Montauk Renewables (MNTK) 10-Q 2021 Q2 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM

10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2021

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                    to                    

Commission File Number:

001-39919

MONTAUK RENEWABLES, INC.

(Exact name of registrant as specified in its charter)

Delaware	85-3189583
(State or Other Jurisdiction of Incorporation or	(IRS Employer Identification No.)
Organization)
680 Andersen Drive, 5 th Floor Pittsburgh, Pennsylvania	15220
(Address of Principal Executive Offices)	(Zip Code)

(412)

747-8700

(Registrant’s Telephone Number, Including Area Code)

N/A

(Former name, former address and former fiscal year, if changed since last report)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.01 per share	MNTK	The Nasdaq Capital Market

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes    ☒  No    ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation

S-T

(§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  Yes    ☒  No    ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a

non-accelerated

filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule

12b-2

of the Exchange Act:

Large accelerated filer	☐	Accelerated filer	☐
Non-accelerated filer	☒	Smaller reporting company	☐
		Emerging growth company	☒

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule

12b-2

of the Exchange Act).  Yes    ☐  No    ☒

The number of outstanding shares of the registrant’s common stock on August 8, 2021 was 143,584,827 shares.

TABLE OF CONTENTS

		Page
PART I FINANCIAL INFORMATION			6
ITEM 1.	FINANCIAL STATEMENTS		6
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		26
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		44
ITEM 4.	CONTROLS AND PROCEDURES		44
PART II OTHER INFORMATION			45
ITEM 1.	LEGAL PROCEEDINGS		45
ITEM 1A.	RISK FACTORS		45
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS		45
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES		46
ITEM 4.	MINE SAFETY DISCLOSURES		46
ITEM 5.	OTHER INFORMATION		46
ITEM 6.	EXHIBITS		46
SIGNATURES			48

Glossary of Key Terms

This Quarterly Report on Form

10-Q

uses several terms of art that are specific to our industry and business. For the convenience of the reader, a glossary of such terms is provided here. Unless we otherwise indicate, or unless the context requires otherwise, any references in this Quarterly Report on Form

10-Q

to:

• “ ADG ” refers to anaerobic digested gas.

• “ CARB ” refers to the California Air Resource Board.

• “ CNG ” refers to compressed natural gas.

• “ CI ” refers to carbon intensity.

• “ CWCs ” refers to cellulosic waiver credits.

• “ D3 ” refers to cellulosic biofuel with a 60% GHG reduction requirement.

• “ D5 ” refers to advanced biofuels with a 50% GHG reduction requirement.

• “ EHS ” refers to environment, health and safety.

• “ EPA ” refers to the U.S. Environmental Protection Agency.

• “ Environmental Attributes ” refer to federal, state and local government incentives in the United States, provided in the form of RINs, RECs, LCFS credits, rebates, tax credits and other incentives to end users, distributors, system integrators and manufacturers of renewable energy projects, that promote the use of renewable energy.

• “ GHG ” refers to greenhouse gases.

• “ JSE ” refers to the Johannesburg Stock Exchange.

• “ LCFS ” refers to Low Carbon Fuel Standard.

• “ LFG ” refers to landfill gas.

• “ PPAs ” refers to power purchase agreements.

• “ RECs ” refers to Renewable Energy Credits.

• “ Renewable Electricity ” refers to electricity generated from renewable sources.

• “ RFS ” refers to the EPA’s Renewable Fuel Standard.

• “ RINs ” refers to Renewable Identification Numbers.

• “ RNG ” refers to renewable natural gas.

• “ RPS ” refers to Renewable Portfolio Standards.

• “ RVOs ” refers to renewable volume obligations.

• “ WRRFs ” refers to water resource recovery facilities.

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Cautionary Note Regarding Forward-Looking Statements

This Quarterly Report on Form

10-Q

contains “forward-looking statements” within the meaning of U.S. federal securities laws that involve substantial risks and uncertainties. All statements other than statements of historical or current fact included in this report are forward-looking statements. Forward-looking statements refer to our current expectations and projections relating to our financial condition, results of operations, plans, objectives, strategies, future performance, and business. You can identify forward-looking statements by the fact that they do not relate strictly to historical or current facts. These statements may include words such as “anticipate,” “assume,” “believe,” “can have,” “contemplate,” “continue,” “could,” “design,” “due,” “estimate,” “expect,” “forecast,” “goal,” “intend,” “likely,” “may,” “might,” “objective,” “plan,” “predict,” “project,” “potential,” “seek,” “should,” “target,” “will,” “would,” and other words and terms of similar meaning in connection with any discussion of the timing or nature of future operational performance or other events. For example, all statements we make relating to estimated and projected costs, expenditures, growth rates, and our plans and objectives for future operations, growth, initiatives, or strategies are forward-looking statements. All forward-looking statements are subject to risks and uncertainties that may cause actual results to differ materially from those that we expect and, therefore, you should not unduly rely on such statements. The risks and uncertainties that could cause those actual results to differ materially from those expressed or implied by these forward-looking statements include but are not limited to:

• the impact of the ongoing COVID-19 pandemic on our business, financial condition and results of operations;

• our ability to develop and operate new renewable energy projects, including livestock farms;

• reduction or elimination of government economic incentives to the renewable energy market;

• delays in acquisition, financing, construction and development of new projects, including expansion plans into new areas such as dairy;

• the length of development and optimization cycles for new projects, including the design and construction processes for our renewable energy projects;

• dependence on third parties for the manufacture of products and services;

• identifying suitable locations for new projects;

• reliance on interconnections to distribution and transmission products for our Renewable Natural Gas and Renewable Electricity Generation segments;

• our projects not producing expected levels of output;

• the anticipated benefits of the Pico feedstock amendment and the North Carolina acquisition;

• concentration of revenues from a small number of customers and projects;

• dependence on our landfill operators;

• our outstanding indebtedness and restrictions under our credit facility;

• our ability to extend our fuel supply agreements prior to expiration;

• our ability to meet milestone requirements under our PPAs;

• existing regulations and changes to regulations and policies that effect our operations;

• decline in public acceptance and support of renewable energy development and projects;

• our expectations regarding Environmental Attribute and commodity prices;

• our expectations regarding the period during which we qualify as an emerging growth company under the Jumpstart Our Business Startup Act (“JOBS Act”);

• our expectations regarding future capital expenditures, including for the maintenance of facilities;

• our expectations regarding the use of net operating losses before expiration;

• our expectations regarding more attractive CI scores by regulatory agencies for our livestock farm projects;

• market volatility and fluctuations in commodity prices and the market prices of Environmental Attributes;

• profitability of our planned livestock farm projects;

• sustained demand for renewable energy;

• security threats, including cyber-security attacks;

4

• the need to obtain and maintain regulatory permits, approvals and consents;

• potential liabilities from contamination and environmental conditions;

• potential exposure to costs and liabilities due to extensive environmental, health and safety laws;

• impacts of climate change, changing weather patterns and conditions, and natural disasters;

• failure of our information technology and data security systems;

• increased competition in our markets;

• continuing to keep up with technology innovations;

• an active trading market for our common stock may not develop;

• our belief that the measures taken to remediate the material weakness identified in our internal control over financial reporting will improve our internal control over financial reporting;

• concentrated stock ownership by a few stockholders and related control over the outcome of all matters subject to a stockholder vote; and

• other risks and uncertainties detailed in the section titled “Risk Factors” in our latest Annual Report on Form 10-K.

We make many of our forward-looking statements based on our operating budgets and forecasts, which are based upon detailed assumptions. While we believe that our assumptions are reasonable, we caution that it is very difficult to predict the impact of known factors, and it is impossible for us to anticipate all factors that could affect our actual results.

All forward-looking statements attributable to us are expressly qualified in their entirety by these cautionary statements as well as others made in our other Securities and Exchange Commission (“SEC”) filings and public communications. You should evaluate all forward-looking statements made by us in the context of these risks and uncertainties. See the “Risk Factors” section in our latest Annual Report on Form

10-K.

We caution you that the risks and uncertainties identified by us may not be all of the factors that are important to you. Furthermore, the forward-looking statements included in this report are made only as of the date hereof. We undertake no obligation to publicly update or revise any forward-looking statement as a result of new information, future events, or otherwise, except as required by law.

5

PART I FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

	Page
Montauk Renewables, Inc .
Unaudited Condensed Consolidated Financial Statements
Condensed Consolidated Balance Sheets		7
Condensed Consolidated Statements of Operations		8
Condensed Consolidated Statements of Stockholders’ and Members’ Equity		9
Condensed Consolidated Statements of Cash Flows		10
Notes to Unaudited Condensed Consolidated Financial Statements		11

6

MONTAUK RENEWABLES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(in thousands, except share data):

	As of June 30, 2021			As of December 31, 2020
ASSETS
Current assets:
Cash and cash equivalents	$	16,350		$	20,992
Accounts and other receivables, net		10,124			5,449
Prepaid expenses and other current assets		4,571			6,044
Total current assets	$	31,045		$	32,485
Restricted cash - non-current	$	573		$	567
Property, plant and equipment, net		184,226			187,046
Related party receivable		7,140			—
Goodwill and intangible assets, net		13,411			14,033
Deferred tax assets		10,560			14,822
Operating lease right-of-use assets		450			586
Other assets		4,243			3,817
Total assets	$	251,648		$	253,356
LIABILITIES AND STOCKHOLDERS’ AND MEMBERS’ EQUITY
Current liabilities:
Accounts payable	$	5,294		$	5,964
Accrued liabilities		12,683			11,539
Current portion of lease liability		292			282
Income taxes payable		265			—
Current portion of derivative instruments		957			1,185
Current portion of long-term debt		9,584			9,492
Total current liabilities	$	29,075		$	28,462
Long-term debt, less current portion	$	51,449		$	56,268
Non-current portion of lease liability		177			320
Non-current portion of derivative instruments		579			1,075
Asset retirement obligation		5,824			5,689
Other liabilities		1,920			1,920
Total liabilities	$	89,024		$	93,734
STOCKHOLDERS’ AND MEMBERS’ EQUITY
Members’ equity	$	—		$	159,622
Common stock, $0.01 par value, authorized 690,000,000 shares; 143,584,827 shares issued at June 30, 2021; 141,015,213 shares outstanding at June 30, 2021		1,410			—
Treasury stock, at cost, 950,214 shares at June 30, 2021		(10,813	)		—
Additional paid-in capital		190,944			—
Retained deficit		(18,917	)		—
Total stockholders’ and members’ equity	$	162,624		$	159,622
Total liabilities and stockholders’ and members’ equity	$	251,648		$	253,356

The accompanying notes to the unaudited condensed consolidated financial statements are an integral part of these statements.

7

MONTAUK RENEWABLES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(in thousands, except per share data):

	Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020
Total operating revenues	$	31,674		$	27,908		$	63,121		$	46,312
Operating expenses:
Operating and maintenance expenses	$	13,187		$	10,125		$	23,830		$	19,961
General and administrative expenses		7,341			3,765			27,761			7,204
Royalties, transportation, gathering and production fuel		5,986			5,248			12,204			8,189
Depreciation, depletion and amortization		5,660			5,302			11,396			10,650
Gain on insurance proceeds		—			(94	)		(82	)		(750	)
Impairment loss		—			—			626			278
Transaction costs		37			—			125			—
Total operating expenses	$	32,211		$	24,346		$	75,860		$	45,532
Operating income (loss)	$	(537	)	$	3,562		$	(12,739	)	$	780
Other expenses :
Interest expense	$	720		$	859		$	1,366		$	3,073
Other expense		10			60			45			34
Total other expenses	$	730		$	919		$	1,411		$	3,107
Income (loss) before income taxes	$	(1,267	)		2,643		$	(14,150	)	$	(2,327	)
Income tax expense (benefit)		3,385			4,226			4,767			(6,560	)
Net income (loss)	$	(4,652	)	$	(1,583	)	$	(18,917	)	$	4,233
Loss per share:
Basic	$	(0.03	)				$	(0.13	)
Diluted	$	(0.03	)				$	(0.13	)
Weighted-average common shares outstanding:
Basic		141,015,213						141,015,213
Diluted		141,015,213						141,015,213

The accompanying notes to the unaudited condensed consolidated financial statements are an integral part of these statements.

8

MONTAUK RENEWABLES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ AND MEMBERS’ EQUITY

(Unaudited)

(in thousands, except share data):

	Common Stock				Treasury Stock					Members’ Equity			Additional Paid-in Capital		Retained Earnings (Deficit)			Total Equity
	Shares		Amount		Shares		Amount
Balance at March 31, 2021		141,015,213	$	1,410		950,214	$	(10,813	)		—		$	188,403	$	(14,265	)	$	164,735
Net loss		—		—		—		—			—			—		(4,652	)		(4,652	)
Stock-based compensation		—		—		—		—			—			2,541		—			2,541
Balance at June 30, 2021		141,015,213	$	1,410		950,214	$	(10,813	)	$	—		$	190,944	$	(18,917	)	$	162,624
	Common Stock				Treasury Stock					Members’ Equity			Additional Paid-in Capital		Retained Earnings (Deficit)			Total Equity
	Shares		Amount		Shares		Amount
Balance at March 31, 2020		—	$	—		—	$	—		$	160,303		$	—	$	—		$	160,303
Net loss		—		—		—		—			(1,583	)		—		—			(1,583	)
Stock-based compensation		—		—		—		—			9			—		—			9
Balance at June 30, 2020		—		—		—		—		$	158,729			—		—		$	158,729
	Common Stock				Treasury Stock					Members’ Equity			Additional Paid-in Capital		Retained Earnings (Deficit)			Total Equity
	Shares		Amount		Shares		Amount
Balance at December 31, 2020		—	$	—		—	$	—			159,622			—		—		$	159,622
Effect of reorganization transactions		138,312,713		1,383		—		—			(159,622	)		158,239		—			—
IPO common stock		2,702,500		27		—		—			—			15,566		—			15,593
Treasury stock		—		—		950,214		(10,813	)		—			—		—			(10,813	)
Net loss		—		—		—		—			—			—		(18,917	)		(18,917	)
Stock-based compensation		—		—		—		—			—			17,139		—			17,139
Balance at June 30, 2021		141,015,213	$	1,410		950,214	$	(10,813	)	$	—		$	190,944	$	(18,917	)	$	162,624
	Common Stock				Treasury Stock					Members’ Equity			Additional Paid-in Capital		Retained Earnings (Deficit)			Total Equity
	Shares		Amount		Shares		Amount
Balance at December 31, 2019		—	$	—		—	$	—		$	154,257		$	—	$	—		$	154,257
Net income		—		—		—		—			4,233			—		—			4,233
Stock-based compensation		—		—		—		—			239			—		—			239
Balance at June 30, 2020		—		—		—		—			158,729			—		—		$	158,729

The accompanying notes to the unaudited condensed consolidated financial statements are an integral part of these statements.

9

MONTAUK RENEWABLES, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(in thousands):

	Six Months Ended June 30,
	2021			2020
Cash flows from operating activities:
Net income (loss)	$	(18,917	)	$	4,233
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization		11,396			10,650
Provision (benefit) for deferred income taxes		4,262			(6,614	)
Stock-based compensation		17,139			239
Related party receivables		—			164
Derivative mark-to-market adjustments and settlements		(724	)		1,774
Gain on property insurance proceeds		(82	)		(750	)
Net loss on sale of assets		22			—
Accretion of asset retirement obligations		215			169
Amortization of debt issuance costs		271			362
Impairment loss		626			278
Changes in operating assets and liabilities:
Accounts and other receivables and other current assets		(3,553	)		(2,285	)
Accounts payable and other accrued expenses		590			150
Net cash provided by operating activities	$	11,245		$	8,370
Cash flows from investing activities
Capital expenditures	$	(4,469	)	$	(10,454	)
Asset Acquisition		(4,142	)		—
Cash collateral deposits, net		0			13
Proceeds from sale of assets		8			—
Proceeds from insurance recovery		82			750
Net cash used in investing activities	$	(8,521	)	$	(9,691	)
Cash flows from financing activities:
Borrowings of long-term debt	$	—		$	8,500
Repayments of long-term debt		(5,000	)		(5,000	)
Proceeds from initial public offering		15,593			—
Treasury stock purchase		(10,813	)		—
Loan to Montauk Holdings Limited		(7,140	)		—
Net cash (used in) provided by financing activities	$	(7,360	)	$	3,500
Net (decrease) increase in cash and cash equivalents and restricted cash	$	(4,636	)	$	2,179
Cash and cash equivalents and restricted cash at beginning of period	$	21,559		$	10,362
Cash and cash equivalents and restricted cash at end of period	$	16,923		$	12,541
Reconciliation of cash, cash equivalents, and restricted cash at end of period:
Cash and cash equivalents	$	16,350		$	11,939
Restricted cash and cash equivalents - current		—			35
Restricted cash and cash equivalents - non-current		573			567
	$	16,923		$	12,541

The accompanying notes to the unaudited condensed consolidated financial statements are an integral part of these statements.

