10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2022

☐   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: 001-38770

EPSILON ENERGY LTD.

(Exact name of registrant as specified in its charter)

Alberta, Canada	98-1476367
(State or other jurisdiction of incorporation or organization)	(I.R.S Employer Identification No.)

16945 Northchase Drive, Suite 1610

Houston, Texas 77060

(281) 670-0002

(Address of principal executive offices including zip code and

telephone number, including area code)

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

Title of each class	Trading Symbol	Name of each exchange on which registered
Common Shares, no par value	EPSN	NASDAQ Global 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.

Yes ☐ No ⌧

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No ⌧

As of August 11, 2022, there were 22,975,512 Common Shares outstanding.

Table of Contents

Contents
FORWARD-LOOKING STATEMENTS		4
PART I-FINANCIAL INFORMATION		5
ITEM 1. FINANCIAL STATEMENTS		5
Unaudited Condensed Consolidated Balance Sheets		5
Unaudited Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)		6
Unaudited Condensed Consolidated Statements of Changes in Shareholders’ Equity		7
Unaudited Condensed Consolidated Statements of Cash Flows		9
Notes to the Unaudited Condensed Consolidated Financial Statements		10
1.	Description of Business	10
2.	Basis of Preparation	10
	Interim Financial Statements	10
	Principles of Consolidation	10
	Use of Estimates	10
	Recently Issued Accounting Standards	10
3.	Cash, Cash Equivalents, and Restricted Cash	11
4.	Property and Equipment	12
	Property Impairment	12
5.	Revolving Line of Credit	12
6.	Shareholders’ Equity	13
7.	Revenue Recognition	17
8.	Income Taxes	19
9.	Commitments and Contingencies	19
	Litigation	19
10.	Net Income Per Share	20
11.	Operating Segments	21
12.	Risk Management Activities	23
	Commodity Price Risks	23
	Commodity Derivative Contracts	23
13.	Asset Retirement Obligations	25
14.	Fair Value Measurements	25
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		26
	Overview	26
	Business Strategy	26
	Operational Highlights	26
	Non-GAAP Financial Measures-Adjusted EBITDA	27
	Net Operating Revenues	29
	Operating Costs	30
	Depletion, Depreciation, Amortization and Accretion (“DD&A”)	30
	General and Administrative	31
	Interest Expense	31
	(Loss) Gain on Commodity Contracts	32
	Other Income (Expense)	32
	Capital Resources and Liquidity	32

	Cash Flow	32
	Credit Agreement	33
	Derivative Transactions	34
	Contractual Obligations	34
	Off-Balance Sheet Arrangements	34
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		35
	Gathering System Revenue Risk	35
	Interest Rate Risk	35
	Derivative Contracts	35
ITEM 4. CONTROLS AND PROCEDURES		35
	Disclosure Controls and Procedures	35
	Changes in Internal Control Over Financial Reporting	36
	Inherent Limitations on Effectiveness of Controls	36
PART II OTHER INFORMATION		36
ITEM 1. LEGAL PROCEEDINGS		36
ITEM 1A. RISK FACTORS		36
ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS		37
ITEM 3. DEFAULTS UPON SENIOR SECURITIES		37
ITEM 4. MINE SAFETY DISCLOSURES		37
ITEM 5. OTHER INFORMATION		37
ITEM 6. EXHIBITS		38
SIGNATURES		38

