Evolve Transition Infrastructure (SNMP) 10-Q10 Nov 212021 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2021	Nov. 09, 2021
Document And Entity Information
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
Document Transition Report	false
Entity File Number	001-33147
Entity Registrant Name	Evolve Transition Infrastructure LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	11-3742489
Entity Address, Address Line One	1360 Post Oak Blvd, Suite 2400
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77056
City Area Code	713
Local Phone Number	783-8000
Title of 12(b) Security	Common Units
Trading Symbol	SNMP
Security Exchange Name	NYSEAMER
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		114,165,219
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001362705
Amendment Flag	false
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2021

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Revenues
Gathering and transportation sales				$ 785
Gathering and transportation lease revenues	$ 16,868	$ 10,670	$ 35,304	34,615
Total revenues	16,868	10,670	35,304	35,400
Operating expenses
Transportation operating expenses	2,065	2,455	6,421	7,641
General and administrative expenses	4,460	2,693	13,964	10,980
Unit-based compensation expense	206	779	749	1,902
Depreciation and amortization	5,143	5,193	15,430	15,512
Accretion expense	98	89	287	263
Total operating expenses	11,972	11,209	36,851	36,298
Other (income) expense
Interest expense, net	31,141	24,015	89,525	70,188
Loss (earnings) from equity investments	1,734	441	1,406	(2,254)
Other (income) expense	687	(2)	(114)	(10)
Total other expenses	33,562	24,454	90,817	67,924
Total expenses	45,534	35,663	127,668	104,222
Loss before income taxes	(28,666)	(24,993)	(92,364)	(68,822)
Income tax expense (benefit)	(19)	43	(17)	140
Loss from continuing operations	(28,647)	(25,036)	(92,347)	(68,962)
Income (loss) from discontinued operations	187	419	1,289	(19,613)
Net loss	$ (28,460)	$ (24,617)	$ (91,058)	$ (88,575)
Loss from continuing operations per unit Common units - Basic and Diluted	$ (0.34)	$ (1.30)	$ (1.48)	$ (3.60)
Loss from discontinued operations per unit Common units - Basic and Diluted	0	0.02	0.02	(1.02)
Net loss per unit
Common units - Basic and Diluted (in dollars per share)	$ (0.34)	$ (1.28)	$ (1.45)	$ (4.62)
Common Units - Basic and Diluted (in units)	84,338,011	19,264,636	62,599,574	19,164,245

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 1,403	$ 1,718
Accounts receivable	11,388	5,259
Prepaid expenses	694	404
Fair value of warrants	160
Current assets from discontinued operations	516	1,602
Total current assets	14,161	8,983
Oil and natural gas properties and related equipment
Gathering and transportation assets	99,908	105,267
Other assets
Intangible assets, net	121,693	131,786
Equity investments	76,515	89,635
Other non-current assets	75	25
Long-term assets from discontinued operations		18,082
Total assets	312,352	353,778
Current liabilities
Accounts payable and accrued liabilities	3,127	4,079
Accounts payable and accrued liabilities - related entities	12,869	25,737
Royalties payable	359	359
Short-term debt, net of debt issuance costs	8,888	110,233
Class C Preferred Units	382,876	345,205
Current liabilities from discontinued operations		341
Total current liabilities	408,119	485,954
Other liabilities
Long term accrued liabilities - related entities	16,930	12,137
Asset retirement obligation	4,600	4,313
Long-term debt, net of discount and debt issuance costs	45,131
Other liabilities	11,990	1,766
Long-term liabilities from discontinued operations		3,152
Total other liabilities	78,651	21,368
Total liabilities	486,770	507,322
Commitments and contingencies (See Note 12)
Partners' deficit
Common units, 96,465,219 and 19,953,880 units issued and outstanding as of September 30, 2021 and December 31, 2020, respectively	(174,418)	(153,544)
Total partners' deficit	(174,418)	(153,544)
Total liabilities and partners' capital	$ 312,352	$ 353,778

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Parenthetical) - shares	Sep. 30, 2021	Dec. 31, 2020
Condensed Consolidated Balance Sheets
Units, issued	96,465,219	19,953,880
Units, outstanding	96,465,219	19,953,880

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Cash flows from operating activities:
Net loss	$ (91,058)	$ (88,575)
Adjustments to reconcile net loss to cash provided by operating activities:
Depreciation, depletion and amortization	5,777	7,275
Amortization of debt issuance costs	828	553
Accretion of Class C discount	37,671	28,110
Class C distribution accrual		37,448
Asset impairments		23,247
Accretion expense	360	422
Distributions from equity investments	11,946	7,624
Equity earnings in affiliate	1,406	(2,254)
Bad debt expense	(1,926)
Gain on sale of assets	(537)
Mark-to-market on Stonepeak Warrant	10,234	(22)
Net gain on commodity derivative contracts		(4,008)
Net cash settlements received on commodity derivative contracts	101	2,394
Gain on Nuvve Holding Warrants	(160)
Unit-based compensation	2,291	823
Amortization of intangible assets	10,093	10,093
Changes in Operating Assets and Liabilities:
Accounts receivable	(5,161)	(6,994)
Accounts receivable - related entities		6,719
Prepaid expenses	(99)	393
Other assets	118	(96)
Accounts payable and accrued liabilities	50,663	(300)
Accounts payable and accrued liabilities- related entities	(8,075)	1,591
Other long-term liabilities	338
Net cash provided by operating activities	24,810	24,443
Cash flows from investing activities:
Proceeds from sales of oil and natural gas properties	15,721
Development of oil and natural gas properties		5
Construction of gathering and transportation assets	(41)	(182)
Contributions to equity affiliates	(232)
Net cash provided by (used in) investing activities	15,448	(177)
Cash flows from financing activities:
Repayment of debt	(61,800)	(34,000)
Proceeds from issuance of debt	5,500	7,000
Issuance of common units	17,051
Payments for offering costs	(582)
Units tendered by employees for tax withholdings		(41)
Debt issuance costs	(742)	(132)
Net cash used in financing activities	(40,573)	(27,173)
Net decrease in cash and cash equivalents	(315)	(2,907)
Cash and cash equivalents, beginning of period	1,718	5,099
Cash and cash equivalents, end of period	1,403	2,192
Supplemental disclosures of cash flow information:
Cash paid during the period for income tax	139	243
Cash paid during the period for interest	$ 2,184	$ 4,259

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Changes in Partners' Capital - USD ($) $ in Thousands	Common Units	Total
Partner's Deficit at Dec. 31, 2019	$ (35,800)	$ (35,800)
Partner's Deficit (in shares) at Dec. 31, 2019	20,087,462
Unit-based compensation programs	$ 243	243
Unit-based compensation programs (in shares)	(23,387)
Units tendered by SOG employees for tax withholding	$ (31)	(31)
Units tendered by SOG employees for tax withholding (in shares)	(88,819)
Net loss	$ (41,341)	(41,341)
Partner's Deficit at Mar. 31, 2020	$ (76,929)	(76,929)
Partner's Deficit (in shares) at Mar. 31, 2020	19,975,256
Partner's Deficit at Dec. 31, 2019	$ (35,800)	(35,800)
Partner's Deficit (in shares) at Dec. 31, 2019	20,087,462
Net loss		(88,575)
Partner's Deficit at Sep. 30, 2020	$ (123,594)	(123,594)
Partner's Deficit (in shares) at Sep. 30, 2020	19,953,880
Partner's Deficit at Mar. 31, 2020	$ (76,929)	(76,929)
Partner's Deficit (in shares) at Mar. 31, 2020	19,975,256
Unit-based compensation programs	$ 266	266
Unit-based compensation programs (in shares)	(126)
Units tendered by SOG employees for tax withholding	$ (11)	(11)
Units tendered by SOG employees for tax withholding (in shares)	(19,867)
Net loss	$ (22,617)	(22,617)
Partner's Deficit at Jun. 30, 2020	$ (99,291)	(99,291)
Partner's Deficit (in shares) at Jun. 30, 2020	19,955,263
Unit-based compensation programs	$ 314	314
Unit-based compensation programs (in shares)	(1,383)
Net loss	$ (24,617)	(24,617)
Partner's Deficit at Sep. 30, 2020	$ (123,594)	(123,594)
Partner's Deficit (in shares) at Sep. 30, 2020	19,953,880
Partner's Deficit at Dec. 31, 2020	$ (153,544)	(153,544)
Partner's Deficit (in shares) at Dec. 31, 2020	19,953,880
Unit-based compensation programs	$ 1,879	1,879
Unit-based compensation programs (in shares)	1,511,138
Common units issued as Class C Preferred distributions	$ 25,685	25,685
Common units issued as Class C Preferred distributions (in shares)	34,720,360
Net loss	$ (34,805)	(34,805)
Partner's Deficit at Mar. 31, 2021	$ (160,785)	(160,785)
Partner's Deficit (in shares) at Mar. 31, 2021	56,185,378
Partner's Deficit at Dec. 31, 2020	$ (153,544)	(153,544)
Partner's Deficit (in shares) at Dec. 31, 2020	19,953,880
Net loss		(91,058)
Partner's Deficit at Sep. 30, 2021	$ (174,418)	(174,418)
Partner's Deficit (in shares) at Sep. 30, 2021	96,465,219
Partner's Deficit at Mar. 31, 2021	$ (160,785)	(160,785)
Partner's Deficit (in shares) at Mar. 31, 2021	56,185,378
Unit-based compensation programs	$ 206	206
Issuance of common units, net of offering costs of $0.3 million	$ 6,720	6,720
Issuance of common units, net of offering costs of $0.3 million (in shares)	8,774,888
Common units issued as Class C Preferred distributions	$ 12,869	12,869
Common units issued as Class C Preferred distributions (in shares)	13,763,249
Net loss	$ (27,796)	(27,796)
Partner's Deficit at Jun. 30, 2021	$ (168,786)	(168,786)
Partner's Deficit (in shares) at Jun. 30, 2021	78,723,515
Unit-based compensation programs	$ 206	206
Issuance of common units, net of offering costs of $0.3 million	$ 9,753	9,753
Issuance of common units, net of offering costs of $0.3 million (in shares)	9,728,854
Common units issued as Class C Preferred distributions	$ 12,869	12,869
Common units issued as Class C Preferred distributions (in shares)	8,012,850
Net loss	$ (28,460)	(28,460)
Partner's Deficit at Sep. 30, 2021	$ (174,418)	$ (174,418)
Partner's Deficit (in shares) at Sep. 30, 2021	96,465,219

Organization And Business

Organization And Business	9 Months Ended
Organization And Business	Sep. 30, 2021
Organization And Business
Organization And Business	1. ORGANIZATION AND BUSINESS Organization We are a publicly-traded limited partnership formed in 2005 focused on the acquisition, development, and ownership of infrastructure critical to the transition of energy supply to lower carbon sources. We own natural gas gathering systems, pipelines, and processing facilities in South Texas and continue to pursue energy transition infrastructure opportunities. Our common units are currently listed on the NYSE American under the symbol “SNMP.” On February 26, 2021, in connection with our management team’s focus on expanding our business strategy to focus on the ongoing energy transition in the industries in which we operate, we changed our name to Evolve Transition Infrastructure LP and our general partner changed its name to Evolve Transition Infrastructure GP LLC.

