio of Total Debt to EBITDA (each as defined in the Revolving Credit Facility) on a quarterly basis may not exceed 4.50 to 1.00 (or during an acquisition period (as defined in the Revolving Credit Facility), 5.00 to 1.00). On a quarterly basis following the Covenant Changeover Date, the Partnership and OMP Operating’s ratio of Total Debt to EBITDA may not exceed 5.25 to 1.00.
Consolidated Senior Secured Leverage Ratio: On a quarterly basis, commencing with the date the Covenant Changeover Date occurs, the Partnership and OMP Operating’s ratio of Consolidated Senior Secured Funded Debt to EBITDA (each as defined in the Revolving Credit Facility) may not exceed 3.75 to 1.00.
Consolidated Interest Coverage Ratio: On a quarterly basis prior to the Covenant Changeover Date and commencing with the fiscal quarter ended December 31, 2017, the Partnership and OMP Operating’s ratio of EBITDA to Consolidated Interest Expense (each as defined in the Revolving Credit Facility) may not be less than 3.00 to 1.00 and on a quarterly basis following the Covenant Changeover Date, the Partnership and OMP Operating’s ratio of EBITDA to Consolidated Interest Expense may not be less than 2.50 to 1.00.
As a result of ongoing internal oversight processes during the six months ended June 30, 2020, we identified that a Control Agreement (as defined in the Revolving Credit Facility) had not been executed for a certain bank account (the “JPM Account”) held at JPMorgan Chase Bank, N.A. (“JPMorgan”), who is a lender under the Revolving Credit Facility. The Control Agreement serves to establish a lien in favor of the lenders under the Revolving Credit Facility with respect to the JPM Account. On May 11, 2020, we executed a Control Agreement with both the Administrative Agent and JPMorgan, thereby completing the documentation required under the Revolving Credit Facility. Despite the Control Agreement’s execution, the failure to have had it in place before the JPM Account was initially funded with cash represented a past Event of Default (as defined in the Revolving Credit Facility). On May 15, 2020, we entered into a limited waiver (the “Limited Waiver”) of this past Event of Default with the Majority Lenders (as defined in the Revolving Credit Facility), which provides forbearance of additional interest owed arising from this past Event of Default until the earlier of (i) November 10, 2020 and (ii) an Event of Default. Pursuant to the Limited Waiver, we recorded additional interest charges of $2.1 million and $28.0 million during the three and six months ended June 30, 2020, respectively. The Limited Waiver excludes the additional interest from the calculation of the interest coverage ratio financial covenant.
We were in compliance with the covenants under the Revolving Credit Facility at June 30, 2020.

Cash Distributions
On August 4, 2020, the Board of Directors of the General Partner declared the quarterly distribution for the second quarter of 2020 of $0.54 per unit. In addition, the General Partner will receive a cash distribution of $1.0 million attributable to the incentive distribution rights related to earnings for the second quarter of 2020. These distributions will be payable on August 27, 2020 to unitholders of record as of August 14, 2020.
As we continue to adjust our outlook for estimated impacts of an economic downturn resulting from COVID-19 and unfavorable commodity demand and prices, we could reevaluate our cash distributions to help preserve flexibility and maintain balance sheet strength. The Board of Directors of our General Partner may change our cash distribution policy at any time, and we do not have a legal or contractual obligation to pay cash distributions quarterly or on any other basis or at our minimum quarterly distribution rate.
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Non-GAAP Financial Measures
Cash Interest, Adjusted EBITDA and Distributable Cash Flow are supplemental non-GAAP financial measures that are used by management and external users of the Partnership’s financial statements, such as industry analysts, investors, lenders and rating agencies. These non-GAAP financial measures should not be considered in isolation or as a substitute for interest expense, net income (loss), operating income (loss), net cash provided by (used in) operating activities or any other measures prepared under GAAP. Because Cash Interest, Adjusted EBITDA and Distributable Cash Flow exclude some but not all items that affect interest expense, net income and net cash provided by operating activities and may vary among companies, the amounts presented may not be comparable to similar metrics of other companies.
Cash Interest
Cash Interest is defined as interest expense plus capitalized interest less amortization of deferred financing costs included in interest expense. Cash Interest is not a measure of interest expense as determined by GAAP. Management believes that the presentation of Cash Interest provides useful additional information to investors and analysts for assessing the interest charges incurred on the Partnership’s debt, excluding non-cash amortization and the Partnership’s ability to maintain compliance with its debt covenants.
The following table presents a reconciliation of the GAAP financial measure of interest expense, net of capitalized interest, to the non-GAAP financial measure of Cash Interest for the periods presented:
  Three Months Ended June 30, Six Months Ended June 30,
 
2020(1)
2019
2020(1)
2019
(In thousands)
Interest expense, net of capitalized interest $ 5,186    $ 4,330    $ 35,443    $ 8,299   
Capitalized interest 68    240    317    302   
Amortization of deferred financing costs (271)   (226)   (541)   (417)  
Cash Interest 4,983    4,344    35,218    8,184   
Less: Cash Interest attributable to Delaware Predecessor —    (208)   —    (456)  
Less: Cash Interest attributable to non-controlling interests(2)
(3)   (3)   (6)   (5)  
Cash Interest attributable to Oasis Midstream Partners LP $ 4,980    $ 4,133    $ 35,212    $ 7,723   
__________________
(1)Cash Interest and Cash Interest attributable to Oasis Midstream Partners LP include an additional interest charge of $2.1 million for the three months ended June 30, 2020 and $28.0 million for the six months ended June 30, 2020 pursuant to the Limited Waiver.