10

MONTAUK RENEWABLES, INC.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(dollars in thousands, except share amounts)

NOTE 1 – DESCRIPTION OF BUSINESS

Operations and organization

Montauk Renewables’ Business

Montauk Renewables, Inc. (the “Company” or “Montauk Renewables”) is a renewable energy company specializing in the management, recovery and conversion of biogas into Renewable Natural Gas (“RNG”). The Company captures methane, preventing it from being released into the atmosphere, and converts it into either RNG or electrical power for the electrical grid (“Renewable Electricity”). The Company, headquartered in Pittsburgh, Pennsylvania, has more than 30 years of experience in the development, operation and management of landfill methane-fueled renewable energy projects. The Company has current operations at 15 operating projects located in California, Idaho, Ohio, Oklahoma, Pennsylvania, North Carolina and Texas. The Company sells RNG and Renewable Electricity, taking advantage of Environmental Attribute premiums available under federal and state policies that incentivize their use.

One of the Company’s key revenue drivers is the selling of captured gas and the selling of Renewable Identification Numbers (“RINs”) to fuel blenders. The Renewable Fuel Standard (“RFS”) is an Environmental Protection Agency (“EPA”) administered federal law that requires transportation fuel to contain a minimum volume of renewable fuel. RNG derived from landfill methane, agricultural digesters and wastewater treatment facilities used as a vehicle fuel qualifies as a D3 (cellulosic biofuel with a 60% greenhouse gas reduction requirement) RIN. The RINs are compliance units for fuel blenders that were created by the RFS program in order to reduce greenhouse gases and imported petroleum into the United States.

An additional program utilized by the Company is the Low Carbon Fuel Standard (“LCFS”). This is state specific and is designed to stimulate the use of

low-carbon

fuels. To the extent that RNG from the Company’s facilities is used as a transportation fuel in states that have adopted an LCFS program, it is eligible to receive an Environmental Attribute additional to the RIN value under the federal RFS.

The second primary revenue driver is the selling of captured electricity and the associated environmental premiums related to renewable sales. The Company’s electric facilities are designed to conform to and monetize various state renewable portfolio standards requiring a percentage of the electricity produced in that state to come from a renewable resource. Such premiums are in the form of Renewable Energy Credits (“RECs”). All three of the Company’s electric facilities receive revenue for the monetization of RECs either as a part of a power sales agreement or separately.

Collectively, the Company benefits from federal, state and local government incentives in the United States, provided in the form of RINs, RECs, LCFS credits, rebates, tax credits and other incentives to end users, distributors, system integrators and manufacturers of renewable energy projects, that promote the use of renewable energy, as Environmental Attributes.

Background and Reorganization Transactions

On January 4, 2021, the Company, Montauk Holdings Limited (“MNK”) and Montauk Holdings USA, LLC (a direct wholly-owned subsidiary of MNK at the time, “Montauk USA”) entered into a series of transactions, including an equity exchange and a distribution collectively referred to as the “Reorganization Transactions,” that resulted in the Company owning all of the assets and entities (other than Montauk USA) previously owned by Montauk USA, and Montauk Renewables became a direct wholly-owned subsidiary of MNK. Prior to the Reorganization Transactions, MNK’s business and operations were conducted entirely through Montauk USA and its U.S. subsidiaries, and MNK held no substantial assets other than equity of Montauk USA. The Company had no significant operations or assets prior to January 4, 2021 when it engaged in the equity exchange with Montauk USA and MNK.

After completion of the Reorganization Transactions, (i) Montauk USA ceased to own any substantial assets and (ii) all entities through which MNK’s business and operations were conducted became owned, directly or indirectly, by the Company. MNK adopted a plan contemporaneously with the completion of the Reorganization Transactions that authorized the liquidation and dissolution of MNK.

On January 15, 2021, MNK sold the membership interest of Montauk USA to a third party. On January 26, 2021, MNK distributed all of the outstanding shares of the Company’s common stock as a pro rata dividend to the holders of MNK’s ordinary shares (the “Distribution”), subject to any tax withholding obligations under applicable South African law. Each ordinary share of MNK outstanding on January 21, 2021, the record date for the Distribution (the “Record Date”), entitled the holder thereof to receive one share of the Company’s common stock.

On January 26, 2021, the Company closed the initial public offering of its common stock on the Nasdaq Capital Market (the “IPO”) with the shares traded under the symbol “MNTK.” Montauk Renewables issued 2,702,500 shares at $8.50 per share and received gross proceeds of $22,971. The Company’s common stock was also secondarily listed on the Johannesburg Stock Exchange under the trading symbol “MKR.”

11

On January 26, 2021, the Company entered into a Loan Agreement and Secured Promissory Note (the “Initial Promissory Note”) with MNK. MNK is currently an affiliate of the Company and certain of the Company’s directors and executive officers are also directors and executive officers of MNK. Pursuant to the Initial Promissory Note, the Company advanced a cash loan of $5,000 to MNK for MNK to pay its dividends tax liability arising from the Reorganization Transactions under the South African Income Tax Act, 1962 (Act No. 58 of 1962), as amended (the “South African Income Tax Act”). On February 22, 2021, the Company and MNK entered into an Amended and Restated Promissory Note (the “Amended Promissory Note”) to increase the principal amount of the loan to a total of $7,140, in the aggregate, in accordance with the Company’s obligations set forth in the Transaction Implementation Agreement entered into by and among the Company, MNK and the other party thereto, dated November 6, 2020, and amended on January 14, 2021.

MNK was delisted from the JSE on January 26, 2021. MNK will be liquidated within 24 months of the Distribution.

COVID-19

In March 2020, the World Health Organization classified the outbreak of

COVID-19

as a pandemic and recommended containment and mitigation measures worldwide. The Company is considered an essential company under the U.S. Federal Cybersecurity and Infrastructure Security Agency guidance and various state and/or local jurisdictions in which it operates. In response to the

COVID-19

pandemic, the Infectious Disease and Response Plan was activated to lead the development and response to any infectious disease event.

While the Company has not experienced any material disruptions in its ability to continue business operations or experienced a material negative impact to its financial results due to

COVID-19

for the six months ended June 30,2021, certain aspects of the Company’s business, financial condition and results of operations were negatively impacted during the six months ended June 30, 2020. These disruptions included the delay of commissioning of development sites for up to five months resulting in delays to registrations and qualifications necessary for EPA pathways and delays in revenue streams from these facilities, contract cancellations, and a decrease in operational efficiency in maintenance and operations. State and local mitigation protocols contributed to reduced needs for transportation fuels, which lowered state-based environmental premiums. The Company also faced a reduction in RINs pricing due to the outbreak of

COVID-19.

The potential future impact of

COVID-19

cannot be predicted with certainty, because new information that may emerge concerning the severity and extent of future surges and strains, vaccine distribution and other actions to contain the virus or treat its impact, among other reasons. Future negative impacts could include, but are not limited to, contract cancellations, supply chain disruptions, registration delays with local, state and federal agencies, Environmental Attribute premiums uncertainty, and a demand decrease in transportation fuels.

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information and with the instructions of the SEC on Form

10-Q

and Rule

10-01

of Regulation

S-X.

Accordingly, they do not include all of the information and disclosures required by GAAP for complete financial statements. In the opinion of management, the unaudited condensed consolidated financial statements include all adjustments necessary, which are of a normal and recurring nature, for the fair presentation of the Company’s financial position and of the results of operations and cash flows for the periods presented. These financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2020 included in the Company’s Annual Report on Form

10-K

filed with the SEC on March 31, 2021 (the “2020 Annual Report”). The results of operations for the three and six months ended June 30, 2021 in this report are not necessarily indicative of the results that may be expected for any other interim period or for the full year. The balance sheet at December 31, 2020 has been derived from the audited financial statements as of that date. For further information, refer to our audited financial statements and notes thereto included for the year ended December 31, 2020 in the 2020 Annual Report.

The historical consolidated financial information included reflects the historical results of operations and financial position of Montauk USA. The consolidated financial statements of Montauk USA became the Company’s historical financial statements following the IPO. Certain historical financial information included relates to periods prior to the Reorganization Transactions.

Retrospective Presentation of Ownership Related to the Reorganization Transactions

As discussed in Note 1, as a result of the Reorganization Transactions, the Company acquired the assets and entities (excluding Montauk USA) which were previously owned by MNK. As part of the Reorganization Transactions, a 1:1 pro rata distribution of shares of the Company’s common stock was made to holders of MNK’s ordinary shares. The Reorganization Transactions resulted in a pro rata distribution whereby the ownership of the Company after the Reorganization Transactions was identical to the ownership of MNK prior to the Reorganization Transaction and was therefore akin to a common control transaction. All members’ equity in the financial statements and notes have been retrospectively adjusted to give effect to the Distribution, as if such pro rata distribution on a 1:1 basis occurred as of all

pre-IPO

periods presented, including periods presented on the Condensed Consolidated Balance Sheets (Unaudited), Condensed Consolidated Statements of Operations (Unaudited), Condensed Consolidated Statements of Stockholders’ and Members’ Equity (Unaudited) and notes to the Unaudited Condensed Consolidated Financial Statements contained herein.

12

Use of Estimates

The preparation of financial statements, in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Equity-Based Compensation

The Company accounts for equity-based compensation under the provisions of ASC 718,

Compensation – Stock Compensation

, (“

ASC 718

”). ASC 718 requires compensation costs related to share-based payment transactions, measured based on the fair value of the instruments issued, be recognized in the consolidated financial statements over the requisite service period of the award. Stock options are initially measured on the grant date using the Black-Scholes valuation model, which requires the use of subjective assumptions related to the expected stock price volatility, term, risk-free interest rate and dividend yield. For restricted stock and restricted stock units, the Company determines the grant date fair value based on the closing market price of the stock on the date of grant.

Recently Issued Accounting Standards

In June 2016, the FASB issued ASU

No. 2016-13,

Financial Instruments –

Credit Losses

. The new guidance changes how entities measure credit losses on financial instruments and the timing of when such losses are recorded. The new standard is effective for fiscal years beginning after December 15, 2022, with early adoption permitted. The Company is currently evaluating the impact this ASU will have on its consolidated financial statements and related disclosures.

In August 2020, the FASB issued ASU

2020-06,

Debt: Debt with Conversion and Other Options (Subtopic

470-20)

and Derivatives and Hedging

– Contracts in Entity’s Own Equity (Subtopic

815-40)

, which simplifies the accounting for convertible instruments and contracts in an entity’s ownequity. This guidance is effective for annual reporting periods beginning after December 15, 2021, including interim periods within those years, with early adoption permitted only as of annual reporting periods beginning after December 15, 2020. The Company currently does not anticipate this ASU will have a material impact on its consolidated financial statements or related financial statement disclosures.

In March 2020, the FASB issued ASU

No. 2020-04,

Reference Rate Reform (Topic 848)

, which provides optional expedients and exceptions to the current guidance on contract modifications and hedging relationships to ease the financial reporting burdens of the expected market transition from London Interbank Offered Rate (“LIBOR”) and other interbank offered rates to alternative reference rates. The guidance was effective upon issuance and may be applied prospectively to contract modifications made and hedging relationships entered into or evaluated on or before December 31, 2022. The Company does not currently anticipate this ASU to have a material effect on its agreements and is working with the administrative agent, Comerica Bank, during the LIBOR transition.

NOTE 3 – ASSET IMPAIRMENT

The Company recorded 0 impairment losses for the three months ended June 30, 2021 and 2020. Impairment losses of $626 and $278 were recorded for the six months ended June 30, 2021 and 2020, respectively. The 2021 impairment loss was due to a notice received from a landfill host in February 2021 amending the underlying gas rights agreement to remove and begin decommissioning activities related to one of the Company’s renewable electric generation sites. The 2020 impairment loss was due to a termination of a development agreement. The Company evaluated and concluded that no other events or conditions existed during the period that suggested long-lived assets may not be recoverable.

NOTE 4 – REVENUES FROM CONTRACTS WITH CUSTOMERS

The following tables display the Company’s revenue by major source, excluding realized and unrealized gains or losses under the Company’s gas hedge program, based on product type and timing of transfer of goods and services for the three and six months ended June 30, 2021 and 2020:

	Three Months Ended June 30, 2021
	Goods transferred at a point in time		Goods transferred over time		Total
Major Goods/Service Line:
Natural Gas Commodity	$	6,332	$	6,627	$	12,959
Natural Gas Environmental Attributes		14,622		—		14,622
Electric Commodity		—		2,299		2,299
Electric Environmental Attributes		1,794		—		1,794
	$	22,748	$	8,926	$	31,674
Operating Segment:
RNG	$	20,954	$	6,627	$	27,581
REG		1,794		2,299		4,093
	$	22,748	$	8,926	$	31,674

13

	Three Months Ended June 30, 2020
	Goods transferred at a point in time		Goods transferred over time		Total
Major Goods/Service Line:
Natural Gas Commodity	$	1,613	$	5,762	$	7,375
Natural Gas Environmental Attributes		16,004		—		16,004
Electric Commodity		—		2,790		2,790
Electric Environmental Attributes		1,739		—		1,739
	$	19,356	$	8,552	$	27,908
Operating Segment:
RNG	$	17,617	$	5,762	$	23,379
REG		1,739		2,790		4,529
	$	19,356	$	8,552	$	27,908

	Six Months Ended June 30, 2021
	Goods transferred at a point in time		Goods transferred over time		Total
Major Goods/Service Line:
Natural Gas Commodity	$	10,308	$	13,322	$	23,630
Natural Gas Environmental Attributes		32,074		—		32,074
Electric Commodity		—		4,572		4,572
Electric Environmental Attributes		2,845		—		2,845
	$	45,227	$	17,894	$	63,121
Operating Segment:
RNG	$	42,382	$	13,322	$	55,704
REG		2,845		4,572		7,417
	$	45,227	$	17,894	$	63,121

	Six Months Ended June 30, 2020
	Goods transferred at a point in time		Goods transferred over time		Total
Major Goods/Service Line:
Natural Gas Commodity	$	3,089	$	11,006	$	14,095
Natural Gas Environmental Attributes		23,028		—		23,028
Electric Commodity		—		5,544		5,544
Electric Environmental Attributes		3,483		—		3,483
	$	29,600	$	16,550	$	46,150
Operating Segment:
RNG	$	26,117	$	11,006	$	37,123
REG		3,483		5,544		9,027
	$	29,600	$	16,550	$	46,150

14

NOTE 5 – ACCOUNTS AND OTHER RECEIVABLES

The Company extends credit based upon an evaluation of the customer’s financial condition and, while collateral is not required, the Company periodically receives surety bonds that guarantee payment. Credit terms are consistent with industry standards and practices. Reserves for uncollectible accounts, if any, are recorded as part of general and administrative expenses in the Consolidated Statements of Operations (Unaudited). For the three and six months ended June 30, 2021 and 2020, there were no reserves for uncollectible accounts.

Accounts and other receivables consist of the following as of June 30, 2021 and December 31, 2020:

	June 30, 2021		December, 31 2020
Accounts receivables	$	9,501	$	5,264
Other receivables		595		164
Reimbursable expenses		28		21
Accounts and other receivables, net	$	10,124	$	5,449

NOTE 6 – PREPAID EXPENSES AND OTHER CURRENT ASSETS

Included within Prepaid expenses and other current assets are RINs with a carrying value of $875, which the Company purchased at market price during the second quarter of 2021. The Company assessed these RINs and determined that market conditions indicated that the recorded cost exceeded the market value and recorded and adjustment of $710 to reduce the RINs to net realizable value. This adjustment is included

 in

Operating and maintenance expenses within the Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2021. There were 0 such adjustments during the three or six months ended June 30, 2020 and the Company did not have any purchased RINs as of December 31, 2020.

NOTE 7 – PROPERTY, PLANT AND EQUIPMENT, NET

Property, plant and equipment consists of the following as of June 30, 2021 and December 31, 2020:

	June 30, 2021			December, 31 2020
Buildings and improvements	$	28,251		$	28,065
Machinery and equipment		246,745			246,874
Gas mineral rights		34,551			34,551
Construction work in progress		11,084			4,485
Total		320,631			313,975
Less: Accumulated depreciation and amortization		(136,405	)		(126,929	)
Property, plant & equipment, net	$	184,226		$	187,046

Depreciation expense for property plant and equipment was $4,843 and $4,476 for the three months ended June 30, 2021 and 2020, respectively, and $9,797 and $8,960 for the six months ended June 30, 2021 and 2020, respectively. Amortization expense for gas mineral rights was $445 and $491 for the three months ended June 30, 2021 and 2020, respectively, and $936 and $981 for the six months ended June 30, 2021 and 2020, respectively.

In May 2021, the Company completed a series of transactions (the “Asset Acquisition”) with a privately-held entity. The Company paid $4,142, including $341 in acquisition costs, for land, building, mobile equipment and other property, plant and equipment. The Asset Acquisition was accounted for as an asset purchase in accordance with ASC 805,

Business Combinations

, and the purchase price and direct transaction costs have been allocated to the individual assets obtained and are classified as construction work in progress as of June 30, 2021.