FORWARD-LOOKING STATEMENTS

Certain statements contained in this report constitute forward-looking statements. The use of any of the words ‘‘anticipate,’’ ‘‘continue,’’ ‘‘estimate,’’ ‘‘expect,’’ ‘‘may,’’ ‘‘will,’’ ‘‘project,’’ ‘‘should,’’ ‘‘believe,’’ and similar expressions and statements relating to matters that are not historical facts constitute ‘‘forward looking information’’ within the meaning of applicable securities laws. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated. Such forward-looking statements are based on reasonable assumptions, but no assurance can be given that these expectations will prove to be correct and the forward-looking statements included in this report should not be unduly relied upon. These statements are made only as of the date of this report. All statements that address operating performance, events or developments that we expect or anticipate will occur in the future — including statements relating to natural gas and oil production rates, commodity prices for crude oil or natural gas, supply and demand for natural gas and oil; the estimated quantity of natural gas and oil reserves, including reserve life; future development and production costs, and statements expressing general views about future operating results — are forward-looking statements. Management believes that these forward-looking statements are reasonable as and when made. However, caution should be taken not to place undue reliance on any such forward-looking statements because such statements speak only as of the date when made. We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as required by law. In addition, forward-looking statements are subject to certain risks and uncertainties that could cause actual results to differ materially from our present expectations or projections. These risks and uncertainties include, but are not limited to, those described in our Annual Report on Form 10-K for the year ended December 31, 2021, and those described from time to time in our future reports filed with the Securities and Exchange Commission. You should consider carefully the statements under Item 1A. Risk Factors included in our Annual Report on Form 10-K for the year ended December 31, 2021. Our Annual Report on Form 10-K for the year ended December 31, 2021 is available on our website at www.epsilonenergyltd.com.

4

PART I-FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Balance Sheets

	June 30,		December 31,
	2022		2021
ASSETS
Current assets
Cash and cash equivalents	$	30,945,605	$	26,497,305
Accounts receivable		9,930,891		4,596,931
Fair value of derivatives		940,553		—
Other current assets		240,998		569,870
Total current assets		42,058,047		31,664,106
Non-current assets
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties		145,697,537		138,032,413
Unproved properties		18,021,391		21,700,926
Accumulated depletion, depreciation, amortization and impairment		(105,047,754)		(102,480,972)
Total oil and gas properties, net		58,671,174		57,252,367
Gathering system		42,566,495		42,475,086
Accumulated depletion, depreciation, amortization and impairment		(33,995,327)		(33,443,949)
Total gathering system, net		8,571,168		9,031,137
Land		637,764		637,764
Buildings and other property and equipment, net		292,727		309,102
Total property and equipment, net		68,172,833		67,230,370
Other assets:
Restricted cash		569,407		568,118
Total non-current assets		68,742,240		67,798,488
Total assets	$	110,800,287	$	99,462,594
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Accounts payable trade	$	1,786,570	$	1,189,905
Gathering fees payable		1,052,168		963,546
Royalties payable		2,471,969		1,853,508
Income taxes payable		2,410,790		1,098,425
Accrued capital expenditures		224,179		1,016,830
Other accrued liabilities		834,779		1,098,127
Fair value of derivatives		—		239,824
Asset retirement obligations		—		85,207
Total current liabilities		8,780,455		7,545,372
Non-current liabilities
Asset retirement obligations		2,735,965		2,748,449
Deferred income taxes		10,224,766		9,905,440
Total non-current liabilities		12,960,731		12,653,889
Total liabilities		21,741,186		20,199,261
Commitments and contingencies (Note 9)
Shareholders' equity
Common shares, no par value, unlimited shares authorized and 23,356,453 issued and 23,082,353 outstanding at June 30, 2022 and 24,202,218 issued and 23,668,203 shares outstanding at December 31, 2021		127,093,520		131,815,739
Treasury shares, 274,100 at June 30, 2022 and 534,015 at December 31, 2021		(1,646,823)		(2,423,007)
Additional paid-in capital		9,171,555		8,835,203
Accumulated deficit		(55,364,008)		(68,783,207)
Accumulated other comprehensive income		9,804,857		9,818,605
Total shareholders' equity		89,059,101		79,263,333
Total liabilities and shareholders' equity	$	110,800,287	$	99,462,594

The accompanying notes are an integral part of these interim unaudited condensed consolidated financial statements