(2)Amounts represent Cash Interest attributable to non-controlling interests associated with finance leases.
Adjusted EBITDA
Adjusted EBITDA is defined as earnings (loss) before interest expense (net of capitalized interest), income taxes, depreciation, amortization, impairment, equity-based compensation expenses and other similar non-cash adjustments. Adjusted EBITDA attributable to Oasis Midstream Partners LP is defined as Adjusted EBITDA less Adjusted EBITDA attributable to Oasis Petroleum’s retained interests in two of the Partnership’s DevCos, Bobcat DevCo and Beartooth DevCo. Adjusted EBITDA should not be considered an alternative to net income (loss), net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Management believes that the presentation of Adjusted EBITDA provides information useful to investors and analysts for assessing the Partnership’s results of operations, financial performance and the Partnership’s ability to generate cash from its business operations without regard to the Partnership’s financing methods or capital structure, coupled with the Partnership’s ability to maintain compliance with its debt covenants. The GAAP measures most directly comparable to Adjusted EBITDA are net income (loss) and net cash provided by operating activities.
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Distributable Cash Flow
Distributable Cash Flow is defined as Adjusted EBITDA attributable to Oasis Midstream Partners LP less Cash Interest attributable to Oasis Midstream Partners LP and maintenance capital expenditures attributable to Oasis Midstream Partners LP. Distributable Cash Flow should not be considered an alternative to net income (loss), net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Management believes that the presentation of Distributable Cash Flow provides information useful to investors and analysts for assessing the Partnership’s results of operations, financial performance and the Partnership’s ability to generate cash from its business operations without regard to the Partnership’s financing methods or capital structure, coupled with the Partnership’s ability to make distributions to its unitholders. The GAAP measures most directly comparable to Distributable Cash Flow are net income (loss) and net cash provided by operating activities.
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The following table presents reconciliations of the GAAP financial measures of net income (loss) and net cash provided by operating activities to the non-GAAP financial measures of Adjusted EBITDA and Distributable Cash Flow for the periods presented:
  Three Months Ended June 30, Six Months Ended June 30,
  2020 2019 2020 2019
(In thousands)
Net income (loss) $ 22,670    $ 50,246    $ (46,689)   $ 94,660   
Depreciation and amortization 11,881    8,691    22,078    17,682   
Impairment 216    —    101,983    —   
Equity-based compensation expense 67    100    133    219   
Interest expense, net of capitalized interest 5,186    4,330    35,443    8,299   
Adjusted EBITDA 40,020    63,367    112,948    120,860   
Less: Adjusted EBITDA attributable to Delaware Predecessor —    1,461    —    2,819   
Less: Adjusted EBITDA attributable to non-controlling interests 14,208    25,836    40,746    50,483   
Adjusted EBITDA attributable to Oasis Midstream Partners LP 25,812    36,070    72,202    67,558   
Less: Cash Interest attributable to Oasis Midstream Partners LP 4,980    4,133    35,212    7,723   
Less: Maintenance capital expenditures attributable to Oasis Midstream Partners LP 460    3,167    1,893    4,834   
Distributable Cash Flow attributable to Oasis Midstream Partners LP(1)
$ 20,372    $ 28,770    $ 35,097    $ 55,001   
Net cash provided by operating activities $ 51,479    $ 58,611    $ 113,145    $ 115,704   
Interest expense, net of capitalized interest 5,186    4,330    35,443    8,299   
Changes in working capital (16,375)   648    (35,099)   (2,729)  
Other non-cash adjustments (270)   (222)   (541)   (414)  
Adjusted EBITDA 40,020    63,367    112,948    120,860   
Less: Net income attributable to Delaware Predecessor —    1,461    —    2,819   
Less: Adjusted EBITDA attributable to non-controlling interests 14,208    25,836    40,746    50,483   
Adjusted EBITDA attributable to Oasis Midstream Partners LP 25,812    36,070    72,202    67,558   
Less: Cash Interest attributable to Oasis Midstream Partners LP 4,980    4,133    35,212    7,723   
Less: Maintenance capital expenditures attributable to Oasis Midstream Partners LP 460    3,167    1,893    4,834   
Distributable Cash Flow attributable to Oasis Midstream Partners LP(1)
$ 20,372    $ 28,770    $ 35,097    $ 55,001   
__________________
(1)For the three and six months ended June 30, 2020, Distributable Cash Flow attributable to Oasis Midstream Partners LP is reduced by additional interest charges of $2.1 million and $28.0 million, respectively, pursuant to the Limited Waiver.
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Off-Balance Sheet Arrangements
In the ordinary course of business, we enter into various commitment agreements and other contractual obligations, some of which are not recognized in our condensed consolidated financial statements, in accordance with GAAP. As of June 30, 2020, our material off-balance sheet arrangements and transactions include a de minimis outstanding letter of credit issued under our Revolving Credit Facility (see Item 1. “Financial Statements (Unaudited) — Notes to Condensed Consolidated Financial Statements — Note 7 — Long-Term Debt”) and $2.5 million in surety bonds issued as financial assurance on certain agreements. See Item 1. “Financial Statements (Unaudited) — Notes to Condensed Consolidated Financial Statements — Note 9 — Commitments and Contingencies” for a description of our commitments and contingencies.