15

NOTE 8 – GOODWILL AND INTANGIBLE ASSETS, NET

Intangible assets consist of the following as of June 30, 2021 and December 31, 2020:

	June 30, 2021		December 31, 2020
Goodwill	$	60	$	60
Intangible assets with indefinite lives:
Emissions allowances	$	777	$	777
Land use rights		329		329
Total intangible assets with indefinite lives:	$	1,106	$	1,106
Intangible assets with finite lives:
Interconnection, net of accumulated amortization of $2,636 and $2,329	$	11,684	$	11,951
Customer contracts, net of accumulated amortization of $16,722 and $16,367		561		916
Total intangible assets with finite lives:	$	12,245	$	12,867
Total Goodwill and Intangible Assets	$	13,411	$	14,033

The weighted average remaining useful life of the customer contracts and interconnection is approximately 6 years and 17 years, respectively. Amortization expense was $372 and $336 for the three months ended June 30, 2021 and 2020, respectively, and $662 and $709 for the six months ended June 30, 2021 and 2020, respectively

.

NOTE

9

 – ASSET RETIREMENT OBLIGATIONS

The following table summarizes the activity associated with asset retirement obligations of the Company as of June 30, 2021 and December 31, 2020:

	Six Months Ended June 30, 2021			Year Ended December 31, 2020
Asset retirement obligations - beginning of period	$	5,689		$	5,928
Accretion expense		215			320
New asset retirement obligations		0			350
Decommissioning		(80	)		(909	)
Asset retirement obligations - end of period	$	5,824		$	5,689

1

6

NOTE

10

 – DERIVATIVE INSTRUMENTS

To mitigate market risk associated with fluctuations in energy commodity prices (natural gas) and interest rates, the Company utilizes various hedges to secure energy commodity pricing and interest rates under a board-approved program. As a result of the hedging strategy employed, the Company had the following realized and unrealized gains and losses in the Condensed Consolidated Statements of Operations (Unaudited) for the three and six months ended June 30, 2021 and 2020:

			Three Months Ended
Derivative Instrument	Location		June 30, 2021		June 30, 2020
Commodity contracts:
Realized natural gas		Gas commodity sales	$	0	$	0
Unrealized natural gas		Other income		0		0
Interest rate swaps		Interest expense		306		26
Net gain (loss)			$	306	$	26

			Six Months Ended
Derivative Instrument	Location		June 30, 2021		June 30, 2020
Commodity contracts:
Realized natural gas		Gas commodity sales	$	0	$	551
Unrealized natural gas		Other income		0		(388	)
Interest rate swaps		Interest expense		724		(1,386	)
Net gain (loss)			$	724	$	(1,223	)

NOTE 1

1

 – FAIR VALUE OF FINANCIAL INSTRUMENTS

The Company’s assets and liabilities that are measured at fair value on a recurring basis include the following as of June 30, 2021 and December 31, 2020, set forth by level, within the fair value hierarchy:

	June 30, 2021
	Level 1		Level 2			Level 3			Total
Interest rate swap derivative liabilities	$	0	$	(1,536	)	$	0		$	(1,536	)
Asset retirement obligations		0		0			(5,824	)		(5,824	)
Pico earn-out liability		0		0			(1,920	)		(1,920	)
	$	0	$	(1,536	)	$	(7,744	)	$	(9,280	)
	December 31, 2020
	Level 1		Level 2			Level 3			Total
Interest rate swap derivative liabilities	$	0	$	(2,260	)	$	0		$	(2,260	)
Asset retirement obligations		0		0			(5,689	)		(5,689	)
Pico earn-out liability		0		0			(1,920	)		(1,920	)
	$	0	$	(2,260	)	$	(7,609	)	$	(9,869	)

A summary of changes in the fair values of the Company’s Level 3 instruments, attributable to asset retirement obligations is included in Note

9

. In addition, certain assets are measured at fair value on a

non-recurring

basis when an indicator of impairment is identified and the assets’ fair value is determined to be less than its carrying value. See Note 3 for additional information.

NOTE 1

2

 – ACCRUED LIABILITIES

The Company’s accrued liabilities consist of the following as of June 30, 2021 and December 31, 2020:

	June 30, 2021		December 31, 2020
Accrued expenses	$	5,401	$	4,975
Payroll and related benefits		1,864		2,341
Royalty		3,485		2,620
Utility		1,149		1,147
Other		784		456
Accrued Liabilities	$	12,683	$	11,539

1

7

NOTE 1

3

 – DEBT

The Company’s debt consists of the following as of June 30, 2021 and December 31, 2020:

	June 30, 2021			December 31, 2020
Term loan	$	25,000		$	30,000
Revolving credit facility		36,697			36,697
Less: current principal maturities		(10,000	)		(10,000	)
Less: debt issuance costs (on long-term debt)		(248	)		(429	)
Long-term debt		51,449			56,268
Current portion of long-term debt		9,584			9,492
	$	61,033		$	65,760

Amended Credit Agreement

On December 12, 2018, Montauk Energy Holdings LLC (“MEH”) entered into the Second Amended and Restated Revolving Credit and Term Loan Agreement (as amended, “Credit Agreement”), by and among MEH, the financial institutions from time to time party thereto as lenders and Comerica Bank, as the administrative agent, sole lead arranger and sole bookrunner (“Comerica”). The Credit Agreement (i) amended and restated in its entirety MEH’s prior revolving credit and term loan facility, dated as of August 4, 2017, as amended, with Comerica and certain other financial institutions and (ii) replaced in its entirety the prior credit agreement, dated as of August 4, 2017, as amended, between Comerica and Bowerman Power LFG, LLC, a wholly-owned subsidiary of MEH.

On March 21, 2019, MEH entered into the first amendment to the Credit Agreement (the “First Amendment”), which clarified a variety of terms, definitions and calculations in the Credit Agreement. The Credit Agreement requires the Company to maintain customary affirmative and negative covenants, including certain financial covenants, which are measured at the end of each fiscal quarter.

On September 12, 2019, MEH entered into the second amendment to the Credit Agreement (the “Second Amendment”). Among other matters, the Second Amendment redefined the Fixed Charge Coverage Ratio (as defined in the Credit Agreement), reduced the commitments under the revolving credit facility to $80,000, redefined the Total Leverage Ratio (as defined in the Credit Agreement) and eliminated the RIN Floor (as defined in the Second Amendment) as an Event of Default. In connection with the Second Amendment, MEH paid down the outstanding term loan by $38,250 and the resulting quarterly principal installments were reduced to $2,500. The maturity date of the Credit Agreement was not changed by the Second Amendment and remains December 12, 2023.

In connection with the completion of the Reorganization Transactions and the IPO, the Company entered into the third amendment to the Credit Agreement (the “Third Amendment”). This amendment permitted the Change of Control provisions, as defined in the underlying agreement, to permit the Reorganization Transactions and IPO to be completed. The amendment also added LIBOR cessation fallback language for a transition to specified alternative SOFR-based rates, or, if those alternatives cannot be determined, to another rate selected by the administrative agent and the borrower under the Amended Credit Agreement as well as provisions that allow one or more parties to transition in advance of the dates set forth above where specified conditions are met.

The Credit Agreement is secured by a lien on substantially all assets of the Company and certain of its subsidiaries and provides for a $95,000 term loan and a $80,000 revolving credit facility. The term loan amortizes in quarterly installments of $2,500 and has a final maturity of December 12, 2023 with interest rates of 2.870% and 2.961% at June 30, 2021 and December 31, 2020, respectively.

As of June 30, 2021, $25,000 was outstanding under the term loan and $36,697 was outstanding under the revolving credit facility. In addition, the Company had $5,765 of outstanding letters of credit as of June 30, 2021. Amounts available under the revolving credit facility are reduced by any amounts outstanding under letters of credit. As of June 30, 2021, the Company’s capacity available for borrowing under the revolving credit facility was $37,537. Borrowings of the term loan and revolving credit facility bear interest at the LIBOR rate plus an applicable margin or the Prime Reference Rate plus an applicable margin, as elected by the Company.

The Company accounted for the Third Amendment as a debt modification in accordance with ASC 470,

Debt

. In connection with the Credit Agreement, the Company paid a total of $1,821 in new debt issuance costs comprised of $836 in costs paid to the lenders and $985 in costs paid as arranger fees. Of this amount, $364 was expensed and $1,457 was capitalized and will be amortized over the life of the Credit Agreement. The Company also incurred $59 in legal fees associated with the Credit Agreement. Amortized debt issuance expense was $133 and $176 for the three months ended June 30, 2021 and 2020, respectively, and $271 and $362 for the six months ended June 30, 2021 and 2020, respectively, and was recorded within interest expense on the condensed consolidated statement of operations.

As of June 30, 2021, the Company was in compliance with all applicable financial covenants under the Credit Agreement as amended.

Capitalized Interest

Capitalized interest was $0 and $372 for the three months ended June 30, 2021 and 2020, respectively, and $0 and $734 for the six months ended June 30, 2021 and 2020, respectively. Interest is capitalized using the borrowing rate for the assets being constructed. Interest capitalized during 2020 was for the construction of two

LFG-to-energy

projects.

1

8

NOTE 1

4

 – INCOME TAXES

The Company’s provision for income taxes in interim periods is typically computed by applying the estimated annual effective tax rates to income or loss before income taxes for the period. In addition,

non-recurring

or discrete items are recorded during the period(s) in which they occur. In the first quarter of 2021, the Company calculated an unusually high estimated annual effective tax rate such that a reliable estimate of the annual effective tax rate could not be made. As such, the Company utilized the actual effective tax rate for the year to date ended March 31, 2021 as the Company’s best estimate for the first quarter of 2021. For the six months ended June 30, 2021, the Company calculated a more reliable estimated annual effective tax rate and thus applied the estimated annual effective tax rates to income or loss before income taxes for the period and recorded any discrete items in the period.

	Three Months Ended
	June 30, 2021			June 30, 2020
Provision for income taxes	$	3,385		$	4,226
Effective tax rate		(267	%)		160	%
	Six Months Ended
	June 30, 2021			June 30, 2020
Provision (benefit) for income taxes	$	4,767		$	(6,560	)
Effective tax rate		(34	%)		282	%

Income tax expense for the three and six months ended June 30, 2021 was calculated using the estimated annual effective tax rate. The effective tax rate differs from the U.S. federal statutory rate of 21% primarily due to the current year permanent disallowance of officers’ compensation under Section 162(m) of the Internal Revenue Code of 1986, as amended (the “Code”) of $4,407, partially offset by the favorable impact of the production tax credit of ($2,219). When the net tax expense for the three and six months ended June 30, 2021 is compared to the

pre-tax

book loss for the respective periods, it results in a negative effective tax rate.

The effective tax rate of (267%) for the three months ended June 30, 2021 was lower than the rate for the three months ended June 30, 2020 of 160% primarily due to the current year disallowance of officers’ compensation under Section 162(m) of the Code. The Company utilized an annual effective tax rate for tax expense calculated for the three months ended June 30, 2021 (compared to a year to date approach at March 31, 2021), which when applied to year to date

pre-tax

book loss and layering in nominal discrete events, resulted in a (

267

%) effective tax rate for the three months ended June 30, 2021. The 160% effective tax rate for the three months ended June 30, 2020 was a result of the second quarter

pre-tax

book income applied to the estimated annual effective tax rate, with no significant discrete events in that quarter.

The effective tax rate of (34%) for the six months ended June 30, 2021 was lower than the rate for the six months ended June 30, 2020 of 282%

primarily due to the income tax benefit that increased the 2020 effective tax rate in connection with the January 1, 2020 dissolution of the Montauk Energy Capital (“MEC”) partnership, which allows all entities under MEC to file as part of the Company’s consolidated federal tax group.

NOTE 1

5

 – SHARE-BASED COMPENSATION

In January 2021, Montauk Renewables undertook the Reorganization Transactions which resulted in the Company owning all of the assets and entities (excluding Montauk USA) through which MNK’s business and operations were conducted. As a result of the Distribution, the options outstanding under MNK’s Employee Share Appreciation Rights Scheme (the “SAR Plan”) were cancelled. The Company recorded $2,050 of accelerated compensation expense in its condensed consolidated statements of operations (unaudited) within general and administrative expenses in connection with the cancellation of the options under the SAR Plan for the six months ended June 30, 2021.

The board of directors of Montauk Renewables adopted the Montauk Renewables, Inc. Equity and Incentive Compensation Plan (“MRI EICP”) in January 2021. Following the closing of the IPO, the board of directors of Montauk Renewables approved the grant of

non-qualified

stock options, restricted stock unit and restricted stock awards to the employees of Montauk Renewables and its subsidiaries in January 2021. In connection with the restricted stock grants the officers of the Company made elections under Section 83(b) of the Code . Pursuant to such elections, the Company withheld 950,214 shares of common stock from such awards at a price of $11.38 per share from such awards. The Company records and reports share-based compensation for stock options, restricted stock, and restricted stock units when vested, in the case of restricted stock and restricted stock units, and when exercised, in the case of options, and such awards are settled in shares of common stock of Montauk Renewables. As of June 30, 2021, unrecognized MRI EICP compensation expense for awards the Company expects to vest approximated $14,005 and will be recognized over approximately 5 years. Stock based compensation expense was $2,541 and $10 for three months ended June 30, 2021 and 2020, respectively and $4,195 and $240 for the six months ended June 30, 2021 and June 30, 2020, respectively. The Company recognizes stock based compensation in its condensed consolidated statements of operations within general and administrative expenses.

1

9

The restricted stock, restricted stock unit and option awards are subject to vesting schedules that commence or conclude, in the case of the option and restricted stock unit awards, on the

one-year

anniversary of the grant date and are subject to the terms and conditions of the MRI EICP and related award agreements including, in the case of the restricted stock awards, each officer having made an election under Section 83(b) of the Code. The Company recorded $10,813 of compensation expense in its condensed consolidated statements of operations (unaudited) within general and administrative expenses for the six months ended June 30, 2021 in connection with the withheld 950,214 shares associated with the Section 83(b) elections.

Options granted under the MRI EICP allow the recipient to receive the Company’s common stock equal to the appreciation in the fair market value of the Company’s common stock between the grant date and the exercise and settlement of options into shares as of the exercise date(s). The fair value of the MRI EICP options was estimated using the Black-Scholes option pricing model with the following weighted-average assumptions (no dividends were expected):

	Grant Date
Risk-free interest rate		0.5	%
Expected volatility		32.0	%
Expected option life (in years)		5.5
Grant-date fair value	$	3.44

The risk-free interest rate was based on United States Treasury yields in effect at the time of the grant for notes with terms comparable to the awards. The expected option life represents an estimate of the period of time options are expected to remain outstanding based on the

mid-point

of the exercisable period to account for the possibility of early exercise or maturity. As the Company recently completed its IPO in January 2021, there is no sufficient stock volatility historical data. The expected volatility was based on the average historical stock price volatility of comparable publicly-traded companies in its industry peer group.

The following table summarizes the options, restricted stock and restricted stock units outstanding under the MRI EICP as of June 30, 2021:

	Restricted Shares					Restricted Stock Units					Options
	Number of Shares			Weighted Average Grant Date Fair Value		Number of Shares			Weighted Average Grant Date Fair Value		Number of Shares		Weighted Average Exercise Price
End of period - December 31, 2020		—		$	—		—		$	—		—	$	—
Beginning of period - January 1, 2021		0		$	0		0		$	0		0	$	0
Granted		2,269,827			11.20		29,304			11.38		950,214		11.38
Vested		(950,214	)		11.38		—			—		0		0
Forfeited		—			—		(1,056	)		11.38		0		0
Exercised		—			—		—			—		—		—
End of period – June 30, 2021		1,319,613		$	11.07		28,248		$	11.38		950,214	$	11.38

The following table summarizes the options and restricted stock under the SAR Plan as of June 30, 2020:

	Options					Restricted Stock
	Number of Shares			Weighted Average Exercise Price		Number of Shares		Weighted Average Grant Date Fair Value
End of period - December 31, 2019		1,872,534		$	1.18		1,939,200	$	0.95
Beginning of period - January 1, 2020		1,872,534		$	1.18		1,939,200	$	0.95
Granted		—			—		—		—
Forfeited		(166,666	)		1.28		—		—
Exercised		(50,000	)		0.44		0		0
End of period – June 30, 2020		1,655,868		$	1.19		1,939,200	$	0.95

NOTE 1

6

 – DEFINED CONTRIBUTION PLAN

The Company maintains a 401(k) defined contribution plan for eligible employees. The Company matches 50% of an employee’s deferrals up to 4%. The Company also contributes 3% of eligible employee’s compensation expense as a safe harbor contribution. The matching contributions vest ratably over four years of service, while the safe harbor contributions vest immediately. Incurred expense related to the 401(k) plan was $134 and $114 for the three months ended June 30, 2021 and 2020, respectively, and $269 and $221 for the six months ended June 30, 2021 and 2020, respectively.

20

NOTE 1

7

 – SEGMENT INFORMATION

The Company’s reportable segments for the three and six months ended June 30, 2021 and 2020 are Renewable Natural Gas and Renewable Electricity Generation. Renewable Natural Gas includes the production of RNG. Renewable Electricity Generation includes generation of electricity at

biogas-to-electricity

plants. The corporate entity is not determined to be an operating segment but is discretely disclosed for purposes of reconciliation of the Company’s unaudited condensed consolidated financial statements. The following tables are consistent with the manner in which the chief operating decision maker evaluates the performance of each segment and allocates the Company’s resources. In the following tables “RNG” refers to Renewable Natural Gas and “REG” refer to Renewable Electricity Generation.