Basis Of Presentation And Summa

Basis Of Presentation And Summary Of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2021
Basis Of Presentation And Summary Of Significant Accounting Policies
Basis of Presentation and Significant Accounting Policies	2. BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation Accounting policies used by us conform to accounting principles generally accepted in the United States of America (“GAAP”). The accompanying financial statements include the accounts of us and our wholly owned subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures, normally included in annual financial statements prepared in accordance with GAAP, have been condensed or omitted pursuant to those rules and regulations. We believe that the disclosures made are adequate to make the information presented not misleading. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, necessary to fairly state the financial position, results of operations and cash flows with respect to the interim condensed consolidated financial statements have been included. The results of operations for the interim periods are not necessarily indicative of the results for the entire year. These unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements and the notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2020, which was filed with the SEC on March 16, 2021. Recent Accounting Pronouncements From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board (“FASB”), which are adopted by us as of the specified effective date. Unless otherwise discussed, management believes that the impact of recently issued standards, which are not effective, will not have a material impact on our consolidated financial statements upon adoption. In January 2020, the FASB issued Accounting Standards Update (“ASU”) 2020-01 “Investments – Equity Securities (Topic 321), Investments – Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815),” which clarifies the interaction among the accounting standards for equity securities, equity method investments and certain derivatives. This ASU is effective for public business entities for annual and interim periods in fiscal years beginning after December 15, 2020. The adoption of this standard did not have a material impact on our condensed consolidated financial statements. In June 2016, the FASB issued ASU 2016-13, “Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” This ASU modifies the impairment model to utilize an expected loss methodology in place of the currently used incurred loss methodology, which will result in more timely recognition of losses. Additionally, in November 2019, the FASB issued ASU 2019-10, “Financial Instruments – Credit Losses (Topic 326), Derivatives and Hedging (Topic 815), and Leases (Topic 842): Effective Dates,” which changed the effective date for certain issuers to annual and interim periods in fiscal years beginning after December 15, 2022, and earlier adoption is permitted. We are currently in the process of evaluating the impact of adoption of this guidance on our condensed consolidated financial statements. Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Partnership’s financial position, results of operations and cash flows. Use of Estimates The condensed consolidated financial statements are prepared in conformity with GAAP, which requires management to make estimates and assumptions that affect the amounts reported in the condensed consolidated financial statements and accompanying notes. These estimates and the underlying assumptions affect the amounts of assets and liabilities reported, disclosures about contingent assets and liabilities and reported amounts of revenues and expenses. The estimates that are particularly significant to our financial statements include estimates of our reserves of natural gas, NGLs and oil; future cash flows from oil and natural gas properties; depreciation, depletion and amortization; asset retirement obligations; certain revenues and operating expenses; fair values of derivatives; and fair values of assets and liabilities. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best judgment using the data available. Management evaluates its estimates and assumptions on an on-going basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from the estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.

Discontinued Operations

Discontinued Operations	9 Months Ended
Discontinued Operations	Sep. 30, 2021
Discontinued Operations
Discontinued Operations	3. DISCONTINUED OPERATIONS Palmetto Divestiture On April 30, 2021, but effective March 1, 2021 (the “Palmetto Effective Time”), SEP Holdings IV, LLC (“SEP IV”), a wholly-owned subsidiary of the Partnership entered into a purchase agreement (the “Palmetto PSA”) with Westhoff Palmetto LP (“Palmetto Buyer”), pursuant to which SEP IV sold to Palmetto Buyer specified wellbores and other associated assets located in Gonzales and Dewitt Counties, Texas (the “Palmetto Assets”) for a base purchase price of approximately $11.5 million, including the impact of final post-closing adjustments (the “Palmetto Divestiture”). Pursuant to the Palmetto PSA, other than a limited amount of retained obligations, Palmetto Buyer has agreed to assume all obligations relating to the Palmetto Assets that arose on or after the Palmetto Effective Time. The Palmetto PSA contains customary representations and warranties by SEP IV and Palmetto Buyer, and SEP IV and Palmetto Buyer have agreed to customary indemnities relating to breaches of representations, warranties and covenants and the payment of assumed and excluded obligations. The Palmetto Divestiture closed simultaneously with the execution of the Palmetto PSA and we recorded a gain of approximately $0.3 million on the sale. Maverick Divestitures On April 30, 2021, but effective March 1, 2021 (the “Maverick Effective Time”), SEP IV entered into a purchase agreement (the “Maverick PSA”) with Bayshore Energy TX LLC (“Maverick Buyer”), pursuant to which SEP IV sold to Maverick Buyer specified wellbores and other associated assets located in Zavala County, Texas (the “Maverick 1 Assets”) for a base purchase price of approximately $2.8 million, which remains subject to final post-closing adjustments expected in the fourth quarter of 2021 (the “Maverick 1 Divestiture”). Pursuant to the Maverick PSA, other than a limited amount of retained obligations, Maverick Buyer has agreed to assume all obligations relating to the Maverick 1 Assets that arose on or after the Maverick Effective Time. The Maverick PSA contains customary representations and warranties by SEP IV and Maverick Buyer, and SEP IV and Maverick Buyer agreed to customary indemnities relating to breaches of representations, warranties and covenants and the payment of assumed and excluded obligations. The Maverick 1 Divestiture closed simultaneously with the execution of the Maverick PSA. Also on April 30, 2021, SEP IV entered into a letter agreement with Maverick Buyer (the “Maverick Letter Agreement”) pursuant to which SEP IV agreed to sell additional other specified wellbores and other associated assets located in Zavala and Dimmit Counties, Texas (the “Maverick 2 Assets”) for a base purchase price of approximately $1.4 million, which remains subject to final post-closing adjustments expected in the fourth quarter of 2021 (the “Maverick 2 Divestiture”). The closing of the Maverick 2 Divestiture was conditioned upon SEP IV obtaining certain consents and complying with other preferential rights related to the Maverick 2 Assets. Following the entrance into the Maverick Letter Agreement, SEP IV complied with the preferential rights and obtained multiple consents related to the Maverick 2 Assets. SEP IV did not obtain one of the required consents and, as a result, the Maverick 2 Assets subject to such consent were removed from the Maverick 2 Assets included in the Maverick 2 Divestiture (the “Updated Maverick 2 Assets”) and the base purchase price was adjusted downward by approximately $31,000. On May 14, 2021, but effective as of the Maverick Effective Time, SEP IV and Maverick Buyer entered into a purchase agreement (the “Maverick 2 PSA”) pursuant to which SEP IV sold to Maverick Buyer the Updated Maverick 2 Assets. Pursuant to the Maverick 2 PSA, other than a limited amount of retained obligations, Maverick Buyer agreed to assume all obligations and liabilities related to the Updated Maverick 2 Assets that arose on or after the Maverick Effective Time. The Maverick 2 PSA contains customary representations and warranties by SEP IV and Maverick Buyer, and SEP IV and Maverick Buyer agreed to customary indemnities relating to breaches of representations, warranties and covenants and the payment of assumed and excluded obligations. The Maverick 2 Divestiture closed simultaneously with the execution of the Maverick 2 PSA. On August 13, 2021, but effect as of the Maverick Effective Time, SEP IV and Maverick Buyer entered into a Purchase Agreement (the “Maverick 3 PSA”) pursuant to which SEP IV sold to Maverick Buyer specified wellbores and other associated assets located in Zavala County, Texas, including the remaining Maverick 2 Assets excluded from the original closing of the Maverick 2 Divestiture (the “Maverick 3 Assets”) for a base purchase price of approximately $31,000, which remains subject to final post-closing adjustments expected in the fourth quarter of 2021 (the “Maverick 3 Divestiture” and together with the Maverick 1 Divestiture and the Maverick 2 Divestiture, the “Maverick Divestitures”). Pursuant to the Maverick 3 PSA, other than a limited amount of retained obligations, Maverick Buyer agreed to assume all obligations and liabilities related to the Maverick 3 Assets that arose on or after the Maverick Effective Time. The Maverick 3 PSA contains customary representations and warranties by SEP IV and Maverick Buyer, and SEP IV and Maverick Buyer agreed to customary indemnities relating to breaches of representations, warranties and covenants and the payment of assumed and excluded obligations. The Maverick 3 Divestiture closed simultaneously with the execution of the Maverick 3 PSA. We recorded a net gain of approximately $0.2 million related to the Maverick Divestitures. Information related to the upstream oil and natural gas assets sold have been reflected in the condensed consolidated financial statements as discontinued operations. The following table presents the results of operations and the gain on disposal which has been included in discontinued operations (in thousands): Three Months Ended Nine Months Ended September 30, September 30, 2021 2020 2021 2020 Revenues Natural gas sales $ — $ 16 $ 255 $ 334 Oil sales 5 1,755 3,241 9,129 Natural gas liquid sales — 69 182 170 Total revenues 5 1,840 3,678 9,633 Expenses Operating expenses Lease operating expenses 20 891 1,797 3,859 Production taxes — 112 160 262 Gain on sale of assets (203) — (537) — Depreciation, depletion and amortization — 360 439 1,856 Asset impairments — — — 23,247 Accretion expense — 55 73 159 Total operating expenses (183) 1,418 1,932 29,383 Income (loss) before income taxes 188 422 1,746 (19,750) Income tax expense (benefit) 1 3 457 (137) Income (loss) from discontinued operations $ 187 $ 419 $ 1,289 $ (19,613)