Critical Accounting Policies and Estimates
There have been no material changes to our critical accounting policies and estimates from those disclosed in our 2019 Annual Report other than as disclosed in Note 2 to our unaudited condensed consolidated financial statements.
Item 3. — Quantitative and Qualitative Disclosures About Market Risk
The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our potential exposure to market risk. The term “market risk” refers to the risk of loss arising from adverse changes in commodity prices and interest rates. The disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses. This forward-looking information provides indicators of how we view and manage our ongoing market risk exposures.
Concentration of customer credit risk. We are dependent on Oasis Petroleum as our most significant customer, and we expect to derive a substantial majority of our revenues from Oasis Petroleum for the foreseeable future. As a result, any event, whether in our dedicated areas or otherwise, that adversely affects Oasis Petroleum’s production, drilling schedule, financial condition, leverage, market reputation, liquidity, results of operations or cash flows may adversely affect our revenues and cash available for distribution. Further, we are subject to the risk of non-payment or non-performance by Oasis Petroleum. We cannot predict the extent to which Oasis Petroleum’s business would be impacted if conditions in the energy industry were to deteriorate, nor can we estimate the impact such conditions would have on Oasis Petroleum’s ability to execute its drilling and development program or to perform under our agreements. Any material non-payment or non-performance by Oasis Petroleum could reduce our ability to make distributions to our unitholders. We did not experience any significant defaults on accounts receivable for the six months ended June 30, 2020. Please see Part II. Item 1A. “Risk Factors” for more information regarding credit risk of our customers.
Commodity price risk. We have limited direct exposure to risks associated with fluctuating commodity prices due to the nature of our business and our long-term, fixed-fee arrangements with Oasis Petroleum. However, to the extent that our future contractual arrangements with Oasis Petroleum or third parties do not provide for fixed-fee structures, we may become subject to commodity price risk. Additionally, as a substantial portion of our revenues are derived from Oasis Petroleum, we will be indirectly subject to risks associated with fluctuating commodity prices to the extent that lower commodity prices adversely affect Oasis Petroleum’s production, drilling schedule, financial condition, leverage, market reputation, liquidity, results of operations or cash flows. As further described in “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations,” the commodity price environment is expected to remain depressed based on over-supply and decreasing demand of crude oil and related products. We cannot predict whether or when crude oil production and economic activities will return to normalized levels. Please see Part II, Item 1A. “Risk Factors” for more information regarding commodity price risks.
Interest rate risk. We have a Revolving Credit Facility which provides for an aggregate commitment amount of $575.0 million as of June 30, 2020. At June 30, 2020, we had $487.5 million of borrowings under the Revolving Credit Facility. Borrowings under the Revolving Credit Facility bear interest at a rate per annum equal to the applicable margin (as described below) plus (i) with respect to Eurodollar Loans, the Adjusted LIBO Rate (as defined in the Revolving Credit Facility) or (ii) with respect to ABR Loans (as defined in the Revolving Credit Facility), the greatest of (a) the Prime Rate in effect on such day, (b) the Federal Funds Effective Rate in effect on such day plus 1/2 of 1.00% or (c) the Adjusted LIBO Rate for a one-month interest period on such day plus 1.00% (each as defined in the Revolving Credit Facility). The applicable margin for borrowings under the Revolving Credit Facility is based on the Partnership’s most recently tested consolidated total leverage ratio and varies from (a) in the case of Eurodollar Loans, 1.75% to 2.75%, and (b) in the case of ABR Loans or swingline loans, 0.75% to 1.75%. The unused portion of the Revolving Credit Facility is subject to a commitment fee ranging from 0.375% to 0.500%.
At June 30, 2020, the outstanding borrowings under our Revolving Credit Facility bore interest at the London Interbank Offered Rate plus a 1.75% margin. We do not currently, but may in the future, utilize interest rate derivatives to reduce interest rate exposure in an attempt to reduce interest rate expense related to debt issued under our Revolving Credit Facility. Interest rate derivatives would be used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio.
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Item 4. — Controls and Procedures
Evaluation of disclosure controls and procedures. As required by Rule 13a-15(b) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), we have evaluated, under the supervision and with the participation of our management, including our Chief Executive Officer (“CEO”), our principal executive officer, and our Chief Financial Officer (“CFO”), our principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of June 30, 2020. Our disclosure controls and procedures are designed to provide reasonable assurance that information required to be disclosed by us in the reports filed or submitted by us under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our CEO and CFO as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, our CEO and CFO have concluded that our disclosure controls and procedures were effective at June 30, 2020.
Changes in internal control over financial reporting. There were no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) and Rule 15d-15(f) under the Exchange Act) that occurred during the three months ended June 30, 2020, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II — OTHER INFORMATION
Item 1. — Legal Proceedings
Our operations are subject to a variety of risks and disputes normally incident to our business. As a result, we may, at any given time, be a defendant in various legal proceedings and litigation arising in the ordinary course of business. However, except as disclosed below, we are not currently subject to any potentially material litigation. We maintain insurance policies with insurers in amounts and with coverage and deductibles that we, with the advice of our insurance advisors and brokers, believe are reasonable and prudent. We cannot, however, assure our unitholders that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal and property damage or that these levels of insurance will be available in the future at economical prices.