	Three Months Ended June 30, 2021
	RNG		REG			Corporate			Total
Total Revenue	$	27,581	$	4,093		$	—		$	31,674
Net income (loss)		7,573		(27	)		(12,198	)		(4,652	)
EBITDA		11,854		1,307			(8,048	)		5,113
Adjusted EBITDA (1)		11,854		1,307			(8,011	)		5,150
Total Assets		156,505		53,369			41,774			251,648
Capital expenditure		2,708		425			—			3,133

(1) Second quarter of 2021 EBITDA Reconciliation

The following table is a reconciliation of the Company’s reportable segments’ net income (loss) from continuing operations to Adjusted EBITDA for the three months ended June 30, 2021:

	Three Months Ended June 30, 2021
	RNG		REG			Corporate			Total
Net income (loss)	$	7,573	$	(27	)	$	(12,198	)	$	(4,652	)
Depreciation and amortization		4,281		1,334			45			5,660
Interest expense		—		—			720			720
Income tax expense (benefit)		—		—			3,385			3,385
EBITDA	$	11,854	$	1,307		$	(8,048	)	$	5,113
Impairment loss		—		—			—			—
Transaction costs		—		—			37			37
Adjusted EBITDA	$	11,854	$	1,307		$	(8,011	)	$	5,150
	Three Months Ended June 30, 2020
	RNG		REG			Corporate			Total
Total Revenue	$	23,378	$	4,530		$	—		$	27,908
Net Income (Loss)		8,086		(775	)		(8,894	)		(1,583	)
EBITDA		11,535		1,034			(3,765	)		8,804
Adjusted EBITDA (1)		11,535		1,034			(3,765	)		8,804
Total Assets		135,921		80,912			37,136			253,969
Capital expenditure		4,223		990			37			5,250

(1) Second quarter of 2020 EBITDA Reconciliation

The following table is a reconciliation of the Company’s reportable segments’ net income (loss) from continuing operations to Adjusted EBITDA for the three months ended June 30, 2020:

	Three Months Ended June 30, 2020
	RNG		REG			Corporate			Total
Net Income (loss)	$	8,086	$	(775	)	$	(8,894	)	$	(1,583	)
Depreciation and amortization		3,449		1,809			44			5,302
Interest expense		—		—			859			859
Income tax expense (benefit)		—		—			4,226			4,226
EBITDA	$	11,535	$	1,034		$	(3,765	)	$	8,804
Impairment loss		—		—			—			—
Non-cash hedging charges		—		—			—			—
Adjusted EBITDA	$	11,535	$	1,034		$	(3,765	)	$	8,804

2

1

For the three months ended June 30, 2021 and 2020, six and four customers, respectively, made up greater than 10% of total revenues.

	Three Months Ended June 30, 2021
	RNG			REG			Corporate		Total
Customer A		17.5	%		—			—		17.5	%
Customer B		16.6	%		—			—		16.6	%
Customer C		13.0	%		—			—		13.0	%
Customer D		—			12.1	%		—		12.1	%
Customer E		11.9	%		—			—		11.9	%
Customer F		11.8	%		—			—		11.8	%

	Three Months Ended June 30, 2020
	RNG			REG			Corporate		Total
Customer A		25.0	%		—			—		25.0	%
Customer B		14.6	%		—			—		14.6	%
Customer C		13.6	%		—			—		13.6	%
Customer D					13.5	%				13.5	%

The Company’s reportable segments for the six months ended June 30, 2021 and 2020 are Renewable Natural Gas and Renewable Electricity Generation.

	Six Months Ended June 30, 2021
	RNG		REG			Corporate			Total
Total Revenue	$	55,704	$	7,417		$	—		$	63,121
Net Income (Loss)		18,134		(2,268	)		(34,783	)		(18,917	)
EBITDA		26,633		542			(28,563	)		(1,388	)
Adjusted EBITDA (2)		26,633		1,168			(28,438	)		(637	)
Total Assets		156,505		53,369			41,774			251,648
Capital Expenditure		4,020		449			—			4,469

(2) First six months of 2021 EBITDA Reconciliation

The following table is a reconciliation of the Company’s reportable segments’ net income (loss) from continuing operations to Adjusted EBITDA for the six months ended June 30, 2021:

	Six Months Ended June 30, 2021
	RNG		REG			Corporate			Total
Net Income (loss)	$	18,134	$	(2,268	)	$	(34,783)		$	(18,917	)
Depreciation and amortization		8,499		2,808			89			11,396
Interest expense		—		—			1,366			1,366
Income tax expense (benefit)		—		2			4,765			4,767
EBITDA	$	26,633	$	542		$	(28,563)		$	(1,388	)
Impairment loss		—		626			—			626
Transaction costs		—		—			125			125
Adjusted EBITDA	$	26,633	$	1,168		$	(28,438)		$	(637	)
	Six Months Ended June 30, 2020
	RNG		REG			Corporate			Total
Total Revenue	$	36,804	$	9,026		$	482		$	46,312
Net Income (Loss)		9,244		(1,294	)		(3,717	)		4,233
EBITDA		16,163		2,352			(7,119	)		11,396
Adjusted EBITDA (2)		16,163		2,630			(6,731	)		12,062
Total Assets		135,921		80,912			37,136			253,969
Capital Expenditure		8,328		2,050			76			10,454

(2) First six months of 2020 EBITDA Reconciliation

2

2

The following table is a reconciliation of the Company’s reportable segments’ net income (loss) from continuing operations to Adjusted EBITDA for the six months ended June 30, 2020:

	Six Months Ended June 30, 2020
	RNG		REG			Corporate			Total
Net Income (loss)	$	9,244	$	(1,294	)	$	(3,717	)	$	4,233
Depreciation and amortization		6,919		3,644			87			10,650
Interest expense		—		—			3,073			3,073
Income tax expense (benefit)		—		2			(6,562	)		(6,560	)
EBITDA	$	16,163	$	2,352		$	(7,119	)	$	11,396
Impairment loss		—		278			—			278
Non-cash hedging charges		—		—			388			388
Adjusted EBITDA	$	16,163	$	2,630		$	(6,731	)	$	12,062

For the six months ended June 30, 2021 and 2020, six and four customers, respectively, made up greater than 10% of total revenues.

	Six Months Ended June 30, 2021
	RNG			REG			Corporate		Total
Customer A		13.8	%		—			—		13.8	%
Customer B		13.1	%		—			—		13.1	%
Customer C		13.1	%		—			—		13.1	%
Customer D		11.5	%		—			—		11.5	%
Customer E		11.1	%		—			—		11.1	%
Customer F					11.0	%		—		11.0	%
	Six Months Ended June 30, 2020
	RNG			REG			Corporate		Total
Customer A		—			16.3	%		—		16.3	%
Customer B		15.6	%		—			—		15.6	%
Customer C		15.1	%		—			—		15.1	%
Customer D		11.4	%		—			—		11.4	%

2

3

NOTE 1

8

– LEASES

The Company leases office space and other office equipment under operating lease arrangements (with initial terms greater than twelve months), expiring in various years through 2024. These leases have been entered into to better enable the Company to conduct business operations. Office space is leased to provide adequate workspace for all employees in Pittsburgh, Pennsylvania and Houston, Texas.

The Company determines if an arrangement is, or contains, a lease at inception based on whether that contract conveys the right to control the use of an identified asset in exchange for consideration for a period of time. For all operating lease arrangements, the Company presents at the commencement date: a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and a

right-of-use

asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term.

The Company has elected, as a practical expedient, not to separate

non-lease

components from lease components, and instead account for each separate component as a single lease component for all lease arrangements, as lessee. In addition, the Company has elected, as a practical expedient, not to apply lease recognition requirements to short-term lease arrangements, generally those with a lease term of less than twelve months, for all classes of underlying assets. In determination of the lease term, the Company considers the likelihood of lease renewal options and lease termination provisions.

The Company uses its incremental borrowing rate as the basis to calculate the present value of future lease payments at lease commencement. The incremental borrowing rate approximates the rate to borrow funds on a collateralized basis over a similar term and in a similar economic environment.

As of June 30, 2021, there were no leases entered into which have not yet commenced and that would entitle the Company to significant rights or create additional obligations.

Supplemental information related to operating lease arrangements was as follows:

	Three Months Ended June 30,
	2021			2020
Cash paid for amounts included in the measurement of operating lease liabilities	$	64		$	75
Weighted average remaining lease term (in years)		1.70			2.20
Weighted average discount rate		5.00	%		5.00	%
	Six Months Ended June 30,
	2021			2020
Cash paid for amounts included in the measurement of operating lease liabilities	$	140		$	150
Weighted average remaining lease term (in years)		1.70			2.20
Weighted average discount rate		5.00	%		5.00	%

Future minimum lease payments as of June 30, 2021, are as follows:

	Amount
Year Ending
Remainder of 2021	$	152
2022		317
2023		8
2024		1
Interest		(9	)
Total	$	469

2

4

NOTE 1

9

– LOSS PER SHARE

Basic loss per share was computed using the following common share data for the three and six months ended June 30, 2021:

	Three Months Ended June 30, 2021
Net loss	$	(4,652	)
Basic weighted-average shares outstanding		141,015,213
Dilutive effect of share-based awards		0
Diluted weighted-average shares outstanding		141,015,213
Basic loss per share	$	(0.03	)
Diluted loss per share	$	(0.03	)
	Six Months Ended June 30, 2021
Net loss	$	(18,917	)
Basic weighted-average shares outstanding		141,015,213
Dilutive effect of share-based awards		0
Diluted weighted-average shares outstanding		141,015,213
Basic loss per share	$	(0.13	)
Diluted loss per share	$	(0.13	)

As a result of incurring a net loss for the three and six months ended June 30, 2021, potential common shares of 2,569,613 were excluded from diluted loss per share because the effect would have been antidilutive.

NOTE

20

– RELATED PARTY TRANSACTIONS

In connection with the Distribution, the Company loaned MNK $7,140, in the aggregate, which is recorded in the condensed consolidated balance sheet within related party receivable, for its dividends tax liability arising under the South African Income Tax Act, 1962, as amended. As security for this loan, MNK has pledged certain of its shares in the Company to Montauk Renewables and agreed to use the proceeds from the sale of such shares to repay this loan.

NOTE 2

1

– SUBSEQUENT EVENTS

The Company evaluated its June 30, 2021 unaudited condensed consolidated financial statements through August 16, 2021, the date the financial statements were issued. The Company is not aware of any subsequent events which would require disclosure in the unaudited condensed consolidated financial statements, except for the matters discussed below.

2

5

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our financial statements and the related notes to those statements included elsewhere in this Quarterly Report on Form

10-Q.

The historical consolidated financial data discussed below reflects the historical results of operations and financial position of Montauk USA. The consolidated financial statements of Montauk USA, our predecessor for accounting purposes, became our historical financial statements following the IPO. Certain historical financial data discussed below relates to periods prior to the Reorganization Transactions. Throughout this section, dollar amounts are expressed in thousands, except for per share amounts, Metric Million British Thermal Unit (“MMBtu”) and RIN pricing amounts, and unless otherwise indicated.

In addition to historical financial information, the following discussion and analysis contains forward-looking statements that involve risks, uncertainties, and assumptions. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of many factors, including those discussed under “Cautionary Note Regarding Forward-Looking Statements,” “Part II, Item 1A.–Risk Factors” and elsewhere in this report.

Overview

Montauk Renewables is a renewable energy company specializing in the management, recovery and conversion of biogas into RNG. The Company captures methane, preventing it from being released into the atmosphere, and converts it into either RNG or Renewable Electricity. The Company, headquartered in Pittsburgh, Pennsylvania, has more than 30 years of experience in the development, operation and management of landfill methane-fueled renewable energy projects. The Company has current operations at 15 operating projects located in California, Idaho, Ohio, Oklahoma, Pennsylvania, North Carolina and Texas. The Company sells RNG and Renewable Electricity, taking advantage of Environmental Attribute premiums available under federal and state policies that incentivize their use.

Biogas is produced by microbes as they break down organic matter in the absence of oxygen (during a process called anaerobic digestion). Our two current sources of commercial scale biogas are LFG and ADG, which is produced inside an airtight tank used to breakdown organic matter, such as livestock waste. We typically secure our biogas feedstock through long-term fuel supply agreements and property lease agreements with biogas site hosts. Once we secure long-term fuel supply rights, we design, build, own, and operate facilities that convert the biogas into RNG or use the processed biogas to produce Renewable Electricity. We sell the RNG and Renewable Electricity through a variety of short-, medium-, and long-term agreements. Because we are capturing waste methane and making use of a renewable source of energy, our RNG and Renewable Electricity generate valuable Environmental Attributes, which we are able to monetize under U.S. federal and state initiatives.

Factors Affecting Development Pipeline

On May 10, 2021, the Company, through a newly formed wholly-owned subsidiary, Montauk Ag Renewables, LLC (“Montauk Ag”), completed a series of transactions with Joseph P. Carroll, Jr. (“Carroll”), Martin A. Redeker (“Redeker”) and certain of their affiliates to purchase (the “Asset Acquisition”) their business (the “Business”) of developing technology to recover residual natural resources from waste streams of modern agriculture and to refine and recycle such waste products through proprietary and other processes in order to produce high quality renewable natural gas,

bio-oil

and biochar (“Montauk Ag Renewables”).

The Asset Acquisition was made pursuant to (i) the Membership Interest and Asset Purchase Agreement, dated May 10, 2021, by and among J.P. Carroll & Co., LLC, Eagle Creek Ranch, L.L.C., NR Nutrient Recovery, LLC, Mr. Carroll, Mr. Redeker and Montauk Ag and (ii) the Real Estate Purchase and Sale Agreement, dated May 10, 2021, by and among Greensboro Ecosystems, LLC and Montauk Ag (together, the “Acquisition Agreements”)

The assets acquired include real property, intellectual property, mobile equipment, and other equipment related to operating the Business. The real property includes the purchase of an approximate 9.35 acre parcel in Duplin County, North Carolina.

The purchase price, excluding acquisition costs, for the Business and related assets consisted of (i) $3,797 paid in cash on May 10, 2021 (minus certain costs and indebtedness) and (ii) two restricted stock awards, in equal amounts, granted under the Company’s Equity and Incentive Compensation Plan, with an aggregate value of $12,500, awarded to each of Messrs. Carroll and Redeker in connection with their respective employment with the Company following the closing of the Asset Acquisition (the “RS Awards”). The RS Awards vest over a five-year period and are subject to the achievement of time- and performance- based vesting criteria over such period. The performance targets in the RS Awards relate to three EBITDA goals of the Business (as determined in good faith by the Company) relative to the purchase price of the Business, including measurement periods for achievements levels (i) on or after the third anniversary of the Asset Acquisition, but prior to the sixth anniversary, (ii) on or after the fourth anniversary of the Asset Acquisition, but prior to the sixth anniversary, and (iii) on or after the fifth anniversary of the Asset Acquisition, but prior to the sixth anniversary.

Also, during the second quarter of 2021, we completed an amendment to our Pico feedstock agreement (“Pico Feedstock Amendment”). The amendment will increase the amount of feedstock supplied to the facility for processing over a one to three-year period. We paid $1,000 in cash at the time of closing the amendment.

26

Factors Affecting Revenue

Our total operating revenues include renewable energy and related sales of Environmental Attributes. Renewable energy sales primarily consist of the sale of biogas, including LFG and ADG, which is either sold or converted to Renewable Electricity. Environmental Attributes are generated and monetized from the renewable energy.

We report revenues from two operating segments: Renewable Natural Gas and Renewable Electricity Generation. Corporate relates to additional discrete financial information for the corporate function; primarily used as a shared service center for maintaining functions described below and not otherwise allocated to a segment. As such, the corporate entity is not determined to be an operating segment but is discretely disclosed for purposes of reconciliation to the Company’s unaudited condensed consolidated financial statements.

• Renewable Natural Gas Revenues : We record revenues from the production and sale of RNG and the generation and sale of the Environmental Attributes derived from RNG, such as RINs and LCFS credits. Our RNG revenues from Environmental Attributes are recorded net of a portion of Environmental Attributes shared with off-take counterparties as consideration for such counterparties using the RNG as a transportation fuel. We monetize a portion of our RNG production under fixed-price and counterparty sharing agreements, which provide floor prices in excess of commodity indices and sharing percentages of the monetization of Environmental Attributes. Under these sharing arrangements, we receive a portion of the profits derived from counterparty monetization of the Environmental Attributes in excess of the floor prices. We commissioned our Pico RNG facility in August 2020 and began reporting it within our RNG segment beginning October 2020. We commissioned Coastal RNG facility in September 2020. While these sites will contribute to improved volumes, we expect facilities to go through optimization periods after commissioning prior to meeting budget expectations.

• Renewable Electricity Generation Revenues: We record revenues from the production and sale of Renewable Electricity and the generation and sale of the Environmental Attributes, such as RECs, derived from Renewable Electricity. All of our Renewable Electricity production is monetized under fixed-price PPAs from our existing operating projects.