5

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Revenues from contracts with customers:
Gas, oil, NGL, and condensate revenue	$	17,915,836	$	5,238,754	$	29,395,161	$	11,677,909
Gas gathering and compression revenue		1,987,168		1,851,095		4,107,941		3,853,252
Total revenue		19,903,004		7,089,849		33,503,102		15,531,161
Operating costs and expenses:
Lease operating expenses		2,621,750		1,784,138		4,392,404		3,378,327
Gathering system operating expenses		171,495		173,547		330,706		364,494
Development geological and geophysical expenses		2,386		11,451		4,772		22,990
Depletion, depreciation, amortization, and accretion		1,803,739		1,646,094		3,192,958		3,328,954
Gain on sale of oil and gas properties		(221,642)		—		(221,642)		—
General and administrative expenses:
Stock based compensation expense		194,050		236,041		336,352		438,540
Other general and administrative expenses		1,465,143		2,048,300		2,636,275		3,375,461
Total operating costs and expenses		6,036,921		5,899,571		10,671,825		10,908,766
Operating income		13,866,083		1,190,278		22,831,277		4,622,395
Other income (expense):
Interest income		21,945		8,904		37,166		16,717
Interest expense		(745)		(22,345)		(16,064)		(49,418)
Gain (loss) on derivative contracts		776,994		(1,827,334)		(194,910)		(1,361,993)
Other (expense) income		(61,713)		(279)		(67,119)		1,663
Other income (expense), net		736,481		(1,841,054)		(240,927)		(1,393,031)
Net income (loss) before income tax expense		14,602,564		(650,776)		22,590,350		3,229,364
Income tax expense (benefit)		4,019,576		(165,751)		6,201,474		978,822
NET INCOME (LOSS)	$	10,582,988	$	(485,025)	$	16,388,876	$	2,250,542
Currency translation adjustments		(19,150)		242		(13,748)		(1,242)
NET COMPREHENSIVE INCOME (LOSS)	$	10,563,838	$	(484,783)	$	16,375,128	$	2,249,300
Net income (loss) per share, basic	$	0.45	$	(0.02)	$	0.69	$	0.09
Net income (loss) per share, diluted	$	0.44	$	(0.02)	$	0.69	$	0.09
Weighted average number of shares outstanding, basic		23,576,746		23,779,205		23,627,015		23,862,749
Weighted average number of shares outstanding, diluted		23,822,123		23,779,205		23,796,166		23,941,340

The accompanying notes are an integral part of these interim unaudited condensed consolidated financial statements

6

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Changes in Shareholders’ Equity

									Accumulated
									Other				Total
	Common Shares Issued			Treasury Shares			Additional		Comprehensive		Accumulated		Shareholders'
	Shares	Amount		Shares	Amount		paid-in Capital		Income		Deficit		Equity
Balance at January 1, 2022	24,202,218	$	131,815,739	(534,015)	$	(2,423,007)	$	8,835,203	$	9,818,605	$	(68,783,207)	$	79,263,333
Net income	—		—	—		—		—		—		5,805,888		5,805,888
Dividends	—		—	—		—		—		—		(1,483,027)		(1,483,027)
Stock-based compensation expenses	—		—	—		—		142,302		—		—		142,302
Exercise of stock options	38,750		209,312	—		—		—		—		—		209,312
Retirement of treasury shares	(534,015)		(2,423,007)	534,015		2,423,007		—		—		—		—
Other comprehensive income	—		—	—		—		—		5,402		—		5,402
Balance at March 31, 2022	23,706,953	$	129,602,044	—	$	—	$	8,977,505	$	9,824,007	$	(64,460,346)	$	83,943,210
Net income	—		—	—		—		—		—		10,582,988		10,582,988
Dividends	—		—	—		—		—		—		(1,486,650)		(1,486,650)
Stock-based compensation expenses	—		—	—		—		194,050		—		—		194,050
Exercise of stock options	72,500		399,475	—		—		—		—		—		399,475
Buyback of common shares	—		—	(697,100)		(4,554,822)		—		—		—		(4,554,822)
Retirement of treasury shares	(423,000)		(2,907,999)	423,000		2,907,999		—		—		—		—
Other comprehensive loss	—		—	—		—		—		(19,150)		—		(19,150)
Balance at June 30, 2022	23,356,453	$	127,093,520	(274,100)	$	(1,646,823)	$	9,171,555	$	9,804,857	$	(55,364,008)	$	89,059,101