Mirada litigation. On March 23, 2017, Mirada Energy, LLC, Mirada Wild Basin Holding Company, LLC and Mirada Energy Fund I, LLC (collectively, “Mirada”) filed a lawsuit against Oasis Petroleum, Oasis Petroleum North America LLC (“OPNA”), and OMS, seeking monetary damages in excess of $100 million, declaratory relief, attorneys’ fees and costs (Mirada Energy, LLC, et al. v. Oasis Petroleum North America LLC, et al.; in the 334th Judicial District Court of Harris County, Texas; Case Number 2017-19911). Mirada asserts that it is a working interest owner in certain acreage owned and operated by Oasis Petroleum in Wild Basin. Specifically, Mirada asserts that Oasis Petroleum has breached certain agreements by: (1) failing to allow Mirada to participate in Oasis Petroleum’s midstream operations in Wild Basin; (2) refusing to provide Mirada with information that Mirada contends is required under certain agreements and failing to provide information in a timely fashion; (3) failing to consult with Mirada and failing to obtain Mirada’s consent prior to drilling more than one well at a time in Wild Basin; and (4) overstating the estimated costs of proposed well operations in Wild Basin. Mirada seeks a declaratory judgment that Oasis Petroleum be removed as operator in Wild Basin at Mirada’s election and that Mirada be allowed to elect a new operator; certain agreements apply to Oasis Petroleum and Mirada and Wild Basin with respect to this dispute; Oasis Petroleum be required to provide all information within its possession regarding proposed or ongoing operations in Wild Basin; and Oasis Petroleum not be permitted to drill, or propose to drill, more than one well at a time in Wild Basin without obtaining Mirada’s consent. Mirada also seeks a declaratory judgment with respect to Oasis Petroleum’s current midstream operations in Wild Basin. Specifically, Mirada seeks a declaratory judgment that Mirada has a right to participate in Oasis Petroleum’s Wild Basin midstream operations, consisting of produced and flowback water disposal, crude oil gathering and natural gas gathering and processing; that, upon Mirada’s election to participate, Mirada is obligated to pay its proportionate costs of Oasis Petroleum’s midstream operations in Wild Basin; and that Mirada would then be entitled to receive a share of revenues from the midstream operations and would not be charged any amount for its use of these facilities for production from the “Contract Area.”
On June 30, 2017, Mirada amended its original petition to add a claim that Oasis Petroleum has breached certain agreements by charging Mirada for midstream services provided by its affiliates and to seek a declaratory judgment that Mirada is entitled to be paid its share of total proceeds from the sale of hydrocarbons received by OPNA or any affiliate of OPNA without deductions for midstream services provided by OPNA or its affiliates.
On February 2, 2018 and February 16, 2018, Mirada filed a second and third amended petition, respectively. In these filings, Mirada alleged new legal theories for being entitled to enforce the underlying contracts, and added Bighorn DevCo, Bobcat DevCo and Beartooth DevCo as defendants, asserting that these entities were created in bad faith in an effort to avoid contractual obligations owed to Mirada.
On March 2, 2018, Mirada filed a fourth amended petition that described Mirada’s alleged ownership and assignment of interests in assets purportedly governed by agreements at issue in the lawsuit. On August 31, 2018, Mirada filed a fifth amended petition that added the Partnership as a defendant, asserting that it was created in bad faith in an effort to avoid contractual obligations owed to Mirada.
On July 2, 2019, Oasis Petroleum, OPNA, OMS, the Partnership, Bighorn DevCo, Bobcat DevCo and Beartooth DevCo (collectively “Oasis Entities”) counterclaimed against Mirada for a judgment declaring that Oasis Entities are not obligated to purchase, manage, gather, transport, compress, process, market, sell or otherwise handle Mirada’s proportionate share of oil and gas produced from OPNA-operated wells. The counterclaim also seeks attorney’s fees, costs and expenses.
On November 1, 2019, Mirada filed a sixth amended petition that stated that Mirada seeks in excess of $200 million in damages and asserted that OMS is an agent of OPNA and OPNA, OMS, the Partnership, Bighorn DevCo, Bobcat DevCo and Beartooth DevCo are agents of Oasis Petroleum. Mirada also changed its allegation that it may elect a new operator for the subject wells to instead allege that Mirada may remove Oasis Petroleum as operator.
On November 1, 2019, the Oasis Entities amended their counterclaim against Mirada for a judgment declaring that a provision in one of the agreements does not incorporate by reference any provisions in a certain participation agreement and joint operating agreement. The additional counterclaim also seeks attorney’s fees, costs and expenses. On the same day, the Oasis Entities filed an amended answer asserting additional defenses against Mirada’s claims.
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On March 13, 2020, Mirada filed a seventh amended petition that did not assert any new causes of action and did not add any new parties. Mirada did add an allegation that Oasis Petroleum breached its implied duty of good faith and fair dealing with respect to certain contracts.
On April 30, 2020, Mirada abandoned its prior claims related to overstating the estimated costs of proposed well operations in Wild Basin. At this point, it is unclear what impact this has on damages because Mirada asserts that its information and failure to consult and obtain consent claims result in the same damages as its abandoned estimated costs claim.
Oasis Petroleum and the Partnership believe that Mirada’s claims are without merit, that Oasis Petroleum has complied with its obligations under the applicable agreements and that some of Mirada’s claims are grounded in agreements that do not apply to Oasis Petroleum. Oasis Petroleum filed answers denying all of Mirada’s claims and intends and continues to vigorously defend against Mirada’s claims.