• Corporate Revenues: Corporate reports realized and unrealized gains or losses under our gas hedge programs. Corporate also relates to additional discrete financial information for the corporate function; primarily used as a shared service center for maintaining functions such as executive, accounting, treasury, legal, human resources, tax, environmental, engineering and other operations functions not otherwise allocated to a segment.

Our revenues are priced based on published index prices which can be influenced by factors outside our control, such as market impacts on commodity pricing and regulatory developments. With our royalty payments structured as a percentage of revenue, royalty payments fluctuate with changes in revenues. Due to these factors, we place a primary focus on managing production volumes and operating and maintenance expenses as these factors are more controllable by us.

RNG Production

Our RNG production levels are subject to fluctuations based on numerous factors, including:

• Disruptions to Production: Disruptions to waste placement operations at our active landfill sites, severe weather events, failure or degradation of our or a landfill operator’s equipment or interconnection or transmission problems could result in a reduction of our RNG production. We strive to proactively address any issues that may arise through preventative maintenance, process improvement and flexible redeployment of equipment to maximize production and useful life. In November 2019, our McCarty facility lost production capacity of one of its engines due to its failure. Production was not restored until March 2020 when a replacement was commissioned. Our first quarter of 2021 volumes improved approximately 29.1% from the first quarter of 2020 due mainly to the commissioning of this engine in the prior year period. In October 2020, California wildfires forced our Bowerman facility to temporarily shut down. While production resumed in November 2020, our first quarter of 2021 revenues related to the Bowerman facility were approximately 18.9% lower than the prior year period, related in part to these wildfires.

• Recent historical cold weather impacted our Atascocita, Galveston, McCarty, and Coastal Plains facilities located in Texas during February 2021. Production at these facilities was temporarily idled due to the loss of power from February 14 through February 20, 2021 and force majeure events were declared by certain of our counter-parties or by us for the period February 12 through February 22, 2021 related to these weather events. Operations at these facilities have subsequently resumed, but as a result of our utility provisions when we are not using utilities, providers are able to contribute the capacity back into the market and we receive credit against our future bills. Due mainly to these agreements, our utility costs within our RNG segment were approximately 54.9% lower in the first quarter of 2021 as compared to the first quarter of 2020. Our utility costs normalized during the second quarter of 2021.

• Quality of Biogas: We are reliant upon the quality and availability of biogas from our site hosts. The quality of the waste at our landfill project sites is subject to change based on the volume and type of waste accepted. Variations in the quality of the biogas could affect our RNG production levels. At three of our projects, we operate the wellfield collection system, which allows greater control over the quality and consistency of the collected biogas. At two of our projects, we have operating and management agreements by which we earn revenue for managing the wellfield collection systems. Additionally, our dairy farm project benefits from the consistency of feedstock and controlled environment of collection of waste to improve biogas quality.

• RNG Production from Our Growth Projects: We anticipate increased production at certain of our existing projects as open landfills continue to take in additional waste and the amount of gas available for collection increases. Delays in commencement of production or extended commissioning issues at a new project or a conversion project would delay any realization of production from that project.

27

Pricing

Our Renewable Natural Gas and Renewable Electricity Generation segments’ revenues are primarily driven by the prices under our

off-take

agreements and PPAs and the amount of RNG and Renewable Electricity that we produce. We sell the RNG produced from our projects under a variety of short-term and medium-term agreements to counterparties, with contract terms varying from three years to five years. Our contracts with counterparties are typically structured to be based on varying natural gas price indices for the RNG produced. All of the Renewable Electricity produced at our

biogas-to-electricity

projects is sold under long-term contracts to creditworthy counterparties, typically under a fixed price arrangement with escalators.

The pricing of Environmental Attributes, which accounts for a substantial portion of our revenues, is subject to volatility based on a variety of factors, including regulatory and administrative actions and commodity pricing.

Our dairy farm project is expected to be awarded a more attractive CI by CARB, thereby generating LCFS credits at a multiple of those generated by our landfill projects. This information is expected to become known in 2022.

The sale of RINs, which is subject to market price fluctuations, accounts for a substantial portion of our revenues. We manage against the risk of these fluctuations through forward sales of RINs, although currently we generally only sell RINs in the calendar year they are generated. In the fourth quarter of 2020, due to the uncertainty regarding the outcome of the 2020 US Presidential election, we entered into forward commitments of approximately 50% of our expected 2021 RIN generation. These forward commitments were based on D3 RIN index prices at the time of the commitment, therefore our realized average RIN price in the first six months of 2021 of approximately $1.77 was below the D3 RIN index of approximately $2.80. The remaining forward commitments will only be monetized throughout 2021. Realized prices for Environmental Attributes monetized in a year may not correspond directly to index prices in the current or following year due to the forward selling of commitments.

Factors Affecting Operating Expenses

Our operating expenses include royalties, transportation, gathering and production fuel expenses, project operating and maintenance expenses, general and administrative expenses, depreciation and amortization, net loss (gain) on sale of assets, impairment loss and transaction costs.

• Project Operating and Maintenance Expenses: Operating and maintenance expenses primarily consist of expenses related to the collection and processing of biogas, including biogas collection system operating and maintenance expenses, biogas processing, operating and maintenance expenses, and related labor and overhead expenses. At the project level, this includes all labor and benefit costs, ongoing corrective and proactive maintenance, project level utility charges, rent, health and safety, employee communication, and other general project level expenses. Scheduled timing of proactive maintenance can be based on equipment usage and, as equipment ages, these costs may not be linear as compared to prior years.

• Royalties, Transportation, Gathering and Production Fuel Expenses: Royalties represent payments made to our facility hosts, typically structured as a percentage of revenue. Transportation and gathering expenses include capacity and metering expenses representing the costs of delivering our RNG and Renewable Electricity production to our customers. These expenses include payments to pipeline operators and other agencies that allow for the transmission of our gas and electricity commodities to end users. Production fuel expenses generally represent alternative royalty payments based on quantity usage of biogas feedstock.

• General and Administrative Expenses: General and administrative expenses primarily consist of corporate expenses and unallocated support functions for our operating facilities, including personnel costs for executive, finance, accounting, investor relations, legal, human resources, operations, engineering, environmental registration and reporting, health and safety, IT and other administrative personnel and professional fees and general corporate expenses. In connection with the consummation of the IPO and the Reorganization Transactions, stock options issued under MNK’s SAR Plan were canceled. Under ASC 718, the Company accelerated all previously unvested stock-based compensation expense of approximately $2,050 in January 2021. The Company’s board of directors approved grants of restricted stock, non-qualified stock option, and restricted stock unit awards under the MRI EICP on January 28, 2021. The Company accounted for stock-based compensation related to these equity awards under ASC 718 and recognized approximately $4,132 in stock-based compensation related to these awards in the first six months of 2021. The Company currently expects this amount to reflect the quarterly expense for each of the remaining quarters in 2021 as the other share-based compensation expense in the first quarter of 2021 was a one-time expense related to the cancellation and replacement of the SAR Plan with the MRI EICP. Finally, in connection with restricted stock awarded, the recipients made elections under 83(b) of the Code and we withheld a portion of the restricted stock awarded. In accordance with ASC 718, the Company recognized accelerated stock-based compensation expense related to the shares and we recorded approximately $10,813 in stock-based compensation in the first quarter of 2021. In the aggregate, we recognized approximately $17,140 in stock-based compensation in the first six months of 2021. For more information, see Note 15 to our unaudited condensed consolidated financial statements.

• Depreciation and Amortization: Expenses related to the recognition of the useful lives of our intangible and fixed assets. We spend significant capital to build and own our facilities. In addition to development capital, we annually reinvest to maintain these facilities.

28

• Impairment Loss: Expenses related to reductions in the carrying value(s) of long-lived assets based on periodic evaluations whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

• Transaction Costs: Transaction costs primarily consist of expenses incurred for due diligence and other activities related to potential acquisitions and other strategic transactions.

Key Operating Metrics

Total operating revenues reflect both sales of renewable energy and sales of related Environmental Attributes. As a result, our revenues are primarily affected by unit production of RNG and Renewable Electricity, production of Environmental Attributes, and the prices at which we monetize such production. Set forth below is an overview of these key metrics:

• Production volumes: We review performance by site based on unit of production calculations for RNG and Renewable Electricity, measured in terms of MMBtu and Megawatt Hours (“MWh”), respectively. While unit of production measurements can be influenced by schedule facility maintenance schedules, the metric is used to measure the efficiency of operations and the impact of optimization improvement initiatives. We monetize a majority of our RNG commodity production under variable-price agreements, based on indices. A portion of our Renewable Natural Gas segment commodity production is monetized under fixed-priced contracts. Our Renewable Electricity Generation segment commodity production is primarily monetized under fixed-priced PPAs.

• Production of Environmental Attributes: We monetize Environmental Attributes derived from our production of RNG and Renewable Electricity. We carry-over a portion of the RINs generated from RNG production to the following year and monetize the carried over RINs in such following calendar year. A majority of our Renewable Natural Gas segment Environmental Attributes are self-monetized, though a portion are generated and monetized by third parties under counterparty sharing agreements. A majority of our Renewable Electricity Generation segment Environmental Attributes are monetized as a component of our fixed-price PPAs.

• Average realized price per unit of production: Our profitability is highly dependent on the commodity prices for natural gas and electricity, and the Environmental Attribute prices for RINs, LCFS credits, and RECs. Realized prices for Environmental Attributes monetized in a year may not correspond directly with that year’s production as attributes may be carried over and subsequently monetized. Realized prices for Environmental Attributes monetized in a year may not correspond directly to index prices due to the forward selling of commitments.

29

The following table summarizes the key operating metrics described above, which metrics we use to measure performance.

(in thousands, unless otherwise indicated)	Three Months Ended June 30						Change			Change %
	2021			2020
Revenues
Renewable Natural Gas Total Revenues	$	27,581		$	23,378		$	4,203			18.0	%
Renewable Electricity Generation Total Revenues	$	4,093		$	4,530		$	(437	)		(9.6	%)
RNG Metrics
CY RNG production volumes (MMBtu)		1,416			1,542			(126	)		(8.2	%)
Less: Current period RNG volumes under fixed/floor-price contracts		(487	)		(532	)		45			8.5	%
Plus: Prior period RNG volumes dispensed in current period		342			297			45			15.2	%
Less: Current period RNG production volumes not dispensed		(339	)		(353	)		14			4.0	%
Total RNG volumes available for RIN generation (1)		932			954			(22	)		(2.3	%)
RIN Metrics
Current RIN generation ( x 11.727) (2)		10,935			11,192			(257	)		(2.3	%)
Less: Counterparty share (RINs)		(1,248	)		(1,348	)		100			7.4	%
Plus: Prior period RINs carried into current period		234			1,700			(1,466	)		(86.2	%)
Less: CY RINs carried into next CY		—			—
Total RINs available for sale (3)		9,921			11,544			(1,623	)		(14.1	%)
Less: RINs sold		(8,750	)		(12,000	)		3,250			27.1	%
RIN Inventory		1,171			(456	)		1,627			356.8	%
RNG Inventory (volumes not dispensed for RINs) (4)		339			353			(14	)		(4.0	%)
Average Realized RIN price	$	1.78		$	1.37		$	0.41			29.9	%
Operating Expenses
Renewable Natural Gas Operating Expenses	$	15,954		$	11,896		$	4,058			34.1	%
Operating Expenses per MMBtu (actual)	$	11.27		$	7.71		$	3.56			46.2	%
Renewable Electricity Generation Operating Expenses	$	2,776		$	3,507		$	(731	)		(20.8	%)
$/MWh (actual)	$	59.09		$	68.54		$	(9.45	)		(13.8	%)
Other Metrics
Renewable Electricity Generation Volumes Produced (MWh)		47			51			(4	)		(7.8	%)
Average Realized Price $/MWh (actual)	$	87.12		$	89.23		$	(2.11	)		(2.4	%)

(1) RINs are generated in the month that the gas is dispensed to generate RINs, which occurs the month after the gas is produced. Volumes under fixed/floor-price arrangements generate RINs which we do not self-market.

(2) One MMBtu of RNG has the same energy content as 11.727 gallons of ethanol, and thus may generate 11.727 RINs under the RFS program.

(3) Represents RINs available to be self-marketed by us during the reporting period.

(4) Represents gas production which has not been dispensed to generate RINs.

30

Results of Operations

Comparison of Three Months Ended June 30, 2021 and 2020

The following table summarizes our revenues, expenses and net income for the periods set forth below:

	Three Months Ended June 30									Change %
	2021			2020			Change
Total operating revenues	$	31,674		$	27,908		$	3,766			13.5	%
Operating expenses:
Operating and maintenance expenses		13,187			10,125			3,062			30.2	%
General and administrative expenses		7,341			3,765			3,576			95.0	%
Royalties, transportation, gathering and production fuel		5,986			5,248			738			14.1	%
Depreciation, depletion and amortization		5,660			5,302			358			6.8	%
Gain on insurance proceeds		—			(94	)		94			100.0	%
Transaction costs		37			—			37			0.0	%
Total operating expenses		32,211			24,346			7,865			32.3	%
Operating profit	$	(537	)	$	3,562		$	(4,099	)		(115.1	%)
Total other expenses		730			919			(189	)		(20.6	%)
Income tax expense (benefit)		3,385			4,226			(841	)		(19.9	%)
Net (loss)	$	(4,652	)	$	(1,583	)	$	(3,069	)		(193.9	%)

Revenues for the Three Months Ended June 30, 2021 and 2020

Total revenues in the second quarter of 2021 were $31,674, an increase of $3,766 (13.5%) compared to $27,908 in the second quarter of 2020. The primary driver for this increase relates to higher revenues of $4,617 recognized under counterparty sharing agreements. Partially offsetting this increase was a decrease in the volume of RINs sold during the second quarter of 2021 due to inter-period timing of transfers of RINs as the majority of our RINs are self-marketed. For these comparative periods we entered into fewer commitments for the second quarter of 2021 versus the second quarter of 2020.

Renewable Natural Gas Revenues

We produced 1,416 MMBtu of RNG during the second quarter of 2021, a decrease of 126 MMBtus over the 1,541 MMBtus (8.2%) produced in second quarter of 2020. Of the second quarter of 2021 volumes, 30 MMBtu of RNG was produced from development sites commissioned during 2020. Of the 156 lower MMBtus of RNG produced at our other locations, 126 MMBtus of this reduction relates to process equipment failures at our McCarty facility. We have repaired the equipment failures at our McCarty facility.

Revenues from the Renewable Natural Gas segment in the second quarter of 2021 were $27,581, an increase of $4,203 (18.0%) compared to $23,378 in the second quarter of 2020. Average commodity pricing for natural gas for the second quarter of 2021 was $2.83 per MMBtu, 7.4% lower than the second quarter of 2020. During the second quarter of 2021, we self-monetized 8,750 RINs, representing a 3,250 decrease (27.1%) compared to 12,000 in the second quarter of 2020. The decrease was primarily related to inter-period timing on transfers of RINs as the majority of our RINs are self-marketed resulting in fewer commitments for second quarter of 2021 versus the second quarter of 2020. Average pricing realized on RIN sales during the second quarter of 2021 was $1.78 as compared to $1.37 in the second quarter of 2020, an increase of 29.9%. This compares to the average D3 RIN index price for the second quarter of 2021 of $3.06 being more than double the average D3 RIN index price in the second quarter of 2020. All of our second quarter 2021 and 2020 RIN sales were priced generally on the D3 index with none based on the CWC. At June 30, 2021, we had approximately 932 MMBtus available for RIN generation and approximately 1,171 RINs generated and unsold. For June 30, 2020, we had approximately 954 MMBtus available for RIN generation and approximately zero generated and unsold.

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Renewable Electricity Generation Revenues

We produced approximately 47 MWh in Renewable Electricity during the second quarter of 2021, a decrease of 4 MWh from the 51 MWh (7.8%) produced in second quarter of 2020. Of the decrease, 3 MWh relates to our Security facility having zero production in second quarter of 2021 compared to 3 MWh produced in second quarter of 2020. The projects to restore the engines at our Security facility are still ongoing and are currently anticipated to be completed in the third quarter of 2021.

In the second quarter of 2021, 100% of Renewable Electricity Generation segment revenues were derived from the monetization of Renewable Electricity at fixed prices associated with the underlying PPAs, as compared to 92.8% in the second quarter of 2020. This provides the Company with certainty of price resulting from our Renewable Electricity sites.

Corporate Analysis

We did not have any gas hedge programs outstanding during the second quarter of 2021 or 2020. During the second quarter of 2021 associated with our purchase of RINs at market prices, we recorded an adjustment of $710 to reduce the carrying value of those RINs to net realizable value. This adjustment was included within operating and maintenance expenses in the condensed consolidated statement of operations. We did not have market purchased RINs during the second quarter of 2020.