Revenue Recognition

Revenue Recognition	9 Months Ended
Revenue Recognition	Sep. 30, 2021
Revenue Recognition
Revenue Recognition	4. REVENUE RECOGNITION Revenue from Contracts with Customers We account for revenue from contracts with customers in accordance with ASC 606, “Revenue from Contracts with Customers.” The unit of account in ASC 606 is a performance obligation, which is a promise in a contract to transfer to a customer either a distinct good or service (or bundle of goods or services) or a series of distinct goods or services provided over a period of time. ASC 606 requires that a contract’s transaction price, which is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer, is to be allocated to each performance obligation in the contract based on relative standalone selling prices and recognized as revenue when (point in time) or as (over time) the performance obligation is satisfied. Disaggregation of Revenue We recognized revenue of approximately $16.9 million and $35.3 million for the three and nine months ended September 30, 2021, respectively. We disaggregate revenue based on revenue and product type. In selecting the disaggregation categories, we considered a number of factors, including disclosures presented outside the financial statements, such as in our earnings release and investor presentations, information reviewed internally for evaluating performance, and other factors used by the Partnership or the users of its financial statements to evaluate performance or allocate resources. We have concluded that disaggregating revenue by revenue and product type appropriately depicts how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. The Firm Transportation Service Agreement, dated September 1, 2017, by and between Seco Pipeline, LLC and SN Catarina, LLC (the “Seco Pipeline Transportation Agreement”) is the only contract that we historically accounted for under ASC 606. The Seco Pipeline Transportation Agreement was terminated by Mesquite effective February 12, 2020. The Gathering Agreement is classified as an operating lease and is accounted for under ASC 842, “Leases” and is reported as gathering and transportation lease revenues in our condensed consolidated statements of operations. We account for income from our unconsolidated equity method investments as earnings from equity investments in our condensed consolidated statements of operations. Earnings from these equity method investments are further discussed in Note 11 “Investments.” Performance Obligations Pursuant to the Seco Pipeline Transportation Agreement, we agreed to provide transportation services of certain quantities of natural gas from the receipt point to the delivery point. Each MMBtu of natural gas transported is distinct and the transportation services performed on each distinct molecule of product is substantially the same in nature. We applied the series guidance and treated these services as a single performance obligation satisfied over time using volumes delivered as the measure of progress. The Seco Pipeline Transportation Agreement required payment within 30 days following the calendar month of delivery. The Seco Pipeline Transportation Agreement contained variable consideration in the form of volume variability. As the distinct goods or services (rather than the series) are considered for the purpose of allocating variable consideration, we have taken the optional exception under ASC 606 which is available only for wholly unsatisfied performance obligations for which the criteria in ASC 606 have been met. Under this exception, neither estimation of variable consideration nor disclosure of the transaction price allocated to the remaining performance obligations is required. Revenue is alternatively recognized in the period that control is transferred to the customer and the respective variable component of the total transaction price is resolved. For forms of variable consideration that are not associated with a specific volume (such as late payment fees) and thus do not meet allocation exception, estimation is required. These fees, however, are immaterial to our condensed consolidated financial statements and have a low probability of occurrence. As significant reversals of revenue due to this variability are not probable, no estimation is required. Contract Balances Under our sales contracts, we invoice customers after our performance obligations have been satisfied, at which point payment is unconditional. Accordingly, our contracts do not give rise to contract assets or liabilities under ASC 606. At September 30, 2021 and December 31, 2020, our accounts receivables from contracts with customers were zero and approximately $1.9 million, respectively.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
Fair Value Measurements	Sep. 30, 2021
Fair Value Measurements
Fair Value Measurements	5. FAIR VALUE MEASUREMENTS Measurements of fair value of derivative instruments are classified according to the fair value hierarchy, which prioritizes the inputs to the valuation techniques used to measure fair value. Fair value is the price that would be received upon the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories: Level 1: Level 2: Level 3: Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Management's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The following table summarizes the fair value of our assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2021 (in thousands): Fair Value Measurements at September 30, 2021 Active Markets for Observable Identical Assets Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value Fair value of warrants Nuvve Holding Warrants $ — $ 160 $ — $ 160 Other liabilities Stonepeak Warrant — (11,654) — (11,654) Total $ — $ (11,494) $ — $ (11,494) The following table summarizes the fair value of our assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2020 (in thousands): Fair Value Measurements at December 31, 2020 Active Markets for Observable Identical Assets Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value Other liabilities Stonepeak Warrant — (1,418) — (1,418) Total $ — $ (1,418) $ — $ (1,418) As of September 30, 2021 and December 31, 2020, the estimated fair value of cash and cash equivalents, accounts receivable, other current assets and current liabilities approximated their carrying value due to their short-term nature. Fair Value on a Non-Recurring Basis The Partnership follows the provisions of Topic 820-10, “Fair Value Measurement,” for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs under the fair value hierarchy. We periodically review oil and natural gas properties and related equipment for impairment when facts and circumstances indicate that their carrying values may not be recoverable. A reconciliation of the beginning and ending balances of the Partnership’s asset retirement obligations is presented in Note 9 “Asset Retirement Obligation.” The following table summarizes the non-recurring fair value measurements of our production assets as of December 31, 2020 (in thousands): Fair Value Measurements at December 31, 2020 Active Markets for Observable Identical Assets Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Impairment (a) $ — $ — $ 12,884 Total net assets $ — $ — $ 12,884 (a) During the year ended December 31, 2020, we recorded a non-cash impairment charge of $23.4 million to impair our producing oil and natural gas properties and $0.9 million to impair the Seco Pipeline. The carrying values of the impaired properties were reduced to a fair value of approximately $12.9 million, estimated using inputs characteristic of a Level 3 fair value measurement. The fair values of oil and natural gas properties and related equipment were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties and related equipment include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; (iv) estimated future cash flows; (v) estimated throughput; and (vi) a market-based weighted average cost of capital rate of 15%. These inputs require significant judgments and estimates by the Partnership’s management at the time of the valuation and are the most sensitive and subject to change. Seco Pipeline The fair value of the Seco Pipeline was measured using probabilistic valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of the Seco Pipeline include estimates of: (i) future operating and development costs; (ii) estimated future cash flows; and (iii) a market-based weighted average cost of capital rate. These inputs require significant judgments and estimates by the Partnership’s management at the time of the valuation and are the most sensitive and subject to change. Fair Value of Financial Instruments The estimated fair value amounts of financial instruments have been determined using available market information and valuation methodologies described below. We prioritize the use of the highest level inputs available in determining fair value such that fair value measurements are determined using the highest and best use as determined by market participants and the assumptions that they would use in determining fair value. Credit Agreement Nuvve Holding Warrants Stonepeak Warrant – Earnout Derivative –

Derivative And Financial Instru

Derivative And Financial Instruments	9 Months Ended
Derivative And Financial Instruments	Sep. 30, 2021
Derivative And Financial Instruments
Derivative And Financial Instruments	6. DERIVATIVE AND FINANCIAL INSTRUMENTS On May 17, 2021, the Partnership entered into a letter agreement (the “Levo Letter Agreement”) with Nuvve Holding Corp. (“Nuvve Holding”) and Stonepeak Rocket Holdings LP (“Stonepeak Rocket”), relating to the proposed formation of a joint venture, Levo Mobility LLC (“Levo” and such proposed joint venture, the “Levo JV”). In connection with the Levo Letter Agreement, on May 17, 2021, Nuvve Holding issued ten-year warrants to the Partnership as follows: (i) Series B Warrants to purchase 200,000 shares of Nuvve Holding’s common stock, at an exercise price of $10.00 per share, which are fully vested upon issuance, (ii) Series C warrants to purchase 100,000 shares of Nuvve Holding’s common stock, at an exercise price of $15.00 per share, which are vested as to 50% of the shares upon issuance and vest as to the remaining 50% when Levo has entered into contracts with third parties for $125 million in aggregate capital expenditures; (iii) Series D warrants to purchase 100,000 shares of Nuvve Holding’s common stock, at an exercise price of $20.00 per share, which are vested as to 50% of the shares upon issuance and vest as to the remaining 50% when Levo has entered into contracts with third parties for $250 million in aggregate capital expenditures; (iv) Series E warrants to purchase 100,000 shares of Nuvve Holding’s common stock, at an exercise price of $30.00 per share, which are vested as to 50% of the shares upon issuance and vest as to the remaining 50% when Levo has entered into contracts with third parties for $375 million in aggregate capital expenditures; and (v) Series F warrants to purchase 100,000 shares of Nuvve Holding’s common stock, at an exercise price of $40.00 per share, which are vested as to 50% of the shares upon issuance and vest as to the remaining 50% when Levo has entered into contracts with third parties for $500 million in aggregate capital expenditures (collectively the “Nuvve Holding Warrants”).The Nuvve Holding Warrants are accounted for in accordance with Topic 815, “Derivatives and Hedging,” and are recorded on the condensed consolidated balance sheets at fair value. Changes in the Nuvve Holding Warrants fair value are recognized in earnings and included in other income on the condensed consolidated statements of operations. The following table sets forth a reconciliation of the changes in fair value of the Partnership’s Nuvve Holding Warrants for the periods indicated (in thousands): Nine Months Ended September 30, 2021 Beginning fair value of warrants $ — Net gain (loss) on warrants 160 Ending fair value of warrants $ 160 To reduce the impact of fluctuations in oil and natural gas prices on our revenues, we historically entered into derivative contracts with respect to a portion of our projected oil and natural gas production through various transactions that fix or modify the future prices to be realized. We did not hedge any of our expected production volumes for 2021. Our historical hedging activities were intended to support oil and natural gas prices at targeted levels and to manage exposure to oil and natural gas price fluctuations. It was never our intention to enter into derivative contracts for speculative trading purposes. Under Topic 815, “Derivatives and Hedging,” all derivative instruments are recorded on the condensed consolidated balance sheets at fair value as either short-term or long-term assets or liabilities based on their anticipated settlement date. We will net derivative assets and liabilities for counterparties where we have a legal right of offset. Changes in the derivatives’ fair values are recognized currently in earnings unless specific hedge accounting criteria are met. We have not elected to designate any of our current derivative contracts as hedges; however, changes in the fair value of all of our derivative instruments are recognized in earnings and included in natural gas sales and oil sales in the condensed consolidated statements of operations. We do not have derivative contracts related to production in 2021 and beyond. The following table sets forth a reconciliation of the changes in fair value of the Partnership’s commodity derivatives for the year ended December 31, 2020 (in thousands): Year Ended December 31, 2020 Beginning fair value of commodity derivatives $ (759) Net gains (losses) on crude oil derivatives 3,814 Net gains on natural gas derivatives 87 Net settlements received on derivative contracts: Oil (2,829) Natural gas (313) Ending fair value of commodity derivatives $ — The effect of derivative instruments on our condensed consolidated statements of operations for each of the three and nine months ended September 30, 2020 was as follows (in thousands). As disclosed above, we did not hedge any of our expected production volumes for 2021. Location of Gain (Loss) Three Months Ended September 30, Nine Months Ended September 30, Derivative Type in Income September 30, 2020 September 30, 2020 Commodity – Mark-to-Market Income (loss) from discontinued operations $ (115) $ 3,912 Commodity – Mark-to-Market Income (loss) from discontinued operations (55) 96 $ (170) $ 4,008 Earnout Derivative Refer to Note 5 “Fair Value Measurements.”

Debt

Debt	9 Months Ended
Debt	Sep. 30, 2021
Debt
Debt	7. DEBT Credit Agreement We have entered into a credit facility with Royal Bank of Canada, as administrative agent and collateral agent, and the lenders party thereto, as amended through the date of the Twelfth Amendment to Third Amended and Restated Credit Agreement, dated as of August 20, 2021 (the “Credit Agreement”). The Credit Agreement provides a quarterly amortizing term loan of $65.0 million (the “Term Loan”) and a maximum revolving credit amount of $5.0 million (the “Revolving Loan”). The Credit Agreement matures on September 30, 2023. Borrowings under the Credit Agreement are secured by various mortgages of midstream properties that we own as well as various security and pledge agreements among us, certain of our subsidiaries and the administrative agent. Borrowings under the Credit Agreement are available for limited direct investment in midstream properties, acquisitions, and working capital and general business purposes. The Credit Agreement has a sub-limit of up to $2.5 million which may be used for the issuance of letters of credit. As of September 30, 2021, we had approximately $54.7 million of debt outstanding, consisting of approximately $52.2 million under the Term Loan and approximately $2.5 million under the Revolving Loan. We are required to make mandatory amortizing payments of outstanding principal on the Term Loan of (i) $3.0 million per fiscal quarter commencing with the quarter ending December 31, 2021, and (ii) $2.0 million per fiscal quarter commencing with the quarter ending March 31, 2023. The maximum revolving credit amount is $5.0 million leaving us with approximately $2.5 million in unused borrowing capacity. There were no letters of credit outstanding under our Credit Agreement as of September 30, 2021. At our election, interest for borrowings under the Credit Agreement are determined by reference to (i) the LIBOR plus an applicable margin between 2.75% and 3.50% per annum based on net debt to EBITDA or (ii) a domestic bank rate (“ABR”) plus an applicable margin between 1.75% and 2.50% per annum based on net debt to EBITDA plus (iii) a commitment fee of 0.500% per annum based on the unutilized portion of the Revolving Loan. Interest on the borrowings for ABR loans and the commitment fee are generally payable quarterly. Interest on the borrowings for LIBOR loans are generally payable at the applicable maturity date. The Credit Agreement contains various covenants that limit, among other things, our ability to incur certain indebtedness, grant certain liens, merge or consolidate, sell all or substantially all of our assets, make certain loans, acquisitions, capital expenditures and investments, and pay distributions to unitholders. In addition, we are required to maintain the following financial covenants: ● current assets to current liabilities, excluding any current maturities of debt, of at least 1.0 to 1.0 at all times; and ● senior secured net debt to consolidated adjusted EBITDA for the last twelve months, as of the last day of any fiscal quarter, of not greater than 3.25 to 1.00. The Credit Agreement also includes customary events of default, including events of default relating to non-payment of principal, interest or fees, inaccuracy of representations and warranties when made or when deemed made, violation of covenants, cross-defaults, bankruptcy and insolvency events, certain unsatisfied judgments, loan documents not being valid and a change in control. A change in control is generally defined as the occurrence of one of the following events: (i) our existing general partner ceases to be our sole general partner or (ii) certain specified persons shall cease to own more than 50% of the equity interests of our general partner or shall cease to control our general partner. If an event of default occurs, the lenders will be able to accelerate the maturity of the Credit Agreement and exercise other rights and remedies. At September 30, 2021, we were in compliance with the financial covenants contained in the Credit Agreement. We monitor compliance on an ongoing basis. If we are unable to remain in compliance with the financial covenants contained in our Credit Agreement or maintain the required ratios discussed above, the lenders could call an event of default and accelerate the outstanding debt under the terms of the Credit Agreement, such that our outstanding debt could become then due and payable. We may request waivers of compliance from the violated financial covenants from the lenders, but there is no assurance that such waivers would be granted. We are required to make mandatory amortizing payments of the outstanding principal on the Term Loan, we expect these quarterly amortizing payments will be made from our operating cash flows and other capital resources. However, there can be no assurance that operations and other capital resources will provide cash in sufficient amounts to make these mandatory amortizing payments. Debt Issuance Costs As of September 30, 2021 and December 31, 2020, our unamortized debt issuance costs were approximately $0.7 million and $0.8 million, respectively. These costs are amortized to interest expense in our condensed consolidated statements of operations over the life of our Credit Agreement. Amortization of debt issuance costs recorded during the three months ended September 30, 2021 and 2020 was approximately $0.3 million and $0.2 million, respectively. Amortization of debt issuance costs recorded during the nine months ended September 30, 2021 and 2020 was approximately $0.8 million and $0.6 million, respectively.