Discovery is ongoing, and each of the parties has made a number of procedural filings and motions, and additional filings and motions can be expected over the course of the claim. Trial is scheduled for October 2020. Neither the Partnership nor Oasis Petroleum can predict or guarantee the ultimate outcome or resolution of such matter. If such matter were to be determined adversely to the Partnership’s or Oasis Petroleum’s interests, or if the Partnership or Oasis Petroleum were forced to settle such matter for a significant amount, such resolution or settlement could have a material adverse effect on the Partnership's business, financial condition, results of operations and cash flows. Such an adverse determination could materially impact Oasis Petroleum’s ability to operate its properties in Wild Basin or develop its identified drilling locations in Wild Basin on its current development schedule. A determination that Mirada has a right to participate in Oasis Petroleum’s midstream operations could materially reduce the interests of Oasis Petroleum and the Partnership in the Partnership’s current assets and future midstream opportunities and related revenues in Wild Basin. Under the Omnibus Agreement the Partnership entered into with Oasis Petroleum in connection with the closing of the initial public offering, Oasis Petroleum agreed to indemnify the Partnership for any losses resulting from this litigation. However, the Partnership cannot guarantee that such indemnity will fully protect the Partnership from the adverse consequences of any adverse ruling.
Solomon litigation. On or about August 28, 2019, Oasis Petroleum LLC, a wholly-owned subsidiary of Oasis Petroleum (“OP LLC”), was named as a defendant in the lawsuit styled Andrew Solomon, on behalf of himself and those similarly situated v. Oasis Petroleum LLC, pending in the United States District Court for the District of North Dakota. The lawsuit alleged violations of the federal Fair Labor Standards Act (the “FLSA”) and Title 29 of the North Dakota Century Code (“Title 29”) as the result of OP LLC’s alleged practice of paying the plaintiff and similarly situated current and former employees overtime at rates less than required by applicable law, or failing to pay for certain overtime hours worked. The lawsuit requested that: (i) its federal claims be advanced as a collective action, with a class of all operators, technicians, and all other employees in substantially similar positions employed by OP LLC who were paid hourly for at least one week during the three-year period prior to the commencement of the lawsuit, who worked 40 or more hours in at least one workweek and/or eight or more hours on at least one workday; and (ii) its state claims be advanced as a class action, with a class of all operators, technicians, and all other employees in substantially similar positions employed by OP LLC in North Dakota during the two-year period prior to the commencement of the lawsuit, who worked 40 or more hours in at least one workweek and/or worked eight or more hours in a day on at least one workday. No motion has been filed for class certification, and the Partnership cannot predict whether such a motion will be filed or a class certified.
Oasis Petroleum believes that Mr. Solomon’s claims are without merit and that OP LLC has complied with its obligations under the FLSA and Title 29. OP LLC has filed an answer denying all of Mr. Solomon’s claims and intends to vigorously defend against the claims. The Partnership cannot predict or guarantee the ultimate outcome or resolutions of such matter. If such matter were to be determined adversely to Oasis Petroleum’s interests, or if Oasis Petroleum were forced to settle such matter for a significant amount, such resolution or settlement could have a material adverse effect on the Partnership’s business, financial condition, results of operations or cash flows.
Item 1A. — Risk Factors
Our business faces many risks. Any of the risks discussed elsewhere in this Form 10-Q and our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations.
For a discussion of our potential risks and uncertainties, see the information in Item 1A. “Risk Factors” in our 2019 Annual Report. Other than as described below, there have been no material changes in our risk factors from those described in our 2019 Annual Report.
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Events outside of our control, including a pandemic, epidemic or outbreak of an infectious disease, such as the recent global outbreak of COVID-19, have materially adversely affected, and may further materially adversely affect, our business.
We face risks related to pandemics, epidemics, outbreaks or other public health events that are outside of our control, and could significantly disrupt our operations and adversely affect our business and financial condition. For example, the recent global outbreak of COVID-19 has reduced demand for crude oil and natural gas and, consequently the demand for midstream services, because of significantly reduced global and national economic activity. On March 13, 2020, the United States declared the COVID-19 pandemic a national emergency, and several states, including Texas, North Dakota and Montana, and municipalities have declared public health emergencies. Along with these declarations, there have been extraordinary and wide-ranging actions taken by international, federal, state and local public health and governmental authorities to contain and combat the outbreak and spread of COVID-19 in regions across the United States and the world, including mandates for many individuals to substantially restrict daily activities and for many businesses to curtail or cease normal operations. To the extent COVID-19 continues or worsens, governments may impose additional similar restrictions.
In addition, the impact of COVID-19 or other public health events may adversely affect our operations or the health of our workforce and the workforces of our customers and service providers by rendering employees or contractors unable to work or unable to access our and their facilities for an indefinite period of time. There can be no assurance that our personnel will not be impacted by these pandemic diseases or ultimately lead to a reduction in our workforce productivity or increased medical costs or insurance premiums as a result of these health risks.
Further, the technology required for the corresponding transition to remote work increases our vulnerability to cybersecurity threats, including threats to gain unauthorized access to sensitive information or to render data or systems unusable, the impact of which may have material adverse effects on our business and operations. See “Item 1A. Risk Factors — Risks Related to Our Business — A cyber incident could result in information theft, data corruption, operational disruption and/or financial loss” in our Annual Report on Form 10-K for the year ended December 31, 2019.