Expenses for the Three Months Ended June 30, 2021 and 2020

General and Administrative Expenses

Total general and administrative expenses of $7,341 for the second quarter of 2021, an increase of $3,576 (95.0%) compared to $3,765 for the second quarter of 2020. Of the total in the second quarter of 2021, $2,201 related to stock-based compensation costs primarily associated with the IPO and Reorganization Transactions. Excluding the impacts of IPO related stock-based compensation, general and administrative expenses increased approximately $1,501. Corporate insurance for second quarter of 2021 increased approximately $796 (129.4%) compared to second quarter of 2020 due to increased premiums associated with the IPO. Additionally, professional fees for second quarter of 2021 increased approximately $293 (55.7%) compared to the second quarter of 2020. Finally, there was an increase in public company filing fees of approximately $126 in the second quarter of 2021. Such fees were nominal in the second quarter of 2020.

Renewable Natural Gas Expenses

Operating and maintenance expenses for our RNG facilities in the second quarter of 2021 were $10,159, an increase of $3,056 (43.0%) as compared to $7,103 in the second quarter of 2020. Approximately $960 of the increase is related to development sites commissioned during 2020. Exclusive of the effects of these development sites, operating and maintenance expenses for the second quarter of 2021 were $9,198, an increase of $2,095 (29.5%) compared to the second quarter of 2020. Our Atascocita facility’s operating and maintenance expenses increased approximately $566 compared to the second quarter of 2020 due to additional media changeouts and disposal expenses. Our Galveston facility had increased repair expenses of approximately $800 in the second quarter of 2021, due to elevated levels of hydrogen sulfide contaminants in the methane feedstock. Additionally, our Rumpke facility operating and maintenance expenses for the second quarter of 2021 increased $438 compared to the second quarter of 2020 due to timing of site planned outage maintenance.

Royalties, transportation, gathering and production fuel expenses for the Company’s RNG facilities for the second quarter of 2021 were $5,537, an increase of $744 (15.5%) compared to $4,793 in the second quarter of 2020. Royalties, transportation, gathering and production fuel expenses increased as a percentage of RNG revenues to 20.1% for the second quarter of 2021 from 20.5% in the second quarter of 2020. While we had decreased production volumes in the second quarter of 2021 compared to the second quarter of 2020, the increase in royalties, transportation, gathering and production fuel expenses is primarily a result of the increase in our counterparty sharing agreement revenues.

32

Renewable Electricity Expenses

Operating and maintenance expenses for our Renewable Electricity facilities in the second quarter of 2021 were $2,328, a decrease of $717 (23.5%) compared to $3,045 in the second quarter of 2020. We reported the results of Pico within the Renewable Electricity Generation segment until October 2020. Of the 2020 period total, Pico contributed $412 and, exclusive of Pico, Renewable Electricity facility operating and maintenance expenses decreased in the second quarter of 2021 compared to the second quarter of 2020 by $311 (40.3%). The decrease is primarily a result of timing of scheduled engine preventative maintenance intervals at our Bowerman facility, which was approximately $198 higher in the second quarter of 2020 over the second quarter of 2021. We continue to anticipate increases in scheduled maintenance for the remaining third and fourth quarters of 2021 at our Bowerman facility.

Royalties, transportation, gathering and production fuel expenses for our Renewable Electricity facilities for the second quarter of 2021 were $448, down from $490 in the second quarter of 2020, and as a percentage of Renewable Electricity Generation segment revenues increased to 11.0% from 10.8%. This increase relates primarily to our Pico results being included in the RNG segment during the first quarter of 2021.

Royalty Payments

Royalties, transportation, gathering, and production fuel expenses in the second quarter of 2021 were $5,986, an increase of $738 (14.1%) compared to $5,248 in the second quarter of 2020. We make royalty payments to our fuel supply site hosts on the commodities we produce and the associated Environmental Attributes. These royalty payments are typically structured as a percentage of revenue subject to a cap, with fixed minimum payments when Environmental Attribute prices fall below a defined threshold. To the extent commodity and Environmental Attributes’ prices fluctuate, our royalty payments may fluctuate upon renewal or extension of a fuel supply agreement or in connection with new projects. Our fuel supply agreements are typically structured as

20-year

contracts, providing long-term visibility into the margin impact of future royalty payments.

Depreciation

Depreciation and amortization in the second quarter of 2021 was $5,660, an increase of $358 (6.8%) compared to $5,302 in the second quarter of 2020. Our development sites commissioned and placed into service during 2020 contributed $615 of increased depreciation and amortization in the second quarter of 2021 as compared to the second quarter of 2020.

Impairment loss

We did not record any impairment losses in the second quarter of 2021 or 2020.

Other Expenses (Income)

Other expenses in the second quarter of 2021 were $730, a decrease of $189 (16.2%) compared to $919 in the second quarter of 2020. Of the decrease in other expenses, $139 of the decrease is related to a reduction of interest expense from second quarter of 2021 compared to the second quarter of 2020.

Income Tax Expense (Benefit)

Income tax expense for the three months ended June 30, 2021 was calculated using the estimated annual effective tax rate. The effective tax rate differs from the U.S. federal statutory rate of 21% primarily due to the current year permanent disallowance of officers’ compensation under code IRC code 162(m) partially offset by the favorable impact of the production tax credit.

The effective tax rate of (267%) for the three months ended June 30, 2021 was lower than the rate for the three months ended June 30, 2020 of 160% primarily due to the current year disallowance of officers’ compensation under code IRC code 162(m). We utilized an annual effective tax rate for tax expense calculated for the three months ended June 30, 2021 (compared to a year to date approach at March 31, 2021), which when applied to year to date pre-tax book loss and layering in nominal discrete events, resulted in a (267%) quarter to date effective tax rate. The 160% second quarter to date 2020 effective tax rate was a result of the second quarter pre-tax book income applied to the estimated annual effective tax rate, with no significant discrete events in that quarter.

Operating Profit (Loss) for the Three Months Ended June 30, 2021 and 2020

Operating loss in the second quarter of 2021 was $537, a decrease of $4,099 (115.0%) compared to an operating profit of $3,562 in the second quarter of 2020. RNG operating profit for the second quarter of 2021 was $7,603, a decrease of $525 (6.5%) compared to $8,128 in the second quarter of 2020. Renewable Electricity Generation operating profit for the second quarter of 2021 was $16, an increase of $773 (102.1%) compared to an operating loss of $758 for the second quarter of 2020. The primary driver of the increase is due to the results of Pico being reported within the Renewable Electricity Generation segment until October 2020.

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The following table summarizes the key operating metrics described above, which metrics we use to measure performance.

(in thousands, unless otherwise indicated)	Six Months Ended June 30
	2021			2020			Change			Change %
Revenues
Renewable Natural Gas Total Revenues	$	55,704		$	36,804		$	18,900			51.4	%
Renewable Electricity Generation Total Revenues	$	7,417		$	9,026		$	(1,609	)		(17.8	%)
RNG Metrics
CY RNG production volumes (MMBtu)		2,764			2,931			(167	)		(5.7	%)
Less: Current period RNG volumes under fixed/floor-price contracts		(939	)		(1,063	)		124			11.7	%
Plus: Prior period RNG volumes dispensed in current period		353			266			87			32.7	%
Less: Current period RNG production volumes not dispensed		(339	)		(353	)		14			4.0	%
Total RNG volumes available for RIN generation (1)		1,839			1,781			58			3.3	%
RIN Metrics
Current RIN generation ( x 11.727) (2)		21,551			20,886			665			3.2	%
Less: Counterparty share (RINs)		(2,395	)		(2,270	)		(125	)		(5.5	%)
Plus: Prior period RINs carried into current period		110			1,330			(1,220	)		(91.7	%)
Less: CY RINs carried into next CY		—			—
Total RINs available for sale (3)		19,266			19,947			(681	)		(3.4	%)
Less: RINs sold		(17,625	)		(19,835	)		2,210			11.1	%
RIN Inventory		1,641			112			1,529			1365.2	%
RNG Inventory (volumes not dispensed for RINs) (4)		339			353			(14	)		(4.0	%)
Average Realized RIN price	$	1.77		$	1.06		$	0.71			67.0	%
Operating Expenses
Renewable Natural Gas Operating Expenses	$	29,088		$	21,310		$	7,778			36.5	%
Operating Expenses per MMBtu (actual)	$	10.53		$	7.27		$	3.26			44.8	%
Renewable Electricity Generation Operating Expenses	$	6,169		$	6,463		$	(294	)		(4.5	%)
$/MWh (actual)	$	65.42		$	62.45		$	2.97			4.8	%
Other Metrics
Renewable Electricity Generation Volumes Produced (MWh)		94			103			(9	)		(8.7	%)
Average Realized Price $/MWh (actual)	$	78.65		$	87.22		$	(8.57	)		(9.8	%)

(1) RINs are generated in the month that the gas is dispensed to generate RINs, which occurs the month after the gas is produced. Volumes under fixed/floor-price arrangements generate RINs which we do not self-market.

(2) One MMBtu of RNG has the same energy content as 11.727 gallons of ethanol, and thus may generate 11.727 RINs under the RFS program.

(3) Represents RINs available to be self-marketed by us during the reporting period.

(4) Represents gas production which has not been dispensed to generate RINs.

34

Results of Operations

Comparison of Six Months Ended June 30, 2021 and 2020

The following table summarizes our revenues, expenses and net income for the periods set forth below:

(in thousands, except per share data)	Six Months Ended June 30
	2021			2020			Change			Change %
Total operating revenues	$	63,121		$	46,312		$	16,809			36.3	%
Operating expenses:
Operating and maintenance expenses		23,830			19,961			3,869			19.4	%
General and administrative expenses		27,761			7,204			20,557			285.4	%
Royalties, transportation, gathering and production fuel		12,204			8,189			4,015			49.0	%
Depreciation, depletion and amortization		11,396			10,650			746			7.0	%
Gain on insurance proceeds		(82	)		(750	)		668			89.1	%
Impairment loss		626			278			348			125.2	%
Transaction costs		125			—			125			0.0	%
Total operating expenses		75,860			45,532			30,328			66.6	%
Operating profit (loss)	$	(12,739	)	$	780		$	(13,519	)		(1733.2	%)
Total other expenses		1,411			3,107			(1,696	)		(54.6	%)
Income tax expense (benefit)		4,767			(6,560	)		11,327			172.7	%
Net income (loss)	$	(18,917	)	$	4,233		$	(23,150	)		(546.9	%)

Revenues for the Six Months Ended June 30, 2021 and 2020

Total revenues in the first six months of 2021 were $63,121, an increase of $16,809 (36.3%) compared to $46,312 in the first six months of 2020. The primary drivers for this increase related to a 66.6% increase in average realized RIN pricing during the first six months of 2021 of $1.77 compared to $1.06 in the first six months of 2020. We also recognized higher revenues under our counterparty sharing agreements of $7,016 in the first six months of 2021 compared to the first six months of 2020.

Renewable Natural Gas Revenues

We produced 2,764 MMBtu of RNG during the first six months of 2021, a decrease of 168 MMBtu from over the 2,931 MMBtus (5.7%) produced in first six months of 2020. Volumes for the first six months of 2021 included 78 MMBtu of RNG produced from development sites commissioned during 2020. Of the 246 lower MMBtus of RNG produced at our other locations, our Rumpke site produced 166 less MMBtus compared to the first quarter of 2020 due to landfill filling patterns limiting production and 75 MMBtus of this reduction was related to process equipment failures at our McCarty facility.

Revenues from the Renewable Natural Gas segment in the first six months of 2021 were $55,704, an increase of $18,900 (51.4%) compared to $36,804 in the first six months of 2020. Average commodity pricing for natural gas for the first six months of 2021 was $2.76 per MMBtu, 4.5% lower than the first six months of 2020. During the first six months of 2021, we self-monetized 17,625 RINs, representing a 2,211 decrease (11.1%) compared to 19,835 in the first six months of 2020. The decrease was primarily related to inter-period timing on transfers of RINs. Average pricing realized on RIN sales during the first six months of 2021 was $1.77 as compared to $1.06 in the first six months of 2020, an increase of 66.6%. This compares to the average D3 RIN index price for the first six months of 2021 of $2.80 being approximately 113.7% higher than the average D3 RIN index price in the first six months of 2020. All of our first six months of 2021 and 2020 RIN sales were priced generally on the D3 index with none based on the CWC. At June 30, 2021, we had approximately 339 MMBtus available for RIN generation. We had approximately 1,641 RINs generated and unsold at June 30, 2021. We had approximately 353 MMBtus available for RIN generation at June 30, 2020 and approximately 112 RINs generated and unsold at June 30, 2020.

35

Renewable Electricity Generation Revenues

We produced approximately 94 MWh in Renewable Electricity in the first six months of 2021 compared to 103 MWh in first six months of 2020. The decrease of 9 MWh (8.9%) is a result of engine maintenance at our Bowerman facility and the ongoing projects to restore the engines at our Security facility, which are currently anticipated to be complete in the third quarter of 2021.

Revenues from Renewable Electricity facilities in the first six months of 2021 were $7,417, a decrease of $1,609 (17.8%) compared to $9,026 in the first six months of 2020. Prior to reporting Pico in RNG, Pico accounted for $574 of the decrease. Our Bowerman facility was impacted in the fourth quarter of 2020 by the California wildfires forcing it to temporarily shut down the facility. This shut down delayed the timing of monetization of the Environmental Attributes associated with the Bowerman facility and resulted in approximately $600 in reduced revenues in the first six months of 2021 as compared to the first six months of 2020.

In the first six months of 2021, 100% of Renewable Electricity Generation segment revenues were derived from the monetization of Renewable Electricity at fixed prices associated with the underlying PPAs, as compared to 93.6% in the first six months of 2020. This provides the Company with certainty of price resulting from our Renewable Electricity sites.

Corporate Analysis

While we did not have any gas hedge programs in the first six months of 2021, our gas hedge program during the first six months of 2020 was priced at rates in excess of the actual index price, resulting in realized losses of $388. During the second quarter of 2021 associated with our purchase of RINs at market prices, we recorded an adjustment of $710 to reduce the carrying value of those RINs to net realizable value. This adjustment was included within operating and maintenance expenses in the condensed consolidated statement of operations. We did not have market purchased RINs during the first six months of 2020.

Expenses for the Six Months Ended June 30, 2021 and 2020

General and Administrative Expenses

Total general and administrative expenses of $27,761 for the first six months of 2021, an increase of $20,557 (285.4%) compared to $7,204 for the first six months of 2020. Of the total in the first six months of 2021, $16,555 related to stock-based compensation costs associated with the IPO and Reorganization Transactions. Excluding the impacts of IPO related stock-based compensation, general and administrative expenses increased approximately $3,786. Employee related costs, including stock-based compensation, increased approximately $17,273 (408.4%) in the first six months of 2021 as compared to the first six months of 2020. This increase is related to our accounting for the cancellation of MNK options and recording approximately $2,050 in previously unvested stock-based compensation expense. We recorded approximately $14,948 in stock-based compensation expense associated with the grants of restricted stock,

non-qualified

stock options, and restricted stock units associated with employee grants approved by the Company’s board of directors in January 2021. Additionally, professional fees increased approximately $1,903 (218.9%) during the first six months of 2021 primarily resulting from our successful completion of the IPO and Reorganization Transactions. Finally, our corporate insurance premiums increased approximately $1,419 (122.1%) during the first six months of 2021 over the first six months of 2020 period primarily related to premium increases associated with the completion of the IPO.

Renewable Natural Gas Expenses

Operating and maintenance expenses for our RNG facilities in the first six months of 2021 were $17,760, an increase of $3,725 (26.5%) as compared to $14,035 in the first six months of 2020. Approximately $2,104 of the increase related to development sites commissioned during 2020. Exclusive of the effects of these development sites, operating and maintenance expenses for the first six months of 2021 were $15,656, a decrease of $1,621 (11.5%) compared to $14,035 in the first six months of 2020. Our Houston based facilities were favorably impacted by lower utility rates during the first six months of 2021. Certain of our utility contracts have provisions that when we are not using utilities, the providers are able to contribute that capacity back into the market and we receive credit against our future bills. The first quarter of 2021 weather event which temporarily impacted our Houston facilities utility consumption resulted in our RNG utilities being approximately $1,721 lower in such period as compared to the first quarter of 2020. The majority of this reduction is related to these contractual arrangements.

Royalties, transportation, gathering and production fuel expenses for the Company’s RNG facilities for the first six months of 2021 were $11,328, an increase of $4,053 (55.7%) compared to $7,275 in the first six months of 2020. Royalties, transportation, gathering and production fuel expenses increased as a percentage of RNG revenues to 20.3% for the first six months of 2021 from 19.8% in the first six months of 2020. The majority of the increase in royalties, transportation, gathering and production fuel expenses related to the increase in Environmental Attribute and counterparty sharing agreement revenues in the first six months of 2021 compared to the first six months of 2020.

36

Renewable Electricity Expenses

Operating and maintenance expenses for our Renewable Electricity facilities in the first six months of 2021 were $5,293, a decrease of $228 (4.1%) compared to $5,521 in the first six months of 2020. We reported the results of Pico within the Renewable Electricity Generation segment until October 2020. Of the 2020 period total, Pico contributed $803 and, exclusive of Pico, Renewable Electricity facility operating and maintenance expenses increased in the first six months of 2021 compared to the first six months of 2020 by $575 (12.2%). The increase is primarily related to scheduled engine preventative maintenance intervals at our Bowerman facility, which was approximately $765 higher in the first six months of 2021 over the first quarter of 2020. This increase in scheduled maintenance is expected to continue into the fourth quarter of 2021 at our Bowerman facility. Offsetting the favorable increase was a repair of an engine at our Tulsa facility of approximately $120 in the first six months of 2020.