Oil And Natural Gas Properties

Oil And Natural Gas Properties And Related Equipment	9 Months Ended
Oil And Natural Gas Properties And Related Equipment	Sep. 30, 2021
Oil And Natural Gas Properties And Related Equipment.
Oil And Natural Gas Properties And Related Equipment	8. GATHERING AND TRANSPORTATION ASSETS Gathering and transportation assets consisted of the following (in thousands): September 30, December 31, 2021 2020 Gathering and transportation assets Midstream assets $ 187,899 $ 187,977 Less: Accumulated depreciation and impairment (87,991) (82,710) Total gathering and transportation assets, net $ 99,908 $ 105,267 Depreciation and Amortization . Gathering and transportation assets, are stated at historical acquisition cost, net of any impairments, and are depreciated using the straight-line method over the useful lives of the assets, which range from three to 15 years for furniture and equipment, up to 36 years for gathering facilities, and up to 40 years for transportation assets. Depreciation and amortization consisted of the following (in thousands): Three Months Ended Nine Months Ended September 30, September 30, 2021 2020 2021 2020 Depreciation and amortization of gathering and transportation related assets $ 1,778 $ 1,830 $ 5,337 $ 5,419 Amortization of intangible assets 3,365 3,363 10,093 10,093 Total depreciation and amortization $ 5,143 $ 5,193 $ 15,430 $ 15,512 Impairment of Gathering and Transportation Assets.

Asset Retirement Obligation

Asset Retirement Obligation	9 Months Ended
Asset Retirement Obligation	Sep. 30, 2021
Asset Retirement Obligation
Asset Retirement Obligation	9. ASSET RETIREMENT OBLIGATION We recognize the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred if a reasonable estimate of fair value can be made. Each period, we accrete the ARO to its then present value. The associated asset retirement cost (“ARC”) is capitalized as part of the carrying amount of our oil and natural gas properties, equipment and facilities or gathering and transportation assets. Subsequently, the ARC is depreciated using the units-of-production method for production assets and the straight-line method for midstream assets. The AROs recorded by us relate to the plugging and abandonment of oil and natural gas wells and decommissioning of oil and natural gas gathering and other facilities. Inherent in the fair value calculation of AROs are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions result in adjustments to the recorded fair value of the existing ARO, a corresponding adjustment is made to the ARC capitalized as part of the oil and natural gas properties, equipment and facilities or gathering and transportation assets. The following table is a reconciliation of changes in ARO for the nine months ended September 30, 2021 and the year ended December 31, 2020 (in thousands): Nine Months Ended Year Ended September 30, 2021 December 31, 2020 Asset retirement obligation, beginning balance $ 4,313 $ 3,958 Accretion expense 287 355 Asset retirement obligation, ending balance $ 4,600 $ 4,313 Additional AROs increase the liability associated with new oil and natural gas wells and other facilities as these obligations are incurred. Abandonments of oil and natural gas wells and other facilities reduce the liability for AROs. During the nine months ended September 30, 2021 and the year ended December 31, 2020, there were no significant expenditures for abandonments and there were no assets legally restricted for purposes of settling existing AROs. During the nine months ended September 30, 2021, obligations were relieved as part of the Palmetto Divestiture and the Maverick Divestitures.

Intangible Assets

Intangible Assets	9 Months Ended
Intangible Assets	Sep. 30, 2021
Intangible Assets
Intangible Assets	10. INTANGIBLE ASSETS Intangible assets are comprised of customer and marketing contracts. The intangible assets balance as of September 30, 2021 is related to the Gathering Agreement with Mesquite that was entered into as part of the acquisition of the Western Catarina gathering system. The Western Catarina gathering system (“Western Catarina Midstream”) is located on the western portion of Mesquite’s acreage position in Dimmit, La Salle and Webb counties, Texas (the western portion of such acreage, “Western Catarina”). Pursuant to the 15 -year agreement, Mesquite tenders all of its crude oil, natural gas and other hydrocarbon-based product volumes produced in the Western Catarina of the Eagle Ford Shale in Texas for processing and transportation through Western Catarina Midstream, with a right to tender additional volumes outside of the dedicated acreage. These intangible assets are being amortized using the straight-line method over the 15 -year life of the agreement. Amortization expense for each of the nine months ended September 30, 2021 and 2020 was approximately $10.1 million. These costs are amortized to depreciation, depletion, and amortization expense in our condensed consolidated statements of operations. The following table is a reconciliation of changes in intangible assets (in thousands): September 30, December 31, 2021 2020 Beginning balance $ 131,786 $ 145,246 Amortization (10,093) (13,460) Ending balance $ 121,693 $ 131,786

Investments

Investments	9 Months Ended
Investments	Sep. 30, 2021
Investments
Investments	11. INVESTMENTS In July 2016, we completed a transaction pursuant to which we acquired from Mesquite a 50% interest in Carnero Gathering, LLC (“Carnero Gathering”), a joint venture that was 50% owned and operated by Targa Resources Corp. (NYSE: TRGP) (“Targa”), for an initial payment of approximately $37.0 million and the assumption of remaining capital commitments to Carnero Gathering, estimated at approximately $7.4 million as of the acquisition date (the “Carnero Gathering Transaction”). The fair value of the intangible asset for the contractual customer relationship related to Carnero Gathering was valued at approximately $13.0 million. This amount is being amortized over a contract term of 15 years and decreases earnings from equity investments in our condensed consolidated statements of operations. As part of the Carnero Gathering Transaction, we are required to pay Mesquite an earnout based on natural gas received above a threshold volume and tariff at designated delivery points from Mesquite and other producers. See Note 5 “Fair Value Measurements” for further discussion of the earnout derivative. In November 2016, we completed a transaction pursuant to which we acquired from Mesquite a 50% interest in Carnero Processing, LLC (“Carnero Processing”), a joint venture that was 50% owned and operated by Targa, for aggregate cash consideration of approximately $55.5 million and the assumption of remaining capital contribution commitments to Carnero Processing, estimated at approximately $24.5 million as of the date of acquisition. In May 2018, we executed a series of agreements with Targa and other parties pursuant to which, among other things: (1) the parties merged their respective 50% interests in Carnero Gathering and Carnero Processing (the “Carnero JV Transaction”) to form an expanded 50 / 50 joint venture in South Texas, within Carnero G&P, LLC (the “Carnero JV”), (2) Targa contributed 100% of the equity interest in the Silver Oak II Gas Processing Plant (“Silver Oak II”), located in Bee County, Texas, to the Carnero JV, which expands the processing capacity of the Carnero JV from 260 MMcf/d to 460 MMcf/d, (3) Targa contributed certain capacity in the 45 miles of high pressure natural gas gathering pipelines owned by Carnero Gathering that connect Western Catarina Midstream to nearby pipelines and the Raptor Gas Processing Facility (the “Carnero Gathering Line”) to the Carnero JV resulting in the Carnero JV owning all of the capacity in the Carnero Gathering Line, which has a design limit (without compression) of 400 MMcf/d, (4) the Carnero JV received a new dedication from Mesquite and its working interest partners of over 315,000 acres located in the Western Eagle Ford on Mesquite’s acreage in Dimmit, Webb, La Salle, Zavala and Maverick counties, Texas (such acreage is collectively referred to as Mesquite’s “Comanche Asset”) pursuant to a new long-term firm gas gathering and processing agreement. The agreement with Mesquite, which was approved by all of the unaffiliated Comanche Asset working interest partners, establishes commercial terms for the gathering of gas on the Carnero Gathering Line and processing at the Raptor Gas Processing Facility and Silver Oak II. Prior to execution of the agreement, volumes from the Comanche Asset were gathered and processed on an interruptible basis, with the processing capabilities of the Carnero JV limited by the capacity of the Raptor Gas Processing Facility. As a result of the Carnero JV Transaction, we now record our share of earnings and losses from the Carnero JV using the Hypothetical Liquidation at Book Value (“HLBV”) method of accounting. HLBV is a balance-sheet approach that calculates the amount we would have received if the Carnero JV were liquidated at book value at the end of each measurement period. The change in our allocated amount during the period is recognized in our condensed consolidated statements of operations. In the event of liquidation of the Carnero JV, available proceeds are first distributed to any priority return and unpaid capital associated with Silver Oak II, and then to members in accordance with their capital accounts. As of September 30, 2021 the Partnership had paid approximately $124.4 million for its investment in the Carnero JV related to the initial payments and contributed capital. The Partnership has accounted for this investment using the equity method. Targa is the operator of the Carnero JV and has significant influence with respect to the normal day-to-day capital and operating decisions. We have included the investment balance in the equity investments caption on the condensed consolidated balance sheets. For the three months ended September 30, 2021, the Partnership recorded an insignificant amount of earnings in equity investments from the Carnero JV, which was offset by approximately $0.3 million related to the amortization of the contractual customer intangible asset. For the nine months ended September 30, 2021, the Partnership recorded losses of approximately $0.5 million in equity investments from the Carnero JV, which was compounded by approximately $0.9 million related to the amortization of the contractual customer intangible asset. We have included these equity method earnings in the earnings from equity investments line within the condensed consolidated statements of operations. Cash distributions of approximately $11.9 million were received during the nine months ended September 30, 2021. Summarized financial information of unconsolidated entities is as follows (in thousands): Nine Months Ended September 30, 2021 2020 Sales $ 78,026 $ 55,578 Total expenses 74,662 44,965 Net income $ 3,364 $ 10,613

Commitments And Contingencies

Commitments And Contingencies	9 Months Ended
Commitments And Contingencies	Sep. 30, 2021
Commitments And Contingencies
Commitments And Contingencies	12. COMMITMENTS AND CONTINGENCIES As part of the Carnero Gathering Transaction, we are required to pay Mesquite an earnout based on natural gas received above a threshold volume and tariff at designated delivery points from Mesquite and other producers. This earnout has an approximate value of zero as of September 30, 2021. For the nine months ended September 30, 2021, we made no payments to Mesquite related to the earnout.