As the potential impact from COVID-19 is uncertain due to the ongoing and dynamic nature of the circumstances, it is difficult to predict the extent to which it may negatively affect our business, including, without limitation, our operating results, financial position and liquidity, the duration of any potential disruption of our business, how and the degree to which the outbreak may impact our customers, supply chain and distribution network, the health of our employees, the productivity and sustainability of our workforce, our insurance premiums, costs attributable to our emergency measures, payments from customers and uncollectable accounts, limitations on travel, the availability of industry experts and qualified personnel and the market for our securities. Any potential impact will depend on future developments and new information that may emerge regarding the severity and duration of COVID-19 and the actions taken by authorities to contain it or treat its impact, all of which are beyond our control. These potential impacts, while uncertain, could continue to adversely affect global economies and financial markets and result in a persistent economic downturn that could have an adverse effect on the industries in which we and our customers operate and on the demand for our midstream services, our operating results and our future prospects. We cannot predict when the continuing adverse effect on us will end, and depending on the duration of the pandemic and its severity, this adverse effect could worsen.
Because a substantial majority of our revenue currently is, and over the long term is expected to be, derived from Oasis Petroleum, any development that materially and adversely affects Oasis Petroleum’s operations, financial condition or market reputation could have a material and adverse impact on us.
We are substantially dependent on Oasis Petroleum as our most significant current customer, and we expect to derive a substantial majority of our revenues from Oasis Petroleum for the foreseeable future. As a result of the recent COVID-19 outbreak or other adverse public health developments, including voluntary and mandatory quarantines, travel restrictions and other restrictions, the operations of our customers, including Oasis Petroleum, have and may continue to experience delays or disruptions and temporary suspensions of operations. Any event, whether in our areas of operation or otherwise, including a pandemic event such as COVID-19 and current geopolitical events involving OPEC and other non-OPEC, oil-producing countries, that adversely affects Oasis Petroleum’s production, drilling and completion schedule, financial condition, leverage, market reputation, liquidity, results of operations or cash flows may adversely affect our revenues and distributable cash. Accordingly, we are indirectly subject to the business risks of Oasis Petroleum, including, among others:
•worldwide and regional economic conditions impacting the global supply and demand for crude oil, natural gas and NGLs;
•the actions of OPEC and other non-OPEC, oil-producing countries, including Russia;
•events that impact global market demand, including impacts from global health epidemics and concerns, such as the COVID-19 pandemic, which has reduced and may continue to reduce demand for crude oil, natural gas and NGLs because of reduced economic activity;
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•a reduction in or slowing of Oasis Petroleum’s anticipated drilling and production schedule, which would directly and adversely impact demand for our midstream infrastructure;
•shut-in of existing production by Oasis Petroleum in areas dedicated to us, which would adversely affect our throughput volumes and revenues;
•the volatility of crude oil and natural gas prices, which could have a negative effect on the value of Oasis Petroleum’s properties, its drilling programs or its ability to finance its operations;
•the existence of substantial unresolved doubt about the ability of Oasis Petroleum to continue as a going concern;
•changes in regulations or statutes applicable to us or Oasis Petroleum, which could have a negative effect on the value of our facilities or services or Oasis Petroleum’s properties, its drilling programs or its ability to finance its operations;
•the availability of capital on an economic basis to fund Oasis Petroleum’s exploration and development activities;
•Oasis Petroleum’s ability to replace reserves;
•Oasis Petroleum’s ability to market and deliver commodities downstream of our systems;
•Oasis Petroleum’s drilling and operating risks, including potential environmental liabilities;
•severe weather that may adversely affect Oasis Petroleum’s production and operations;
•limitations on Oasis Petroleum’s operations resulting from its debt restrictions and financial covenants;
•adverse effects of governmental and environmental regulation; and
•losses from pending or future litigation.
In addition, although Oasis Petroleum has dedicated certain acreage to us under each of our commercial agreements with Oasis Petroleum, these commercial agreements do not contain any material minimum volume commitments. Accordingly, if commodity prices continue to decline or remain at their current levels for a prolonged period, Oasis Petroleum has the ability to substantially reduce its drilling and completion expenditures and/or shut-in existing producing wells, which would decrease our throughput volumes from Oasis Petroleum and related revenue streams under our commercial agreements.
Further, we are subject to the risk of non-payment or non-performance by Oasis Petroleum, including with respect to our long-term contracts for natural gas gathering, compression, processing and gas lift; crude oil gathering, stabilization, blending, storage and transportation; produced and flowback water gathering and disposal; and freshwater distribution. If Oasis Petroleum were to default under any of these contracts, we would have the contractual right to bring suit against Oasis Petroleum to enforce the terms of such contract, and there can be no assurance that we would obtain a recovery, or that any such recovery that would fully compensate us for the consequence of such default. We neither can predict the extent to which Oasis Petroleum’s business would be impacted if conditions in the energy industry continue to deteriorate or continue in their current state for an extended period of time, nor can we estimate the impact such conditions would have on Oasis Petroleum’s ability to execute its drilling and development program or perform under our commercial agreements. Any material non-payment or non-performance by Oasis Petroleum could reduce our ability to make distributions to our unitholders.
Also, due to our relationship with Oasis Petroleum, our ability to access the capital markets, or the pricing or other terms of any capital markets transactions, may be adversely affected by any impairment to Oasis Petroleum’s financial condition or adverse changes in its credit ratings. Further, if we were to seek a credit rating in the future, our credit rating may be adversely affected by Oasis Petroleum’s leverage or its dependence on the cash flows from us to service its indebtedness, as credit rating agencies such as Standard & Poor’s Ratings Services and Moody’s Investors Service may consider the credit profile of Oasis Petroleum and its affiliates because of their ownership interest in and control of us.