Royalties, transportation, gathering and production fuel expenses for our Renewable Electricity facilities for the first six months of 2021 were $876, a decrease of $67 (7.1%) compared to $943 in the first six months of 2020, and as a percentage of Renewable Electricity Generation segment revenues increased to 11.8% from 10.5%. This decrease relates to the temporary shutdown of our Bowerman facility due to the California wildfires resulting in a loss of revenue associated with the Environmental Attributes.

Royalty Payments

Royalties, transportation, gathering, and production fuel expenses in the first six months of 2021 were $12,204, an increase of $4,015 (49.0%) compared to $8,189 in the first six months of 2020. We make royalty payments to our fuel supply site hosts on the commodities we produce and the associated Environmental Attributes. These royalty payments are typically structured as a percentage of revenue subject to a cap, with fixed minimum payments when Environmental Attribute prices fall below a defined threshold. To the extent commodity and Environmental Attributes’ prices fluctuate, our royalty payments may fluctuate upon renewal or extension of a fuel supply agreement or in connection with new projects. Our fuel supply agreements are typically structured as

20-year

contracts, providing long-term visibility into the margin impact of future royalty payments.

Depreciation

Depreciation and amortization in the first six months of 2021 was $11,396, an increase of $746 (7.0%) compared to $10,650 in the first six months of 2020. Our development sites commissioned and placed into service during 2020 contributed $1,151 of increased depreciation and amortization in the first six months of 2021 as compared to the first six months of 2020.

Impairment loss

We calculated and recorded an impairment loss of $626 in the first six months of 2021, an increase of $348 (125.2%) compared to $278 in the first six months of 2020. The impairment in first six months of 2021 related to a landfill host requesting us to decommission a previously converted electric to RNG site. We had been contractually obligated to maintain the site. The impairment in first six months of 2020 was attributable to the termination of a development agreement related to our Pico acquisition.

Other Expenses (Income)

Other expenses in the first six months of 2021 were $1,410, a decrease of $1,697 (54.6%) compared to other expenses of $3,107 in the first six months of 2020. Reduced interest expense of $1,707 in the first six months of 2021 compared to the first six months of 2020 associated with our Credit Agreement, was the primary reason for this reduction.

Income Tax Expense (Benefit)

Income tax expense for the six months ended June 30, 2021 was calculated using an annualized effective tax rate. The effective tax rate differs from the U.S. federal statutory rate of 21% primarily due to the current year permanent disallowance of officers’ compensation under code IRC code 162(m) partially offset by the favorable impact of the production tax credit.

The effective tax rate of (34%) for the six months ended June 30, 2021 was lower than the rate for the six months ended June 30, 2020 of 282% primarily due to the income tax benefit that increased the 2020 effective tax rate in connection with the January 1, 2020 dissolution of the MEC partnership which allows all entities under Montauk Energy Capital to file as part of our consolidated federal tax group.

Operating Loss for the Six Months Ended June 30, 2021 and 2020

Operating loss in the first six months of 2021 was $12,739, a decrease of $13,519 (1,733.2%) compared to an operating profit of $780 in the first six months of 2020. The primary driver of the increase in operating loss relates to the IPO and Reorganization Transactions stock-based compensation expense of $16,618 recognized in the first six months of 2021. RNG operating profit for the first six months of 2021 was $18,198, an increase of $8,873 (95.2%) compared to $9,325 in the first six months of 2020. Renewable Electricity Generation operating loss for the first six months of 2021 was $2,203, a decrease of $862 (64.4%) compared to an operating loss of $1,341 for the first six months of 2020.

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Key Trends

Trends Affecting the Renewable Fuel Market

We believe rising demand for RNG is attributable to a variety of factors, including growing public support for renewable energy, U.S. governmental actions to increase energy independence, environmental concerns increasing demand for natural

gas-powered

vehicles, job creation, and increasing investment in the renewable energy sector.

Key drivers for the long-term growth of RNG include the following factors:

• Regulatory or policy initiatives, including the federal RFS program and state-level low-carbon fuel programs in states such as California and Oregon, that drive demand for RNG and its derivative Environmental Attributes.

• Efficiency, mobility and capital cost flexibility in our operations enable RNG to compete successfully in multiple markets. Our operating model is nimble, as we commonly use modular equipment; our RNG processing equipment is more efficient than its fossil-fuel correlates.

• Demand for compressed natural gas (“CNG”) from natural gas-fueled vehicles. The RNG we create is pipeline quality and can be used for transportation fuel when converted to CNG. CNG is commonly used by medium-duty fleets that are close to fueling stations, such as city fleets, local delivery trucks and waste haulers.

• Regulatory requirements, market pressure and public relations challenges increase the time, cost and difficulty of permitting new fossil fuel-fired facilities.

There is significant potential for sustained growth in biogas conversion from waste sources, given evolving consumer preferences, regulatory conditions, ongoing waste industry trends, and project economics. We believe that our status as a large producer of RNG from LFG, our

30-year

track record of developing and operating projects, and our deep relationships with some of the largest landfill owners in the country position us well to continue to grow our portfolio. We intend to continue to pursue financially disciplined growth through our proven growth channels, including expansion of existing projects, conversion projects, optimization across our portfolio, greenfield development and acquisitions.

The factors that we believe will affect our future operating results are as follows:

Conversion of Electricity Projects to RNG Projects:

We periodically evaluate opportunities to convert existing facilities from Renewable Electricity to RNG production. These opportunities tend to be most attractive for any merchant electricity facilities given the favorable economics for the sale of RNG plus RINs relative to the sale of market rate electricity plus RECs. This strategy has been an increasingly attractive avenue for growth since 2014 when RNG from landfills became eligible for D3 RINs. Upon completion of a conversion, we expect that the increase in revenue upon commencement of RNG production will more than offset the loss of revenue from Renewable Electricity production. Historically, we have taken advantage of these opportunities on a gradual basis at our merchant electricity facilities, such as Atascocita and Coastal Plains.

Acquisition and Development Pipeline

The timing and extent of our development pipeline affects our operating results due to:

• Impact of Higher Selling, General and Administrative Expenses Prior to the Commencement of a Project’s Operation: We incur significant expenses in the development of new RNG projects. Further, the receipt of RINs is delayed, and typically does not commence for a period of four to six months after the commencement of injecting RNG into a pipeline, pending final registration approval of the project by the EPA and then the subsequent completion of a third-party quality assurance plan certification. During such time, the RNG is either physically or theoretically stored and later withdrawn from storage to allow for the generation of RINs.

• Shifts in Revenue Composition for Projects from New Fuel Sources: As we expand into livestock farm projects, our revenue composition from Environmental Attributes will change. We believe that livestock farms offer us a lucrative opportunity, as the value of LCFS credits for dairy farm projects, for example, are a multiple of those realized from landfill projects due to the significantly more attractive CI score of livestock farms.

• Incurrence of Expenses Associated with Pursuing Prospective Projects That Do Not Come to Fruition: We incur expenses to pursue prospective projects with the goal of a site host accepting our proposal or being awarded a project in a competitive bidding process. Historically, we have evaluated opportunities which we decided not to pursue further due to the prospective project not meeting our internal investment thresholds or a lack of success in a competitive bidding process. To the extent we seek to pursue a greater number of projects or bidding for projects becomes more competitive, our expenses may increase.

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Regulatory, Environmental and Social Trends

Regulatory, environmental and social factors are key drivers that incentivize the development of RNG and Renewable Electricity projects and influence the economics of these projects. We are subject to the possibility of legislative and regulatory changes to certain incentives, such as RINs, RECs and GHG initiatives. The EPA missed its November 30, 2020 statutory deadline to set RVOs for 2021. Accordingly, EPA has not set RVOs for 2021, though we currently anticipate a proposed rule setting the RVOs for 2021 and 2022 during the fourth quarter of 2021. It is unclear if they will meet this timeline. The manner in which the EPA will establish RVOs beginning in 2023, when the statutory RVO mandates are set to expire, is expected to create additional uncertainty as to RIN pricing. Further changes to the CI score assigned to a project upon its renewal or a change in the way CARB develops the CI score for a new project could significantly affect the profitability of a project, particularly in the case of a livestock farm project.

Non-GAAP

Financial Measures:

The following table presents EBITDA and Adjusted EBITDA,

non-GAAP

financial measures for each of the periods presented below. We present EBITDA and Adjusted EBITDA because we believe the measures assist investors in analyzing our performance across reporting periods on a consistent basis by excluding items that we do not believe are indicative of our core operating performance. In addition, EBITDA and Adjusted EBITDA are financial measurements of performance that management and the board of directors use in their financial and operational decision-making and in the determination of certain compensation programs. EBITDA and Adjusted EBITDA are supplemental performance measures that are not required by or presented in accordance with GAAP. EBITDA and Adjusted EBITDA should not be considered alternatives to net income or any other performance measure derived in accordance with GAAP, or as an alternative to cash flows from operating activities or a measure of our liquidity or profitability.

The following table provides our EBITDA and Adjusted EBITDA, as well as a reconciliation to net income, which is the most directly comparable GAAP measure, for the three months ended June 30, 2021 and 2020:

	Three Months Ended June 30
	2021			2020
Net Income (loss)	$	(4,652	)	$	(1,583	)
Depreciation and Amortization		5,660			5,302
Interest expense		720			859
Income tax expense (benefit)		3,385			4,226
EBITDA		5,113			8,804
Transaction costs		37			—
Adjusted EBITDA	$	5,150		$	8,804

The following table provides our EBITDA and Adjusted EBITDA, as well as a reconciliation to net income, which is the most directly comparable GAAP measure, for the six months ended June 30, 2021 and 2020:

	Six Months Ended June 30
	2021			2020
Net Income (loss)	$	(18,917	)	$	4,233
Depreciation and Amortization		11,396			10,650
Interest expense		1,366			3,073
Income tax expense (benefit)		4,767			(6,560	)
EBITDA		(1,388	)		11,396
Impairment loss (1)		626			278
Transaction costs		125			—
Non-cash hedging charges		—			388
Adjusted EBITDA	$	(637	)	$	12,062

(1) During the six months ended June 30, 2021, we recorded an impairment of $626 related to a landfill hosts request for us to decommission a facility previously converted to an RNG facility. We were previously contractually obligated to maintain this facility. During the six months ended June 30, 2020, we recorded an impairment of $278 termination of a development agreement related to our Pico acquisition.

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Liquidity and Capital Resources

Sources of Liquidity

At June 30, 2021 and December 31, 2020, our cash and cash equivalents, net of restricted cash, was $16,350 and $20,992 respectively. We intend to fund near-term development projects using cash flows from operations and borrowings under our revolving credit facility. We believe that we will have sufficient cash flows from operations and borrowing availability under our credit facility to meet our debt service obligations and anticipated required capital expenditures (including for projects under development) for at least the next 12 months. However, we are subject to business and operational risks that could adversely affect our cash flows and liquidity.

On January 26, 2021, upon the closing of our IPO, we received net proceeds of $14,472 after deducting underwriting discounts and commissions of $1,608 and other estimated costs of $6,891.

At June 30, 2021, we had debt before debt issuance costs of $61,698, compared to debt before debt issuance costs of $66,697 at December 31, 2020.

Our debt before issuance costs (in thousands) are as follows:

	June 30, 2021		December 31, 2020
Term loan	$	25,000	$	30,000
Revolving credit facility		36,697		36,697
Debt before debt issuance costs	$	61,697	$	66,697

On December 12, 2018, we entered into an amended revolving credit and term loan agreement (as amended, the “Amended Credit Agreement”), with Comerica Bank (“Comerica”) and certain other financial institutions. The Amended Credit Agreement, which is secured by substantially all of our assets and assets of certain of our subsidiaries and provides for a five-year $95,000 term loan and a five-year $80,000 revolving credit facility.

As of June 30, 2021, $25,000 was outstanding under the term loan and $36,697 was outstanding under the revolving credit facility. The term loan amortizes in quarterly installments of $2,500 and has a final maturity of December 12, 2023 with an interest rate of 2.870% and 2.961% at June 30, 2021 and December 31, 2020, respectively. The revolving and term loans under the Amended Credit Agreement bear interest at the Eurodollar Margin or Base Rate Margin based on our Total Leverage Ratio (in each case, as those terms are defined in the Amended Credit Agreement).

The Amended Credit Agreement contains customary covenants applicable to us and certain of our subsidiaries, including financial covenants. The Amended Credit Agreement is subject to customary events of default, and contemplates that we would be in default if, for any fiscal quarter (x) the average monthly D3 RIN price (as determined in accordance with the Amended Credit Agreement) is less than $0.80 per RIN and (y) the consolidated EBITDA for such quarter is less than $6,000. Consolidated EBITDA is defined under the Amended Credit Agreement as net income plus (a)income tax expense, (b) interest expense, (c) depreciation, depletion, and amortization expense,

(d) non-cash

unrealized derivative expense and (e) any other extraordinary, unusual, or

non-recurring

adjustments to certain components of net income, as agreed upon by Comerica in certain circumstances.

Under the Amended Credit Agreement, we are required to maintain the following ratios:

• a maximum ratio of Total Liabilities to Tangible Net Worth (in each case, as those terms are defined in the Amended Credit Agreement) of greater than 2.0 to 1.0 as of the end of any fiscal quarter; and

• as of the end of each fiscal quarter, (x) a Fixed Charge Coverage Ratio (as defined in the Amended Credit Agreement) of not less than 1.2 to 1.0 and (y) a Total Leverage Ratio (as defined in the Amended Credit Agreement) of not more than 3.0 to 1.0.

As of June 30, 2021, we were in compliance with all applicable financial covenants under the Amended Credit Agreement.

The Amended Credit Agreement replaced our prior credit agreements with Comerica Bank and a portion of the proceeds of the term loan made under the Amended Credit Agreement were used by us to, among other things, fully satisfy an aggregate of $52,500 outstanding under such credit agreements. For additional information regarding the Amended Credit Agreement see Note 13— Debt to our unaudited condensed consolidated financial statements.

Debt Financing

We have historically funded our growth and capital expenditures with our working capital, cash flow from operations and debt financing. We expect our 2021 capital expenditures to range between $8,500 and $9,500. Our 2021 capital plans include annual preventative maintenance expenditures, annual wellfield expansion projects, other specific facility improvements, and information technology improvements. Additionally, we expect to spend $5,000 on optimization projects at our recently commissioned development facilities. Our Amended Credit Agreement provides us with an $80,000 revolving credit facility, with a $75,000 accordion option, providing us with access to additional capital to implement our acquisition and development strategy. Finally, we currently anticipate up to $14,000 in development capital expenditures in 2021 relating to the existing Montauk Ag Renewables acquisition and Pico expansion projects.

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Cash Flow

The following table presents information regarding our cash flows and cash equivalents for the six months ended June 30, 2021 and 2020:

	Six Months Ended June 30
	2021			2020
Net cash flows provided by operating activities	$	11,245		$	8,370
Net cash flows used in investing activities		(8,521	)		(9,691	)
Net cash flows (used in) provided by financing activities		(7,360	)		3,500
Net increase (decrease) in cash and cash equivalents		(4,636	)		2,179
Restricted cash, end of period		573			602
Cash and cash equivalents and restricted, end of period		16,923			12,541

During the first six months of 2021, we generated $11,245 of cash from operating activities, a 34.3% increase from the first six months of 2020 of $8,371. Working capital and other assets and liabilities used $2,963 in the first six months of 2021 compared to using $2,135 in the first six months of 2020. During the three months ended June 30, 2021, we purchased approximately 500 RINs at a D3 spot price of $3.17. Significant adjustments to net income included our accounting for stock-based compensation, a $16,900 increase, and a $2,498 reduction related to our interest rate swap agreements.

Our net cash flows used in investing activities has historically focused on project development and facility maintenance. For the first six months of 2021, our capital expenditures were $4,469, of which approximately $1,550 of our first six months of 2021 capital expenditures were related to optimization projects at our recently commissioned facilities and $1,000 related to the Pico Feedstock Amendment. Including acquisition costs of $341, we acquired assets for the Business in North Carolina of $4,142. For the first six months of 2020, our capital expenditures were $10,454, of which $760, $2,776 and $1,241 related to the construction of our Galveston, Coastal Plains, and Pico RNG facilities, respectively. We also incurred $3,003 in capital expenditures rebuilding the failed engine at our McCarty RNG facility.

Our net cash flows used in financing activities of $7,360 for the first six months of 2021 decreased by $10,860 compared to cash provided by financing activities in the first six months of 2020. The closing of our IPO provided $12,401 in proceeds after payment of commissions and expenses. In connection with withholding shares from restricted stock awards pursuant to elections made by employees under Section 83(b) of the Code, the Company reacquired 950,214 shares with a value of approximately $10,813. Additionally, in connection with the Distribution, we loaned $7,140 to MNK for its dividends tax liability arising under the South African Income Tax Act, 1962, as amended. As security for this loan, MNK has pledged certain of its shares in the Company to Montauk Renewables and agreed to use the proceeds from the sale of such shares to repay this loan. During 2020, we borrowed $8,500 under our revolving credit agreement to be used primarily for development capital expenditures.