Related Party Transactions

Related Party Transactions	9 Months Ended
Related Party Transactions	Sep. 30, 2021
Related Party Transactions
Related Party Transactions	13. RELATED PARTY TRANSACTIONS Please read the disclosure under the headings “Relationship with Stonepeak,” “Relationship with Mesquite,” “Relationship with SP Holdings” and “Shared Services Agreement” in Note 13 “Related Party Transactions” of our Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2020 for a more complete description of certain related party transactions that were entered into prior to 2021.

Unit-Based Compensation

Unit-Based Compensation	9 Months Ended
Unit-Based Compensation	Sep. 30, 2021
Unit-Based Compensation
Unit-Based Compensation	14. UNIT-BASED COMPENSATION The Sanchez Production Partners LP Long-Term Incentive Plan (the “LTIP”) allows for grants of restricted common units. Restricted common unit activity under the LTIP during the period is presented in the following table: Weighted Average Number of Grant Date Restricted Fair Value Units Per Unit Outstanding at December 31, 2020 683,171 $ 2.68 Granted 1,651,785 1.12 Returned/Cancelled (140,647) 2.37 Outstanding at September 30, 2021 2,194,309 $ 1.53 In March 2021, the Partnership issued 1,651,785 restricted common units pursuant to the LTIP to certain officers of the Partnership’s general partner. Two-thirds of the restricted common units vest on the one year anniversary of the date of grant and the remaining one-third vest on the second year anniversary of the date of grant. The number of restricted common units granted was based on the fair value on the day before the grant date. As of September 30, 2021, 7,619,823 common units remained available for future issuance to participants under the LTIP.

Partners' Capital

Partners' Capital	9 Months Ended
Partners' Capital	Sep. 30, 2021
Partners' Capital
Partners' Capital	15. PARTNERS’ CAPITAL Outstanding Units As of September 30, 2021, we had 36,474,436 Class C Preferred Units outstanding and 96,465,219 common units outstanding which included 2,194,309 unvested restricted common units issued under the LTIP. Common Unit Issuances We entered into a letter agreement with SP Holdings providing that during the period beginning with the fiscal quarter ended September 30, 2019 and continuing until the end of the fiscal quarter after the fiscal quarter in which we redeem all of our issued and outstanding Class C Preferred Units, SP Holdings agrees to delay receipt of its fees, not including reimbursement of costs, as a result, we have not issued any common units to SP Holdings in connection with providing services under the Shared Services Agreement for any quarter following the quarter ended June 30, 2019. As of September 30, 2021, the number of units to be issued under the Shared Services Agreement is 14,611,540. Class C Preferred Units On August 2, 2019, Stonepeak exchanged all of their current equity ownership for newly issued Class C Preferred Units and the Stonepeak Warrant in a private placement transaction (the “Exchange”). The holders of the Class C Preferred Units receive a quarterly distribution of 12.5% per annum payable in cash. To the extent that Available Cash (as defined in the Third Amended and Restated Agreement of Limited Partnership of the Partnership (the “Amended Partnership Agreement”)) is insufficient to pay the distribution in cash, all or a portion of the distribution may be paid in Class C Preferred PIK Units. Commencing with the quarter ending March 31, 2022, the distribution rate will increase to 14% per annum. Distributions are to be paid on or about the last day of each of February, May, August and November following the end of each quarter and are charged to interest expense in our condensed consolidated statements of operations. Beginning January 1, 2022, Adjusted Available Cash (as defined in the Amended Partnership Agreement) will be distributed to holders of the Class C Preferred Units to redeem a number of Class C Preferred Units to be determined based on the amount of Adjusted Available Cash. The Class C Preferred Units are accounted for as a current liability on our condensed consolidated balance sheet consisting of the following (in thousands): September 30, December 31, 2021 2020 Class C Preferred Units, beginning balance $ 345,205 $ 281,688 Accretion of discount 37,671 38,938 Distribution accrual — 24,579 Class C Preferred Units, ending balance $ 382,876 $ 345,205 The table below reflects the payment of distributions on Class C Preferred Units related to the periods indicated. Class C Preferred Date of Date of Date of Three Months Ended PIK Distribution Declaration Record Distribution December 31, 2019 1,039,314 February 13, 2020 February 28, 2020 February 20, 2020 March 31, 2020 1,071,793 April 29, 2020 May 20, 2020 May 29, 2020 June 30, 2020 1,105,286 July 31, 2020 August 20, 2020 August 31, 2020 On November 16, 2020, the Partnership and Stonepeak entered into the Stonepeak Letter Agreement wherein the parties agreed that the distribution on the Class C Preferred Units for the three months ended September 30, 2020 would be paid in common units instead of Class C Preferred PIK Units, cash or a combination thereof. The Stonepeak Letter Agreement also provides that Stonepeak will be able to elect to receive distributions on the Class C Preferred Units in common units for any quarter following the third quarter of 2020 by providing written notice to the Partnership no later than the last day of the calendar month following the end of such quarter. The table below reflects distributions on Class C Preferred Units which were elected to be paid in common units related to the periods indicated. Class C Preferred Date of Three Months Ended Distribution of Common Units Distribution September 30, 2020 22,274,869 February 1, 2021 December 31, 2020 12,445,491 February 25, 2021 March 31, 2021 13,763,249 May 20, 2021 June 30, 2021 8,012,850 August 20, 2021 Stonepeak Warrant On August 2, 2019 , in connection with the Exchange, the Partnership issued to Stonepeak the Stonepeak Warrant, which entitles the holder to receive junior securities representing ten percent of junior securities deemed outstanding when exercised. The Stonepeak Warrant expires on the later of August 2, 2026 or 30 days following the full redemption of the Class C Preferred Units. There is no strike price associated with the exercise of the Stonepeak Warrant. The Stonepeak Warrant is accounted for as a liability in accordance with ASC 480 and is presented within other liabilities on the condensed consolidated balance sheet. Changes in the fair value of the Stonepeak Warrant are charged to interest expense in our condensed consolidated statements of operations. Earnings per Unit Net income (loss) per common unit for the period is based on any distributions that are made to the unitholders (common units) plus an allocation of undistributed net income (loss) based on provisions of the Amended Partnership Agreement, divided by the weighted average number of common units outstanding. The two-class method dictates that net income (loss) for a period be reduced by the amount of distributions and that any residual amount representing undistributed net income (loss) be allocated to common unitholders and other participating unitholders to the extent that each unit may share in net income (loss) as if all of the net income for the period had been distributed in accordance with the Amended Partnership Agreement. Unit-based awards granted but unvested are eligible to receive distributions. The underlying unvested restricted unit awards are considered participating securities for purposes of determining net income (loss) per unit. Undistributed income is allocated to participating securities based on the proportional relationship of the weighted average number of common units and unit-based awards outstanding. Undistributed losses (including those resulting from distributions in excess of net income) are allocated to common units based on provisions of the Amended Partnership Agreement. Undistributed losses are not allocated to unvested restricted unit awards as they do not participate in net losses. Distributions declared and paid in the period are treated as distributed earnings in the computation of earnings per common unit even though cash distributions are not necessarily derived from current or prior period earnings. The Partnership’s general partner does not have an economic interest in the Partnership and, therefore, does not participate in the Partnership’s net income.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
Variable Interest Entities	Sep. 30, 2021
Variable Interest Entities
Variable Interest Entities	16. VARIABLE INTEREST ENTITIES The Partnership’s investment in the Carnero JV represents a variable interest entity (“VIE”) that could expose the Partnership to losses. The amount of losses the Partnership could be exposed to from the Carnero JV is limited to the capital investment of approximately $76.5 million. As of September 30, 2021, the Partnership had invested approximately $124.4 million in the Carnero JV and no debt has been incurred by the Carnero JV. We have included this VIE in other assets, equity investments on our condensed consolidated balance sheet. Below is a tabular comparison of the carrying amounts of the assets and liabilities of the VIE and the Partnership’s maximum exposure to loss as of September 30, 2021 and December 31, 2020 (in thousands): September 30, December 31, 2021 2020 Acquisitions, earnout and capital investments $ 128,483 $ 128,251 Earnings in equity investments 29,049 30,455 Distributions received (81,017) (69,071) Maximum exposure to loss $ 76,515 $ 89,635