Any material limitation on our ability to access capital as a result of our relationship with Oasis Petroleum or adverse changes at Oasis Petroleum could limit our ability to obtain future financing under favorable terms, or at all, or could result in increased financing costs in the future. Similarly, material adverse changes at Oasis Petroleum could have a material adverse effect on our unit price, limiting our ability to raise capital through equity issuances or debt financing, or could negatively affect our ability to engage in, expand or pursue our business activities, and could also prevent us from engaging in certain transactions that might otherwise be considered beneficial to us.
Our exposure to commodity price risk may change over time and we cannot guarantee the terms of any existing or future agreements for our midstream services with third parties or with Oasis Petroleum.
We currently generate the majority of our revenues pursuant to fee-based agreements under which we are paid based on volumetric fees, rather than the underlying value of the commodity. Consequently, our existing operations and cash flows have minimal direct exposure to commodity price risk. However, Oasis Petroleum and our other upstream customers are exposed to commodity price risk, and extended reduction in commodity prices could reduce the future production volumes available for our midstream services below expected levels. Since the beginning of 2020, the daily spot prices for NYMEX WTI crude oil
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have ranged from a high of $63.27 per barrel to a low of $(36.98) per barrel, and the daily spot prices for NYMEX Henry Hub natural gas have ranged from a high of $2.17 per MMBtu to a low of $1.42 per MMBtu. The recent significant decline in crude oil prices has largely been attributable to the recent actions of Saudi Arabia and Russia, which have resulted in substantial increases in the global supply of crude oil. Specifically, in March 2020, Saudi Arabia and Russia failed to agree on a plan to extend production cuts that expired on April 1, 2020 within OPEC and other non-OPEC, oil-producing countries, including Russia. Subsequently, Saudi Arabia announced plans to increase production to record levels and to reduce the prices at which they sell crude oil. These events, combined with the continued global outbreak of COVID-19, which has significantly impacted both crude oil prices and natural gas prices due to substantially reduced demand for crude oil and natural gas because of reduced global and national economic activity, contributed to a sharp drop in prices for crude oil in the first quarter of 2020. The impact has not been as severe on natural gas prices, but such prices are susceptible to global actions impacting supply and demand.
In April 2020, OPEC announced an agreement among OPEC and other non-OPEC countries, including Russia, to reduce aggregate global production by approximately 10 million barrels a day in May and June of 2020, with gradually decreasing reductions in daily production through the end of 2020. While these cuts in production may offset some of the oversupply of the global crude oil market, crude oil prices have remained low and we cannot predict whether or when crude oil production and global economic activities will return to normalized levels.
Additionally, although we intend to maintain fee-based pricing terms on both new contracts and existing contracts for which prices have not yet been set, our efforts to negotiate such terms may not be successful, which could have a material adverse effect on our business. Furthermore, Oasis Petroleum and our other upstream customers may seek to renegotiate certain terms of our existing commercial agreements, including amendments to reduce the amount of fees that we charge under such agreements. If the current distressed nature of the global economy, and specific pressure on the crude oil and natural gas sector, causes us to have to accept fee reductions or other concessions in order to keep these contracts in place, such concessions may nonetheless have a material adverse effect on our revenues and distributable cash flows.
Restrictions in our Revolving Credit Facility could adversely affect our business, financial condition, results of operations and ability to make quarterly cash distributions to our unitholders.
Our Revolving Credit Facility contains a number of restrictive covenants that impose significant operating and financial restrictions on us, including restrictions on our ability to, among other things:
•incur or guarantee additional debt;
•redeem or repurchase units or make distributions under certain circumstances;
•make certain investments and acquisitions;
•incur certain liens or permit them to exist;
•enter into certain types of transactions with affiliates;
•merge or consolidate with another company; and
•transfer, sell or otherwise dispose of assets.
Our Revolving Credit Facility also contains covenants requiring us to maintain certain financial ratios and tests. Our ability to meet those financial ratios and tests can be affected by events beyond our control, and we cannot assure unitholders that we will meet any such ratios and tests.
In addition, our Revolving Credit Facility contains a condition to borrowing and a representation that no material adverse effect has occurred, which includes, among other things, a material adverse change in, or material adverse effect on the business, operations, property or condition (financial or otherwise) of us or our wholly-owned subsidiaries. If a material adverse effect were to occur, we would not be able to borrow under our credit facility and circumstances may arise that could lead to an event of default under the provisions of the Revolving Credit Facility, which could cause all of our existing indebtedness to become immediately due and payable.
The provisions of our Revolving Credit Facility may affect our ability to obtain future financing and pursue attractive business opportunities and our flexibility in planning for, and reacting to, changes in business conditions. In addition, a failure to comply with the provisions of our Revolving Credit Facility could result in a default or an event of default that could enable our lenders to declare the outstanding principal of that debt, together with accrued and unpaid interest, to be immediately due and payable. If the payment of our debt is accelerated, our assets may be insufficient to repay such debt in full, and our unitholders could experience a partial or total loss of their investment. Please read “Part II. Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources.”
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A shortage of equipment and skilled labor could reduce equipment availability and labor productivity and increase labor and equipment costs, which could have a material adverse effect on our business and results of operations.