Internal Control Over Financial Reporting

In the preparation of our unaudited condensed consolidated financial statements for the IPO, as well as the preparation of our year-end financial statements, we and our independent public accounting firm identified a material weakness in our internal control over financial reporting that impacted the twelve months ended December 31, 2020 and for the nine months ended September 30, 2020 and 2019. During the second quarter of 2021, we continued to implement remediation initiatives in response to the previously identified material weakness in connection with our material weakness remediation plan. As we complete testing over the remediation initiatives we have implemented, we will be able to assess the effectiveness of our remediation plan as noted below.

See “Risk Factors–Emerging Growth Company Risks–We have identified a material weakness in our internal control over financial reporting. We continue to implement remediation initiatives in response to this material weakness. If we identify additional material weaknesses in the future or otherwise fail to maintain an effective system of internal controls, we may not be able to accurately or timely report our financial condition or results of operations, which may adversely affect our business” in our 2020 Annual Report.

Critical Accounting Policies and Estimates

Our unaudited condensed consolidated financial statements are prepared in conformity with GAAP and require our management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, costs and expenses and related disclosures. We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances. Actual results may differ from these estimates, and such estimates may change if the underlying conditions or assumptions change.

Revenue Recognition

Our revenues are comprised of renewable energy and the related Environmental Attribute sales provided under long-term contracts with our customers. All revenue is recognized when we satisfy our performance obligation(s) under the contract (either implicit or explicit) by transferring the promised product to the customer either when (or as) the customer obtains control of the product. A performance obligation is a promise in a contract to transfer a distinct product or service to a customer. A contract’s transaction price is allocated to each distinct performance obligation. We allocate the contract’s transaction price to each performance obligation using the product’s observable market standalone selling price for each distinct product in the contract.

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Revenue is measured as the amount of consideration we expect to receive in exchange for transferring our products. As such, revenue is recorded net of allowances and customer discounts. To the extent applicable, sales, value add, and other taxes collected from customers and remitted to governmental authorities are accounted for on a net (excluded from revenues) basis. The nature of our long-term contracts may give rise to several types of variable consideration, such as periodic price increases. This variable consideration is outside of our control as the variable consideration is dictated by the market.

The nature of the Company’s long-term contracts may give rise to several types of variable consideration, such as periodic price increases. This variable consideration is outside of the Company’s influence as the variable consideration is dictated by the market. Therefore, the variable consideration associated with the long-term contracts is considered fully constrained.

RINs

We generate D3 RINs through our production and sale of RNG used for transportation purposes as prescribed under the RFS program. Our operating costs are associated with the production of RNG. The RINs are generated as an output of our renewable operating projects. The RINs that we generate are able to be separated and sold independently from the energy produced. Therefore, no cost is allocated to the RIN when it is generated. Revenue is recognized on these Environmental Attributes when there is an agreement in place to monetize the credits at an agreed upon price with a customer and transfer of control has occurred. We enter into forward commitments to transfer RINs. These forward commitments are based on D3 RIN index prices at the time of the commitment. Realized prices for RINs monetized in a year may not correspond directly to index prices due to the forward selling of commitments.

RECs

We generate RECs through our production and conversion of landfill methane into Renewable Electricity in various states, including California, Oklahoma, and Texas. These states have various laws requiring utilities to purchase a portion of their energy from renewable resources. Our operating costs are associated with the production of Renewable Electricity. The RECs are generated as an output of our renewable operating projects. The RECs that we generate are able to be separated and sold independently from the electricity produced. Therefore, no cost is allocated to the REC when it is generated. Revenue is recognized on these Environmental Attributes when there is an agreement in place to monetize the credits at an agreed upon price with a customer and transfer of control has occurred.

Income Taxes

We are subject to income taxes in the U.S. federal jurisdiction and various state and local jurisdictions. Tax regulations within each jurisdiction are subject to the interpretation of the related tax laws and regulations and require significant judgment to apply.

Our net deferred tax asset position is a result of net operating losses (“NOLs”), fixed assets, intangibles, and tax credit carryforwards. The realization of deferred tax assets is dependent upon our ability to generate sufficient future taxable income during the periods in which those temporary differences become deductible, prior to the expiration of the tax attributes. The evaluation of deferred tax assets requires judgment in assessing the likely future tax consequences of events that have been recognized in our financial statements or tax returns and forecasting future profitability by tax jurisdiction.

We evaluate our deferred tax assets at reporting periods on a jurisdictional basis to determine whether adjustments to the valuation allowance are appropriate considering changes in facts or circumstances. As of each reporting date, management considers new evidence, both positive and negative, when determining the future realization of our deferred tax assets. We account for uncertain tax positions using a

“more-likely-than-not”

threshold for recognizing and resolving uncertain tax positions. The evaluation of uncertain tax positions is based on factors that include, but are not limited to, changes in tax law, the measurement of tax positions taken or expected to be taken in tax returns, the effective settlement of matters subject to audit, new audit activity and changes in facts or circumstances related to a tax position. Given our current level of

pre-tax

earnings and forecasted future

pre-tax

earnings, we expect to generate income before taxes in the United States in future periods at a level that would fully utilize our U.S. federal NOL carryforwards and the majority of its state NOL carryforwards prior to their expiration.

Intangible Assets

Separately identifiable intangible assets are recorded at their fair values upon acquisition. We account for intangible assets in accordance with ASC 350,

Intangibles—Goodwill and Other

. Finite-lived intangible assets include interconnections, customer contracts, and trade names and trademarks. The interconnection intangible asset is the exclusive right to utilize an interconnection line between the operating project and a utility substation to transmit produced electricity. Included in that right is full maintenance provided on this line by the utility. Intangible assets with finite useful lives are amortized on a straight-line basis over their estimated useful life. We evaluate our finite-lived intangible assets for impairment as events or changes in circumstances indicate the carrying value of these assets may not be fully recoverable. Events that could result in an impairment include, among others, a significant decrease in the market price or the decision to close a site.

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Indefinite-lived intangible assets are not amortized and include emission allowances and land use rights. Emission allowances consist of credits that need to be applied to nitrogen oxide (“NOx”) emissions from internal combustion engines. These engines emit levels of NOx for which environmental permits are required in certain regions in the United States. Except for permanent allocations of NOx credits, allowances available for use each year are capped at a level necessary for ozone attainment per the National Ambient Air Quality Standards. We assess the impairment of intangible assets that have indefinite lives at least on an annual basis or whenever events or changes in circumstances indicate that the carrying value of the asset may not be recoverable.

If finite-lived or indefinite-lived intangible assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. The fair value is determined based on the present value of expected future cash flows. We use our best estimates in making these evaluations, however, actual future pricing, operating costs and discount rates could vary from the assumptions used in our estimates and the impact of such variations could be material.

Finite-Lived Asset Impairment

In accordance with FASB ASC Topic 360, Property, Plant and Equipment and intangible assets with finite useful lives are evaluated for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by comparing the carrying amount of an asset or asset group to future undiscounted cash flows expected to be generated by the asset or asset group. Such estimates are based on certain assumptions, which are subject to uncertainty and may materially differ from actual results, including considering project specific assumptions for long-term credit prices, escalated future project operating costs and expected site operations. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Fair value is generally determined by considering (i) internally developed discounted cash flows for the asset group, (ii) third-party valuations, and/or (iii) information available regarding the current market value for such assets. We use our best estimates in making these evaluations and consider various factors, including future pricing and operating costs. However, actual future market prices and project costs could vary from the assumptions used in our estimates and the impact of such variations could be material.

We recorded impairments of $626 and $278 during the first six months of 2021 and 2020, respectively. See Note 3, “Asset Impairment” to our unaudited condensed consolidated financial statements for more information.

Off-Balance

Sheet Arrangements

Off-balance

sheet arrangements comprise those arrangements that may potentially impact our liquidity, capital resources and results of operations, even though such arrangements are not recorded as liabilities under GAAP. Our

off-balance

sheet arrangements are limited to the outstanding letters of credit described below. Although these arrangements serve a variety of our business purposes, we are not dependent on them to maintain our liquidity and capital resources, and we are not aware of any circumstances that are reasonably likely to cause the

off-balance

sheet arrangements to have a material adverse effect on liquidity and capital resources.

For the first six months of 2021, we had approximately $5,765 of

off-balance

sheet arrangements of outstanding letters of credit. These letters of credit reduce the borrowing capacity of our revolving credit facility under our Amended Credit Agreement. Certain of our contracts require these letters of credit to be issued to provide additional performance assurances. There was no usage against these outstanding letters of credit. During the 2020 period, we did not have

off-balance

sheet arrangements other than outstanding letters of credit of approximately $7,145.

Contractual Obligations

There were no material changes to our significant contractual obligations during the second quarter of 2021 as compared to those previously reported within “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 2020 Annual Report.

Emerging Growth Company

We are an emerging growth company, as defined in the JOBS Act. The JOBS Act allows emerging growth companies to delay the adoption of new or revised accounting standards until such time as those standards apply to private companies. We intend to utilize these transition periods, which may make it difficult to compare our financial statements to those of

non-emerging

growth companies and other emerging growth companies that have opted out of the transition periods afforded under the JOBS Act.

Recent Accounting Pronouncements

For a description of our recently adopted accounting pronouncements and recently issued accounting standards not yet adopted, see Note 2, “Summary of Significant Accounting Policies” of Part I, Item 1 of our unaudited condensed consolidated financial statements in this report.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There have been no material changes since our disclosure in “Quantitative and Qualitative Disclosures About Market Risk” included in Part II, Item 7A of our 2020 Annual Report.

ITEM 4. CONTROLS AND PROCEDURES

Management’s Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the Company’s reports under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and that such information is accumulated and communicated to the Company’s management, including the Company’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosures. Any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. The Company, with the participation of the Company’s Chief Executive Officer and Chief Financial Officer, concluded that, as of June 30, 2021, the Company’s disclosure controls and procedures were not effective, pursuant to Rule

13a-15

and Rule

15d-15

of the Exchange Act, based on the material weakness in internal control over financial reporting described below.

In light of the above, our management, including our Chief Executive Officer and Chief Financial Officer, has performed additional analyses, reconciliations, and other post-closing procedures and has concluded that, notwithstanding the material weakness in our internal control over financial reporting, the unaudited condensed consolidated financial statements for the periods covered by and included in this Quarterly Report on Form

10-Q

fairly present, in all material respects, our financial position, results of operations and cash flows for the periods presented in conformity with GAAP.

Previously Reported Material Weakness

During the preparation of our interim financial statements in connection with our IPO, as well as the preparation of our

year-end

financial statements, we and our independent public accounting firm identified a material weakness in internal control over financial reporting. As defined in Rule

12b-2

under the Exchange Act, a “material weakness” is a deficiency, or combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis. Specifically, we did not have adequate procedures and controls with respect to complete and accurate recording of inputs to the consolidated income tax provision and related accruals.

The identified control deficiencies could have resulted in a misstatement of our accounts or disclosures that could have resulted in a material misstatement of our annual or interim consolidated financial statements that would not be prevented or detected, and accordingly, we determined that these control deficiencies constituted a material weakness. Management has taken remediation activities since the time the material weaknesses were identified; however, the remediated controls were not in place for a sufficient period of time to be tested for their design and operational effectiveness. The material weakness will not be considered remediated until the remediated controls have been operating for a sufficient period of time and can be evidenced through testing that they are operating effectively.

Under “Changes in Internal Control over Financial Reporting” below, we describe our remediation plan to address the identified material weakness.

Changes in Internal Control Over Financial Reporting

There have been changes in our internal control over financial reporting during the quarter ended June 30, 2021 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. During the quarter June 30, 2021, we continued to implement remediation initiatives in response to the previously identified material weakness in connection with our material weakness remediation plan. As we complete testing over the remediation initiatives we have implemented, we will be able to assess the effectiveness of our remediation plan as noted below.

As part of our ongoing remediation initiatives, we continue to implement measures designed to improve our internal control over financial reporting in order to remediate the control deficiencies that led to the material weakness, including outsourcing the parallel preparation and review of our tax calculations and related disclosures by external specialists, and initiating design and implementation of our financial control environment which includes creation of additional controls that are designed to strengthen our review and reconciliation processes around preparation of the annual and interim tax provision and related disclosures. While we believe that these efforts will improve our internal control over financial reporting, the implementation of our remediation is ongoing and will require ongoing validation and testing of the design and operating effectiveness of internal controls.

If the steps we take do not remediate the material weakness in a timely manner, there could continue to be a reasonable possibility that these control deficiencies or others could result in a material misstatement of our annual or interim consolidated financial statements that would not be prevented or detected on a timely basis.

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PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, we and our subsidiaries may be parties to legal proceedings arising in the normal course of our business. We and our subsidiaries are currently not a party, nor is our property subject, to any material pending legal proceedings.

ITEM 1A. RISK FACTORS

We face a number of risks that could materially and adversely affect our business, results of operations, cash flow, liquidity, or financial condition. A discussion of our risk factors can be found in Part I, “Item 1A Risk Factors” in our 2020 Annual Report. The impact of

COVID-19

may exacerbate the risks discussed in Part I, “Item 1A. Risk Factors” in our 2020 Annual Report, any of which could have a material effect on us.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Use of Proceeds from Sale of Registered Securities

On January 21, 2021, our Registration Statement on Form

S-1,

as amended (File

No. 333-251312)

(the “Registration Statement”), was declared effective by the SEC in connection with our IPO. The underwriter for the IPO was Roth Capital Partners. A total of 3,399,515 shares of our common stock were sold pursuant to the Registration Statement, which was comprised of (1) 2,702,500 shares of new common stock issued by the Company and (2) 697,015 shares of the Company’s common stock held by MNK. The 3,399,515 shares were sold at an offering price of $8.50 per share and resulted in net proceeds to the Company of approximately $15.0 million, after deducting the underwriting discount of approximately $1.6 million and offering expenses payable by the Company of approximately $6.2 million.

The IPO closed on January 26, 2021. No payments for such expenses were made directly or indirectly to (i) any of our officers or directors or their associates, (ii) any persons owning 10% or more of any class of our equity securities or (iii) any of our affiliates.

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From the closing of the IPO through June 30, 2021, approximately $4.1 million of the net proceeds from the IPO have been used by Montauk Renewables in connection with due diligence and the consummation of the Montauk Ag Renewables acquisition in May 2021. An immaterial amount has been used relating to other possible acquisitions and projects. The remaining net proceeds of approximately $10.9 is held as cash.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

ITEM 6. EXHIBITS

Exhibit Number	Description
2.1+	Membership Interest and Asset Purchase Agreement, dated May 10, 2021, by and among J.P. Carroll & Co., LLC, Eagle Creek Ranch, L.L.C., NR Nutrient Recovery, LLC, Joseph P. Carroll, Jr., Martin A. Redeker and Montauk Swine Ag, LLC (incorporated by reference to Exhibit 2.1 to our Current Report on Form 8-K (File No. 001-39919), filed on May 11, 2021)
2.2+	Real Estate Purchase and Sale Agreement, dated May 10, 2021, by and among Greensboro Ecosystems, LLC and Montauk Swine Ag, LLC (incorporated by reference to Exhibit 2.2 to our Current Report on Form 8-K (File No. 001-39919), filed on May 11, 2021)
10.1^	Form of Indemnification Agreement between Montauk Renewables, Inc. and each of its directors and executive officers (incorporated by reference to Exhibit 10.1 to our Current Report on Form 8-K (File No. 001-39919), filed June 8, 2021)

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Exhibit Number	Description
31.1	Certification of the Chief Executive Officer Pursuant to Rules 13a-14(a) and 15d-14(a) of the Securities Exchange Act
31.2	Certification of the Chief Financial Officer Pursuant to Rules 13a-14(a) and 15d-14(a) of the Securities Exchange Act
32.1	Certification of the Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2	Certification of the Chief Financial Officer Pursuant to 18 U.S.C. Section 1350, as adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101.INS	Inline XBRL Instance Document
101.SCH	Inline XBRL Taxonomy Extension Schema Document
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

^ Exhibits marked with a (^) are management contracts or compensation plans or arrangements.

+ Exhibits marked with a (+) exclude certain immaterial schedules and exhibits pursuant to the provisions of Regulation S-K, Item 601(a)(5) or Item 601(a)(6). A copy of any of the omitted schedules and exhibits pursuant to Regulation S-K, Item 601(a)(5) will be furnished to the Securities and Exchange Commission upon request.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

August 16, 2021	MONTAUK RENEWABLES, INC.
	By:	/s/ SEAN F. MCCLAIN
		Sean F. McClain
		President, Chief Executive Officer and Director (Principal Executive Officer)
	By:	/s/ KEVIN A. VAN ASDALAN
		Kevin A. Van Asdalan
		Chief Financial Officer (Principal Financial and Accounting Officer)

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