Subsequent Events

Subsequent Events	9 Months Ended
Subsequent Events	Sep. 30, 2021
Subsequent Events
Subsequent Events	17. SUBSEQUENT EVENTS NYSE American Update On October 4, 2021, the NYSE American informed us that we regained compliance with the NYSE American Company Guide (the “Company Guide”) by meeting the requirements of the $50 million market capitalization exemption from the stockholders’ equity requirement in Section 1003(a) of the Company Guide. At the opening of trading on October 5, 2021, the below compliance (“.BC”) indicator was no longer disseminated and the Partnership was removed from the list of NYSE American noncompliant issuers on the NYSE American’s website. Mesquite Adversary Proceeding On October 15, 2021, Mesquite and SN Catarina, LLC (collectively, the “Mesquite Plaintiffs”) initiated adversary proceeding 21-03931 (MI) against the Partnership and Catarina Midstream, LLC (“Catarina Midstream”) in the Bankruptcy Court (the “Mesquite Adversary”). In the Mesquite Adversary, the Mesquite Plaintiffs seek recharacterization of the September 2015 transaction pursuant to which the Partnership acquired from SN Catarina all of SN Catarina’s interest in Catarina Midstream, including the gathering assets then-owned by SN Catarina (the “Catarina Arrangement”), as a disguised financing. The Mesquite Plaintiffs claim that SN Catarina is the legal owner of the gathering system subject to that transaction and demand its return. The Mesquite Plaintiffs also assert various claims for constructive and actual fraudulent transfer arising from (1) the Catarina Arrangement; (2) payments made by SN Catarina to Catarina Midstream under the Gathering Agreement after Catarina Midstream increased tariff rates for interruptible throughput volumes from the eastern portion (“Eastern Catarina”) of Mesquite’s acreage position in Dimmit, La Salle and Webb counties in Texas; and (3) payments made by SN Catarina to Catarina Midstream for the incremental infrastructure fee under the Gathering Agreement amendment and on a month-to-month basis by mutual agreement of the parties after the amendment’s expiration. The Mesquite Plaintiffs seek declaratory relief related to the recharacterization claim as well as avoidance of the alleged constructive and actual fraudulent transfers and recovery of the amounts transferred to Catarina Midstream. Stonepeak Letter Agreement Election On October 29, 2021, pursuant to the terms of the Stonepeak Letter Agreement, the Partnership received written notice of Stonepeak’s election to receive distributions on the Class C Preferred Units for the quarter ended September 30, 2021, in common units. In accordance with the Stonepeak Letter Agreement, the Partnership will issue 10,832,186 common units to Stonepeak on November 22, 2021 (the “Q321 Stonepeak Units”). HOBO Transaction; New Management Team Hires On November 3, 2021, the Partnership entered into a Framework Agreement (the “Framework Agreement”) with HOBO Renewable Diesel LLC (“HOBO”). The Framework Agreement provides that, subject to the satisfaction of applicable conditions precedent, the Partnership will fund certain development expenses of HOBO as HOBO seeks to develop, construct, own and operate renewable fuels facilities. HOBO’s initial project is a 9,000 barrel per day (120 million gallons per year) renewable diesel production facility to be located in Clinton, Iowa (the “Initial Project”). Subject to the satisfaction of certain conditions, including HOBO securing a long-term strategic offtake agreement for the Initial Project, the Partnership will exclusively fund the development and construction of the Initial Project and future renewable fuels projects that can produce renewable diesel and sustainable aviation fuel (“SAF”) and contribute to the advancement of the transition to a low-carbon world. Renewable diesel and SAF are unique drop-in fuels that are immediately consumable by existing automotive and airplane engines and reduce carbon emissions relative to petroleum based products. These drop-in fuels are in increasingly high demand by customers, including the US federal government, as more organizations embrace de-carbonization. HOBO and the Partnership are also considering incorporation of additional carbon reduction opportunities into the Initial Project and future projects which the management teams believe could result in the production of some of the lowest carbon intensity fuels in the US. We refer to the transactions described above or otherwise contemplated by the Framework Agreement as the “HOBO Transaction.” In furtherance of the Initial Project and to support the Partnership’s energy transition focus, key members of the HOBO leadership team will join the Partnership’s management team effective December 1st, 2021. HOBO Co-Founder and Chief Executive Officer Randy Gibbs will join as the new Chief Executive Officer, and as a member of the Board, HOBO Co-Founder and President Mike Keuss will join as the new President and Chief Operating Officer, and HOBO’s Chief Financial Officer Jonathan Hartigan will join as the new President and Chief Investment Officer (the “New Executives”). Each of the New Executives accepted employment effective November 3, 2021, and will transition to their respective director and executive roles effective December 1, 2021. The New Executives have each had long and successful careers in both the fossil fuel and renewable energy spaces and bring extensive experience in project development, engineering, operations, and financing to the Partnership’s management team. In connection with the management team hires, the Partnership’s general partner entered into Executive Services Agreements with each of the New Executives and issued awards under the Evolve Transition Infrastructure 2021 Equity Inducement Award Plan totaling 14,100,000 common units, and under the Partnership’s Long-Term Incentive Plan (the “LTIP”) totaling 3,600,000 common units (such 17,700,000 common units, collectively, the “New Executive Units”). The New Executive Units are subject to vesting in three separate tranches if certain performance conditions with respect to the Initial Project are satisfied or if certain performance metrics relating to total unitholder return are satisfied. Resignation of Chief Executive Officer; Transition Agreement On November 3, 2021, Gerald Willinger, the current Chief Executive Officer of the Partnership’s general partner, resigned from his position as Chief Executive Officer of the Partnership’s general partner and a member of the Board, effective November 30, 2021 and at such time that is immediately prior to December 1, 2021. Mr. Willinger will assist in the onboarding of new management in November to ensure a smooth transition. In connection with Mr. Willinger’s departure, on November 3, 2021, the Partnership’s general partner entered into a Separation and Transition Agreement with Mr. Willinger. Amendments to Stonepeak Warrant As previously disclosed, the LTIP provides that upon the issuance of additional common units from time to time, the maximum number of common units that may be delivered or reserved for delivery with respect to the LTIP shall be automatically increased (each such increase, an “LTIP Increase”) by a number of common units equal to the lesser of (i) fifteen percent (15%) of such additional common units, or (ii) such lesser number of common units as determined by the Board. On October 29, 2021, the Board determined that the LTIP Increase with respect to the Q321 Stonepeak Units will be fifteen percent (15%). On November 5, 2021, the Partnership and Stonepeak entered into Amendment No. 4 to the Stonepeak Warrant to exclude from the Stonepeak Warrant the 1,624,828 Common Units included in the LTIP Increase resulting from the issuance of the Q321 Stonepeak Units, resulting in an additional 1,624,828 Common Units being reserved for delivery with respect to the LTIP. On November 9, 2021, the Board determined that the LTIP Increase with respect to the New Executive Units will be fifteen percent (15%), resulting in an additional 2,655,000 common units being reserved for delivery with respect to the LTIP. On November 9, 2021, the Partnership and Stonepeak entered into Amendment No. 5 to the Stonepeak Warrant to exclude from the Stonepeak Warrant both the New Executive Units and the 2,655,000 Common Units included in the LTIP Increase resulting from the issuance of the New Executive Units.

Basis Of Presentation And Sum_2

Basis Of Presentation And Summary Of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2021
Basis Of Presentation And Summary Of Significant Accounting Policies
Basis of Presentation	Basis of Presentation Accounting policies used by us conform to accounting principles generally accepted in the United States of America (“GAAP”). The accompanying financial statements include the accounts of us and our wholly owned subsidiaries. All intercompany accounts and transactions have been eliminated in consolidation. These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures, normally included in annual financial statements prepared in accordance with GAAP, have been condensed or omitted pursuant to those rules and regulations. We believe that the disclosures made are adequate to make the information presented not misleading. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, necessary to fairly state the financial position, results of operations and cash flows with respect to the interim condensed consolidated financial statements have been included. The results of operations for the interim periods are not necessarily indicative of the results for the entire year. These unaudited condensed consolidated financial statements should be read in conjunction with our audited consolidated financial statements and the notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2020, which was filed with the SEC on March 16, 2021.
Recent Accounting Pronouncements	Recent Accounting Pronouncements From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board (“FASB”), which are adopted by us as of the specified effective date. Unless otherwise discussed, management believes that the impact of recently issued standards, which are not effective, will not have a material impact on our consolidated financial statements upon adoption. In January 2020, the FASB issued Accounting Standards Update (“ASU”) 2020-01 “Investments – Equity Securities (Topic 321), Investments – Equity Method and Joint Ventures (Topic 323), and Derivatives and Hedging (Topic 815),” which clarifies the interaction among the accounting standards for equity securities, equity method investments and certain derivatives. This ASU is effective for public business entities for annual and interim periods in fiscal years beginning after December 15, 2020. The adoption of this standard did not have a material impact on our condensed consolidated financial statements. In June 2016, the FASB issued ASU 2016-13, “Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments.” This ASU modifies the impairment model to utilize an expected loss methodology in place of the currently used incurred loss methodology, which will result in more timely recognition of losses. Additionally, in November 2019, the FASB issued ASU 2019-10, “Financial Instruments – Credit Losses (Topic 326), Derivatives and Hedging (Topic 815), and Leases (Topic 842): Effective Dates,” which changed the effective date for certain issuers to annual and interim periods in fiscal years beginning after December 15, 2022, and earlier adoption is permitted. We are currently in the process of evaluating the impact of adoption of this guidance on our condensed consolidated financial statements. Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Partnership’s financial position, results of operations and cash flows.
Use of Estimates	Use of Estimates The condensed consolidated financial statements are prepared in conformity with GAAP, which requires management to make estimates and assumptions that affect the amounts reported in the condensed consolidated financial statements and accompanying notes. These estimates and the underlying assumptions affect the amounts of assets and liabilities reported, disclosures about contingent assets and liabilities and reported amounts of revenues and expenses. The estimates that are particularly significant to our financial statements include estimates of our reserves of natural gas, NGLs and oil; future cash flows from oil and natural gas properties; depreciation, depletion and amortization; asset retirement obligations; certain revenues and operating expenses; fair values of derivatives; and fair values of assets and liabilities. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best judgment using the data available. Management evaluates its estimates and assumptions on an on-going basis using historical experience and other factors, including the current economic environment, which management believes to be reasonable under the circumstances. Such estimates and assumptions are adjusted when facts and circumstances dictate. As future events and their effects cannot be determined with precision, actual results could differ from the estimates. Any changes in estimates resulting from continuing changes in the economic environment will be reflected in the financial statements in future periods.

Discontinued Operations (Tables

Discontinued Operations (Tables)	9 Months Ended
Discontinued Operations (Tables)	Sep. 30, 2021
Discontinued Operations
Schedule Of Discontinued Operations	Three Months Ended Nine Months Ended September 30, September 30, 2021 2020 2021 2020 Revenues Natural gas sales $ — $ 16 $ 255 $ 334 Oil sales 5 1,755 3,241 9,129 Natural gas liquid sales — 69 182 170 Total revenues 5 1,840 3,678 9,633 Expenses Operating expenses Lease operating expenses 20 891 1,797 3,859 Production taxes — 112 160 262 Gain on sale of assets (203) — (537) — Depreciation, depletion and amortization — 360 439 1,856 Asset impairments — — — 23,247 Accretion expense — 55 73 159 Total operating expenses (183) 1,418 1,932 29,383 Income (loss) before income taxes 188 422 1,746 (19,750) Income tax expense (benefit) 1 3 457 (137) Income (loss) from discontinued operations $ 187 $ 419 $ 1,289 $ (19,613)

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2021
Fair Value Measurements
Schedule of fair value of assets and liabilities on a recurring basis	The following table summarizes the fair value of our assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2021 (in thousands): Fair Value Measurements at September 30, 2021 Active Markets for Observable Identical Assets Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value Fair value of warrants Nuvve Holding Warrants $ — $ 160 $ — $ 160 Other liabilities Stonepeak Warrant — (11,654) — (11,654) Total $ — $ (11,494) $ — $ (11,494) The following table summarizes the fair value of our assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2020 (in thousands): Fair Value Measurements at December 31, 2020 Active Markets for Observable Identical Assets Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value Other liabilities Stonepeak Warrant — (1,418) — (1,418) Total $ — $ (1,418) $ — $ (1,418)
Schedule of non-recurring fair value measurements	The following table summarizes the non-recurring fair value measurements of our production assets as of December 31, 2020 (in thousands): Fair Value Measurements at December 31, 2020 Active Markets for Observable Identical Assets Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Impairment (a) $ — $ — $ 12,884 Total net assets $ — $ — $ 12,884 (a) During the year ended December 31, 2020, we recorded a non-cash impairment charge of $23.4 million to impair our producing oil and natural gas properties and $0.9 million to impair the Seco Pipeline. The carrying values of the impaired properties were reduced to a fair value of approximately $12.9 million, estimated using inputs characteristic of a Level 3 fair value measurement.

Derivative And Financial Inst_2

Derivative And Financial Instruments (Tables)	9 Months Ended
Derivative And Financial Instruments (Tables)	Sep. 30, 2021
Derivative [Line Items]
Schedule Of Effect Of Derivative Instruments On Consolidated Statements Of Operations	The effect of derivative instruments on our condensed consolidated statements of operations for each of the three and nine months ended September 30, 2020 was as follows (in thousands). As disclosed above, we did not hedge any of our expected production volumes for 2021. Location of Gain (Loss) Three Months Ended September 30, Nine Months Ended September 30, Derivative Type in Income September 30, 2020 September 30, 2020 Commodity – Mark-to-Market Income (loss) from discontinued operations $ (115) $ 3,912 Commodity – Mark-to-Market Income (loss) from discontinued operations (55) 96 $ (170) $ 4,008
Warrants
Derivative [Line Items]
Reconciliation Of Changes In Fair Value Of Derivatives	The following table sets forth a reconciliation of the changes in fair value of the Partnership’s Nuvve Holding Warrants for the periods indicated (in thousands): Nine Months Ended September 30, 2021 Beginning fair value of warrants $ — Net gain (loss) on warrants 160 Ending fair value of warrants $ 160
Commodity derivatives
Derivative [Line Items]
Reconciliation Of Changes In Fair Value Of Derivatives	The following table sets forth a reconciliation of the changes in fair value of the Partnership’s commodity derivatives for the year ended December 31, 2020 (in thousands): Year Ended December 31, 2020 Beginning fair value of commodity derivatives $ (759) Net gains (losses) on crude oil derivatives 3,814 Net gains on natural gas derivatives 87 Net settlements received on derivative contracts: Oil (2,829) Natural gas (313) Ending fair value of commodity derivatives $ —