Midstream infrastructure assets require special equipment and laborers skilled in multiple disciplines, such as equipment operators, mechanics and engineers, among others. Our reliance on skilled employees and independent contractors exposes us to the possibility of delay or interruption of our operations because of COVID-19. It is impossible to predict the effect of the continued spread, or fear of continued spread, of COVID-19 globally. Should COVID-19 continue to spread globally or within the U.S., our business, financial condition and results of operations could be materially and adversely impacted because it could result in a loss of available, skilled contractors or services. If we experience shortages of necessary equipment or skilled labor in the future, our labor and equipment costs and overall productivity could be materially and adversely affected. If our equipment or labor prices increase or if we experience materially increased health and benefit costs for employees, our results of operations could be materially and adversely affected.
The loss of key personnel could adversely affect our ability to operate.
We depend on the services of a relatively small group of our General Partner’s and Oasis Petroleum’s senior management and technical personnel. The public health concerns posed by COVID-19 could pose a risk to these key personnel and may render these individuals unable to work or travel. The extent to which COVID-19 may impact these key personnel, and subsequently our business, cannot be predicted at this time. We continue to monitor the situation, have actively implemented policies and practices to address the situation, and may adjust our current policies and practices as more information and guidance become available. We do not maintain, nor do we plan to obtain, any insurance against the loss of any of these individuals. Because competition for experienced personnel in the industry is intense, we may not be able to find acceptable replacements with comparable skills and experience. The loss of the services of our General Partner’s or Oasis Petroleum’s senior management or technical personnel could have a material adverse effect on our business, financial condition and results of operations.
Contracts with customers are subject to additional risk in the event of a bankruptcy proceeding.
To the extent any of our customers, including Oasis Petroleum, are in financial distress or commence bankruptcy proceedings, our contracts with them, including provisions relating to dedications of production, may be subject to renegotiation or rejection under applicable provisions of the United States Bankruptcy Code. If a contract with a customer is altered or rejected in bankruptcy proceedings, we could lose some or all of the expected revenues associated with that contract, which could cause the market price of our common units to decline. This may be exacerbated in the future as the COVID-19 outbreak and the governmental responses thereto continue. These factors, combined with volatile prices of crude oil and natural gas may precipitate a continued economic slowdown and/or a recession. Concerns about global economic growth have had a significant adverse impact on global financial markets and commodity prices. If the economic climate in the United States or abroad continues to deteriorate, demand for crude oil, natural gas and related products could further diminish, which will impact the demand for our customers’ products and therefore negatively affect our customers’ results of operations, liquidity and financial condition, resulting in significant financial distress for our customers.
If third-party pipelines or other facilities interconnected to our midstream systems become partially or fully shut down or otherwise unavailable, or if the volumes we gather or treat do not meet the quality specifications of such pipelines or facilities, our business, financial condition, results of operations, cash flows and ability to make distributions to our unitholders could be adversely affected.
Our midstream systems are connected to other pipelines or facilities, some of which are owned by third parties. The continuing operation of such pipelines or facilities is not within our control. In addition, these downstream operators may impose specifications for the products that they are willing to accept. If the total mix of a product fails to meet the applicable product quality specifications, these downstream operators may refuse to accept all or a part of the products or may invoice us for the costs to handle or damages from receiving out-of-specification products.
If any of these pipelines or facilities becomes partially or fully shutdown or otherwise unable to gather, transport, treat or process natural gas or crude oil, or if the volumes we gather or transport do not meet the quality specifications of such pipelines or facilities, our business, financial condition, results of operations, cash flows and ability to make distributions to our unitholders could be adversely affected.
On May 1, 2020, Northern Border Pipeline Company (“Northern Border”) submitted a tariff filing to the FERC in Docket No. RP20-859 proposing to modify the gas quality provisions of its FERC Gas Tariff to, among other things, establish a Btu safe harbor upper limit of 1,100 Btu per cubic foot, and when necessary, allow Northern Border to post an upper Btu limit if Northern Border is unable to blend gas receipts to achieve an overall heat content level of no higher than 1,100 Btu. Any changes to gas quality specification requirements on Northern Border must be approved by the FERC and we do not know at this time what, if any, impact the final gas quality specifications requirements will have on the Partnership. However, changes to the gas quality specification on Northern Border, a pipeline downstream of our natural gas processing plants, may impact gas
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processing requirements at our natural gas processing plants, and costs associated with additional processing may impact the Partnership’s economics.
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Item 6. — Exhibits
Exhibit
No. 		  Description of Exhibit
Sarbanes-Oxley Section 302 certification of Principal Executive Officer.
Sarbanes-Oxley Section 302 certification of Principal Financial Officer.
Sarbanes-Oxley Section 906 certification of Principal Executive Officer.
Sarbanes-Oxley Section 906 certification of Principal Financial Officer.
101.INS(a) XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH(a)   XBRL Schema Document.
101.CAL(a)   XBRL Calculation Linkbase Document.
101.DEF(a)   XBRL Definition Linkbase Document.
101.LAB(a)   XBRL Labels Linkbase Document.
101.PRE(a)   XBRL Presentation Linkbase Document.
104(a) Cover Page Interactive Data File - the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
___________________
(a)  Filed herewith.
(b)  Furnished herewith.


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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.
      OASIS MIDSTREAM PARTNERS LP
By: OMP GP LLC, its general partner
Date: August 5, 2020   By:   /s/ Taylor L. Reid
      Taylor L. Reid
      Chief Executive Officer and Director
(Principal Executive Officer)

  By:   /s/ Richard N. Robuck
      Richard N. Robuck
      Senior Vice President and Chief Financial Officer
(Principal Accounting Officer and Principal Financial Officer)

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