Oil And Natural Gas Propertie_2

Oil And Natural Gas Properties And Related Equipment (Tables)	9 Months Ended
	Sep. 30, 2021
Oil And Natural Gas Properties And Related Equipment.
Schedule of gathering and transportation assets	Gathering and transportation assets consisted of the following (in thousands): September 30, December 31, 2021 2020 Gathering and transportation assets Midstream assets $ 187,899 $ 187,977 Less: Accumulated depreciation and impairment (87,991) (82,710) Total gathering and transportation assets, net $ 99,908 $ 105,267
Schedule of oil and natural gas properties	September 30, December 31, 2021 2020 Gathering and transportation assets Midstream assets $ 187,899 $ 187,977 Less: Accumulated depreciation and impairment (87,991) (82,710) Total gathering and transportation assets, net $ 99,908 $ 105,267
Schedule of depreciation, depletion, and amortization	Depreciation and amortization consisted of the following (in thousands): Three Months Ended Nine Months Ended September 30, September 30, 2021 2020 2021 2020 Depreciation and amortization of gathering and transportation related assets $ 1,778 $ 1,830 $ 5,337 $ 5,419 Amortization of intangible assets 3,365 3,363 10,093 10,093 Total depreciation and amortization $ 5,143 $ 5,193 $ 15,430 $ 15,512

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	9 Months Ended
Asset Retirement Obligation (Tables)	Sep. 30, 2021
Asset Retirement Obligation
Reconciliation of changes in asset retirement obligation	The following table is a reconciliation of changes in ARO for the nine months ended September 30, 2021 and the year ended December 31, 2020 (in thousands): Nine Months Ended Year Ended September 30, 2021 December 31, 2020 Asset retirement obligation, beginning balance $ 4,313 $ 3,958 Accretion expense 287 355 Asset retirement obligation, ending balance $ 4,600 $ 4,313

Intangible Assets (Tables)

Intangible Assets (Tables)	9 Months Ended
Intangible Assets (Tables)	Sep. 30, 2021
Intangible Assets
Schedule of Intangible assets	September 30, December 31, 2021 2020 Beginning balance $ 131,786 $ 145,246 Amortization (10,093) (13,460) Ending balance $ 121,693 $ 131,786

Investments (Tables)

Investments (Tables)	9 Months Ended
Investments (Tables)	Sep. 30, 2021
Investments
Summarized financial information of unconsolidated entities	Summarized financial information of unconsolidated entities is as follows (in thousands): Nine Months Ended September 30, 2021 2020 Sales $ 78,026 $ 55,578 Total expenses 74,662 44,965 Net income $ 3,364 $ 10,613

Unit-Based Compensation (Tables

Unit-Based Compensation (Tables)	9 Months Ended
Unit-Based Compensation (Tables)	Sep. 30, 2021
Unit-Based Compensation
Schedule of units activity	Weighted Average Number of Grant Date Restricted Fair Value Units Per Unit Outstanding at December 31, 2020 683,171 $ 2.68 Granted 1,651,785 1.12 Returned/Cancelled (140,647) 2.37 Outstanding at September 30, 2021 2,194,309 $ 1.53

Partners' Capital (Tables)

Partners' Capital (Tables)	9 Months Ended
Partners' Capital (Tables)	Sep. 30, 2021
Schedule of Class C preferred units	The Class C Preferred Units are accounted for as a current liability on our condensed consolidated balance sheet consisting of the following (in thousands): September 30, December 31, 2021 2020 Class C Preferred Units, beginning balance $ 345,205 $ 281,688 Accretion of discount 37,671 38,938 Distribution accrual — 24,579 Class C Preferred Units, ending balance $ 382,876 $ 345,205
Class C preferred units
Schedule of distributions	Class C Preferred Date of Date of Date of Three Months Ended PIK Distribution Declaration Record Distribution December 31, 2019 1,039,314 February 13, 2020 February 28, 2020 February 20, 2020 March 31, 2020 1,071,793 April 29, 2020 May 20, 2020 May 29, 2020 June 30, 2020 1,105,286 July 31, 2020 August 20, 2020 August 31, 2020
Common Units
Schedule of distributions	Class C Preferred Date of Three Months Ended Distribution of Common Units Distribution September 30, 2020 22,274,869 February 1, 2021 December 31, 2020 12,445,491 February 25, 2021 March 31, 2021 13,763,249 May 20, 2021 June 30, 2021 8,012,850 August 20, 2021

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	9 Months Ended
Variable Interest Entities (Tables)	Sep. 30, 2021
Variable Interest Entities
Schedule of carrying amounts of assets and liabilities of variable interest entity	Below is a tabular comparison of the carrying amounts of the assets and liabilities of the VIE and the Partnership’s maximum exposure to loss as of September 30, 2021 and December 31, 2020 (in thousands): September 30, December 31, 2021 2020 Acquisitions, earnout and capital investments $ 128,483 $ 128,251 Earnings in equity investments 29,049 30,455 Distributions received (81,017) (69,071) Maximum exposure to loss $ 76,515 $ 89,635

Discontinued Operations (Detail

Discontinued Operations (Details) - USD ($)	Aug. 13, 2021	Apr. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues			$ 5,000	$ 1,840,000	$ 3,678,000	$ 9,633,000
Lease operating expenses			20,000	891,000	1,797,000	3,859,000
Production taxes				112,000	160,000	262,000
Gain on sale of assets			(203,000)		(537,000)
Depreciation, depletion and amortization				360,000	439,000	1,856,000
Asset impairments						23,247,000
Accretion expense				55,000	73,000	159,000
Total operating expenses			(183,000)	1,418,000	1,932,000	29,383,000
Income (loss) before income taxes			188,000	422,000	1,746,000	(19,750,000)
Income tax expense (benefit)			1,000	3,000	457,000	(137,000)
Income (loss) from discontinued operations			187,000	419,000	1,289,000	(19,613,000)
Divestiture of (The "Palmetto Assets")
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture		$ 11,500,000
Divestiture gain		300,000
Divestiture of (The "Maverick 1 Assets")
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture		2,800,000
Divestiture of (The "Maverick 2 Assets")
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture		1,400,000
Closing adjustment		$ 31,000
Divestiture of (The "Maverick 3 Assets")
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture	$ 31,000
Divestitures of (The "Maverick Assets")
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Divestiture gain					200,000
Natural gas sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues				16,000	255,000	334,000
Oil sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues			$ 5,000	1,755,000	3,241,000	9,129,000
Natural gas liquid sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues				$ 69,000	$ 182,000	$ 170,000

Revenue Recognition (Details)

Revenue Recognition (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
Revenue Recognition (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Revenue Recognition
Revenues	$ 16,868	$ 10,670	$ 35,304	$ 35,400
Payment term (in days)			30 days
Receivables	$ 1,900		$ 1,900

Fair Value Measurements (Recurr

Fair Value Measurements (Recurring) (Details) - Recurring - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value of warrants: Nuvve Holding Warrants	$ 160
Other liabilities: Stonepeak Warrant	(11,654)	$ (1,418)
Total	(11,494)	(1,418)
Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value of warrants: Nuvve Holding Warrants	160
Other liabilities: Stonepeak Warrant	(11,654)	(1,418)
Total	$ (11,494)	$ (1,418)

Fair Value Measurements (Non-Re

Fair Value Measurements (Non-Recurring) (Details) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2021miMMcf	Dec. 31, 2020USD ($)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Market-based weighted average cost of capital rate	15.00%
Nonrecurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Asset impairments		$ 23,400
Seco Pipeline, LLC
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Number of miles of natural gas pipeline \| mi	30
Daily pipeline capacity (MMcf/d) \| MMcf	400
Seco Pipeline, LLC \| Nonrecurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Asset impairments		900
Fair Value, Inputs, Level 3 \| Nonrecurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Impairment		12,884
Fair value		12,884
Fair Value, Inputs, Level 3 \| Seco Pipeline, LLC \| Nonrecurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value		0
Asset impairments		$ 900

Derivative And Financial Inst_3

Derivative And Financial Instruments (Details) - Levo Mobility LLC Joint Venture - Nuvve Holding Corp $ / shares in Units, $ in Millions	May 17, 2021USD ($)$ / sharesshares
Derivative [Line Items]
Warrants and Rights Outstanding, Term	10 years
Series B Warrants
Derivative [Line Items]
Number of shares called by warrants \| shares	200,000
Warrants exercise price \| $ / shares	$ 10
Series C Warrants
Derivative [Line Items]
Number of shares called by warrants \| shares	100,000
Warrants exercise price \| $ / shares	$ 15
Aggregate capital expenditures threshold for warrants vesting \| $	$ 125
Series C Warrants \| Vested upon issuance
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series C Warrants \| Vested upon Levo entry into threshold amount of contracts with third parties
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series D Warrants
Derivative [Line Items]
Number of shares called by warrants \| shares	100,000
Warrants exercise price \| $ / shares	$ 20
Aggregate capital expenditures threshold for warrants vesting \| $	$ 250
Series D Warrants \| Vested upon issuance
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series D Warrants \| Vested upon Levo entry into threshold amount of contracts with third parties
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series E Warrants
Derivative [Line Items]
Number of shares called by warrants \| shares	100,000
Warrants exercise price \| $ / shares	$ 30
Aggregate capital expenditures threshold for warrants vesting \| $	$ 375
Series E Warrants \| Vested upon issuance
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series E Warrants \| Vested upon Levo entry into threshold amount of contracts with third parties
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series F Warrants
Derivative [Line Items]
Number of shares called by warrants \| shares	100,000
Warrants exercise price \| $ / shares	$ 40
Aggregate capital expenditures threshold for warrants vesting \| $	$ 500
Series F Warrants \| Vested upon issuance
Derivative [Line Items]
Warrants vesting percentage	50.00%
Series F Warrants \| Vested upon Levo entry into threshold amount of contracts with third parties
Derivative [Line Items]
Warrants vesting percentage	50.00%

Derivative And Financial Inst_4

Derivative And Financial Instruments (Changes In Fair Value) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Warrants
Derivative [Line Items]
Net gain (loss)		$ 160
Ending fair value		$ 160
Commodity derivatives
Derivative [Line Items]
Beginning fair value			$ (759)	$ (759)
Net gain (loss)	$ (170)		4,008
Oil reserves \| Commodity derivatives
Derivative [Line Items]
Net gain (loss)	(115)		3,912	3,814
Net settlements received on derivative contracts				(2,829)
Natural gas \| Commodity derivatives
Derivative [Line Items]
Net gain (loss)	$ (55)		$ 96	87
Net settlements received on derivative contracts				$ (313)

Derivative And Financial Inst_5

Derivative And Financial Instruments (Effect On Statement Of Operations) (Details) - Commodity derivatives - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2020	Sep. 30, 2020	Dec. 31, 2020
Derivative Instruments Gain Loss [Line Items]
Net gain (loss)	$ (170)	$ 4,008
Oil reserves
Derivative Instruments Gain Loss [Line Items]
Net gain (loss)	(115)	3,912	$ 3,814
Natural gas
Derivative Instruments Gain Loss [Line Items]
Net gain (loss)	$ (55)	$ 96	$ 87

Debt (Details)

Debt (Details) $ in Thousands	3 Months Ended		9 Months Ended
Debt (Details) $ in Thousands	Sep. 30, 2021USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2021USD ($)	Sep. 30, 2020USD ($)	Dec. 31, 2020USD ($)	Nov. 06, 2020USD ($)
Line of Credit Facility [Line Items]
Credit agreement available	$ 2,500		$ 2,500
Letters of credit outstanding	0		0
Credit agreement, outstanding	54,700		54,700
Amortization of debt issuance costs	300	$ 200	828	$ 553
Unamortized debt issue costs	700		$ 700		$ 800
Credit Agreement
Line of Credit Facility [Line Items]
Maximum borrowing capacity						$ 65,000
Commitment fee on unutilized borrowing base			0.50%
Credit agreement, outstanding	$ 52,200		$ 52,200
Current assets to current liabilities ratio			1
Debt to Adjusted EBITDA ratio	3.25		3.25
Credit Agreement \| Amount per fiscal quarter commencing with the quarter ending December 31, 2021
Line of Credit Facility [Line Items]
Line of Credit Facility, Periodic Payment			$ 3,000
Credit Agreement \| Amount per fiscal quarter commencing with the quarter ending March 31, 2023
Line of Credit Facility [Line Items]
Line of Credit Facility, Periodic Payment			2,000
Revolving Credit Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 5,000		5,000			$ 5,000
Credit agreement, outstanding	2,500		2,500
Letter of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 2,500		$ 2,500
Minimum \| Credit Agreement
Line of Credit Facility [Line Items]
Ownership percentage by subsidiary			50
Minimum \| Credit Agreement \| London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Variable interest rate			2.75%
Minimum \| Credit Agreement \| ABR
Line of Credit Facility [Line Items]
Variable interest rate			1.75%
Maximum \| Credit Agreement \| London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Variable interest rate			3.50%
Maximum \| Credit Agreement \| ABR
Line of Credit Facility [Line Items]
Variable interest rate			2.50%

Oil And Natural Gas Propertie_3

Oil And Natural Gas Properties And Related Equipment (Gathering and Transportation Assets) (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Midstream assets	$ 99,908	$ 105,267
Midstream
Property, Plant and Equipment [Line Items]
Midstream assets	187,899	187,977
Less: Accumulated depreciation, amortization and impairment	(87,991)	(82,710)
Total gathering and transportation assets, net	$ 99,908	$ 105,267

Oil And Natural Gas Propertie_4

Oil And Natural Gas Properties And Related Equipment (DDA and Impairments) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Property, Plant and Equipment [Line Items]
Amortization of intangible assets	$ 3,365	$ 3,363	$ 10,093	$ 10,093
Depreciation, depletion and amortization			$ 5,777	7,275
Asset impairments				23,247
Furniture and Equipment \| Minimum
Property, Plant and Equipment [Line Items]
Useful lives			3 years
Furniture and Equipment \| Maximum
Property, Plant and Equipment [Line Items]
Useful lives			15 years
Gathering Facilities \| Maximum
Property, Plant and Equipment [Line Items]
Useful lives			36 years
Transportation assets \| Maximum
Property, Plant and Equipment [Line Items]
Useful lives			40 years
Gathering and Transportation Related Assets
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	1,778	1,830	$ 5,337	5,419
Oil and Natural Gas-Related Assets and Gathering and Transportation-Related Assets
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	$ 5,143	$ 5,193	$ 15,430	$ 15,512

Asset Retirement Obligation (De

Asset Retirement Obligation (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Asset Retirement Obligation
Asset retirement obligation, beginning balance			$ 4,313	$ 3,958	$ 3,958
Accretion expense	$ 98	$ 89	287	$ 263	355
Asset retirement obligation, ending balance	4,600		4,600		4,313
Legally restricted assets	$ 0		$ 0		$ 0

Intangible Assets (Details)

Intangible Assets (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
Intangible Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 3,365	$ 3,363	$ 10,093	$ 10,093
Beginning balance			131,786	145,246	$ 145,246
Amortization			(10,093)	$ 10,100	(13,460)
Ending balance	$ 121,693		$ 121,693		$ 131,786
Customer Contracts
Finite-Lived Intangible Assets [Line Items]
Agreement term (in years)			15 years
Useful life			15 years

Investments (Details)

Investments (Details) $ in Thousands	1 Months Ended				3 Months Ended		9 Months Ended
Investments (Details) $ in Thousands	May 31, 2018aMMcf	Apr. 30, 2018MMcf	Nov. 30, 2016USD ($)	Jul. 31, 2016USD ($)	Sep. 30, 2021USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2021USD ($)	Sep. 30, 2020USD ($)
Schedule of Equity Method Investments [Line Items]
Earnings (losses) in equity investments					$ (1,734)	$ (441)	$ (1,406)	$ 2,254
Amortization of intangible assets					3,365	$ 3,363	10,093	10,093
Distributions received							11,946	$ 7,624
Carnero Gathering, Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)				50.00%
Payments to acquire interest in joint venture				$ 37,000			124,400
Assumption of capital commitments in joint venture				7,400
Daily processing capacity \| MMcf	400
Carnero Gathering, Joint Venture \| Customer Relationships
Schedule of Equity Method Investments [Line Items]
Intangible asset, fair value				$ 13,000
Agreement term (in years)				15 years
Carnero Processing, Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			50.00%
Payments to acquire interest in joint venture			$ 55,500
Assumption of capital commitments in joint venture			$ 24,500
Carnero G&P, Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)	50.00%
Payments to acquire interest in joint venture							124,400
Daily processing capacity \| MMcf	460	260
Earnings (losses) in equity investments							(500)
Distributions received							11,900
Carnero G&P, Joint Venture \| Customer Relationships
Schedule of Equity Method Investments [Line Items]
Amortization of intangible assets					$ 300		$ 900
Carnero Gathering and Carnero Processing [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)	50.00%
Mesquite Energy, Inc. \| Carnero Gathering, Joint Venture \| Western Eagle Ford [Member]
Schedule of Equity Method Investments [Line Items]
Acres dedicated for gathering \| a	315,000
Targa \| Carnero Gathering, Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)				50.00%
Targa \| Carnero Processing, Joint Venture
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)			50.00%
Targa \| SIlver Oak II [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest (as a percent)	100.00%

Investments (Unconsolidated Ent

Investments (Unconsolidated Entities) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Schedule of Equity Method Investments [Line Items]
Sales	$ 16,868	$ 10,670	$ 35,304	$ 35,400
Net income			(91,058)	(88,575)
Unconsolidated entities
Schedule of Equity Method Investments [Line Items]
Sales			78,026	55,578
Total expenses			74,662	44,965
Net income			$ 3,364	$ 10,613

Commitments And Contingencies (

Commitments And Contingencies (Details)	9 Months Ended
Commitments And Contingencies (Details)	Sep. 30, 2021USD ($)
Carnero Gathering, Joint Venture
Variable Interest Entity [Line Items]
Earnout derivative liability	$ 0
Mesquite Energy, Inc.
Variable Interest Entity [Line Items]
Earnout payments	$ 0

Unit-Based Compensation (Detail

Unit-Based Compensation (Details) - LTIP - $ / shares	1 Months Ended	9 Months Ended
Unit-Based Compensation (Details) - LTIP - $ / shares	Apr. 30, 2019	Sep. 30, 2021
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Units available for issuance		7,619,823
Restricted Stock Units (RSUs)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Restricted Units, Outstanding		683,171
Number of Restricted Units, Granted		1,651,785
Number of Restricted Units, Returned/Cancelled		(140,647)
Number of Restricted Units, Outstanding		2,194,309
Weighted Averaged Grant Date Fair Value Per Unit, Outstanding		$ 2.68
Weighted Averaged Grant Date Fair Value Per Unit, Granted		1.12
Weighted Averaged Grant Date Fair Value Per Unit, Returned/Cancelled		2.37
Weighted Averaged Grant Date Fair Value Per Unit, Outstanding		$ 1.53
Restricted Stock Units (RSUs) \| Directors
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Restricted Units, Granted	1,651,785

Partners' Capital (Details)

Partners' Capital (Details) - USD ($)	9 Months Ended
Partners' Capital (Details) - USD ($)	Sep. 30, 2021	Dec. 31, 2020
Limited Partners' Capital Account [Line Items]
Common units, outstanding	96,465,219	19,953,880
Units, issued	96,465,219	19,953,880
Proceeds from common units sold	$ 17,051,000
Class C preferred units
Limited Partners' Capital Account [Line Items]
Class B preferred units, outstanding	36,474,436
Class C preferred units \| Settlement Agreement with Stonepeak Catarina Holdings LLC
Limited Partners' Capital Account [Line Items]
Units to be issued under agreement	$ 14,611,540
Common Units
Limited Partners' Capital Account [Line Items]
Common units, outstanding	96,465,219
Unvested restricted common units \| LTIP
Limited Partners' Capital Account [Line Items]
Common units, outstanding	2,194,309

Partners' Capital (Preferred Un

Partners' Capital (Preferred Units) (Details) - USD ($) $ in Thousands	9 Months Ended		12 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Class C Preferred Units, beginning balance	$ 345,205	$ 281,688	$ 281,688
Accretion of discount	37,671		38,938
Distribution accrual			24,579
Class C Preferred Units, ending balance	$ 382,876		$ 345,205
Class C preferred units
Warrant exercise period	30 days
Class C preferred units \| Distribution period commencing with the quarter ended on September 30, 2019
Distributions (as a percent)		12.50%
Class C preferred units \| Distribution period commencing with the quarter ending March 31, 2022
Distributions (as a percent)	14.00%

Partners' Capital (Distribution

Partners' Capital (Distributions) (Details) - shares	Nov. 22, 2021	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Class C preferred units
Units distribution (in units)		1,105,286	1,071,793	1,039,314
Common Units
Units distribution (in units)		8,012,850	13,763,249	12,445,491	22,274,869
Common Units \| Forecast
Units distribution (in units)	10,832,186

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended	12 Months Ended
	Jul. 31, 2016	Sep. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Acquisitions, earnout and capital investments		$ 128,483	$ 128,251
Earnings in equity investments		29,049	30,455
Distributions received		(81,017)	(69,071)
Maximum exposure to loss		76,515	$ 89,635
Carnero Gathering, Joint Venture
Variable Interest Entity [Line Items]
Payments to acquire interest in joint venture	$ 37,000	124,400
Debt incurred		0
Maximum exposure to loss		$ 76,500

Subsequents Events (Details)

Subsequents Events (Details) gal in Millions, $ in Millions

Nov. 22, 2021shares

Nov. 13, 2021bblgal

Nov. 09, 2021shares

Oct. 29, 2021

Oct. 04, 2021USD ($)

Nov. 10, 2021shares

Jun. 30, 2020shares

Mar. 31, 2020shares

Dec. 31, 2019shares

Sep. 30, 2019shares

Nov. 05, 2021shares

Sep. 30, 2021shares

Common Units

Subsequent Event [Line Items]

Units distribution (in units)

8,012,850

13,763,249

12,445,491

22,274,869

LTIP

Subsequent Event [Line Items]

Units available for issuance

7,619,823

Forecast | Common Units

Subsequent Event [Line Items]

Units distribution (in units)

10,832,186

Subsequent event | Minimum

Subsequent Event [Line Items]

NYSE American Company Guide market capitalization requirement met | $

$ 50

Subsequent event | Common Units

Subsequent Event [Line Items]

LTIP units, percentage increase

15.00%

Subsequent event | New Executive Units

Subsequent Event [Line Items]

Common units issued

17,700,000

Subsequent event | Equity Inducement Award Plan | Common Units

Subsequent Event [Line Items]

Common units issued

14,100,000

Subsequent event | LTIP

Subsequent Event [Line Items]

LTIP units, percentage increase

15.00%

Number of common units excluded from warrant

1,624,828

Units available for issuance

2,655,000

1,624,828

Subsequent event | LTIP | Common Units

Subsequent Event [Line Items]

Common units issued

3,600,000

The "Framework Agreement" | Subsequent event

Subsequent Event [Line Items]

Expected development project barrels per day | bbl

9,000

Expected development project gallons per year | gal

120