The accompanying notes are an integral part of these interim unaudited condensed consolidated financial statements

7

									Accumulated
									Other				Total
	Common Shares Issued			Treasury Shares			Additional		Comprehensive		Accumulated		Shareholders'
	Shares	Amount		Shares	Amount		paid-in Capital		Income		Deficit		Equity
Balance at January 1, 2021	23,985,799	$	131,730,401	—	$	—	$	7,879,119	$	9,820,647	$	(80,410,724)	$	69,019,443
Net income	—		—	—		—		—		—		2,735,567		2,735,567
Stock-based compensation expenses	—		—	—		—		202,499		—		—		202,499
Buyback of common shares	—		—	(123,200)		(492,479)		—		—		—		(492,479)
Other comprehensive income	—		—	—		—		—		242		—		242
Balance at March 31, 2021	23,985,799		131,730,401	(123,200)		(492,479)		8,081,618		9,820,889		(77,675,157)	$	71,465,272
Net loss	—		—	—		—		—		—		(485,025)		(485,025)
Stock-based compensation expenses	—		—	—		—		236,041		—		—		236,041
Buyback of common shares	—		—	(141,015)		(568,989)		—		—		—		(568,989)
Other comprehensive loss	—		—	—		—		—		(1,484)		—		(1,484)
Balance at June 30, 2021	23,985,799		131,730,401	(264,215)		(1,061,468)		8,317,659		9,819,405		(78,160,182)	$	70,645,816

The accompanying notes are an integral part of these interim unaudited condensed consolidated financial statements

8

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Cash Flows

	Six months ended June 30,
	2022		2021
Cash flows from operating activities:
Net income	$	16,388,876	$	2,250,542
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion		3,192,958		3,328,954
Loss on derivative contracts		194,910		1,361,993
Gain on sale of oil and gas properties		(221,642)		—
Settlement paid on derivative contracts		(1,375,287)		(27,460)
Settlement of asset retirement obligation		(118,259)		(3,483)
Stock-based compensation expense		336,352		438,540
Deferred income tax expense		319,326		230,863
Changes in assets and liabilities:
Accounts receivable		(5,333,960)		388,912
Prepaid income taxes and other current assets		328,872		(12,476)
Accounts payable, royalties payable and other accrued liabilities		738,023		77,248
Income taxes payable		1,312,365		—
Net cash provided by operating activities		15,762,534		8,033,633
Cash flows from investing activities:
Additions to unproved oil and gas properties		(162,445)		(70,058)
Additions to proved oil and gas properties		(4,935,370)		(1,557,869)
Additions to gathering system properties		(82,855)		(79,419)
Additions to land, buildings and property and equipment		(1,234)		(5,745)
Proceeds from sale of oil and gas properties		200,000		—
Prepaid drilling costs		—		273
Net cash used in investing activities		(4,981,904)		(1,712,818)
Cash flows from financing activities:
Buyback of common shares		(3,956,403)		(1,061,468)
Exercise of stock options		608,787		—
Dividends		(2,969,677)		—
Net cash used in financing activities		(6,317,293)		(1,061,468)
Effect of currency rates on cash, cash equivalents and restricted cash		(13,748)		(1,242)
Increase in cash, cash equivalents and restricted cash		4,449,589		5,258,105
Cash, cash equivalents and restricted cash, beginning of period		27,065,423		13,836,771
Cash, cash equivalents and restricted cash, end of period	$	31,515,012	$	19,094,876
Supplemental cash flow disclosures:
Income taxes paid	$	4,566,000	$	1,074,025
Interest paid	$	33,885	$	27,073
Non-cash investing activities:
Change in unproved properties accrued in accounts payable and accrued liabilities	$	—	$	(65,000)
Change in proved properties accrued in accounts payable and accrued liabilities	$	(1,097,247)	$	805,443
Change in gathering system accrued in accounts payable and accrued liabilities	$	8,554	$	(8,915)
Change in prepaid drilling costs	$	—	$	979,358
Asset retirement obligation asset additions and adjustments	$	7,666	$	(29,853)
Non-cash financing activities:
Change in share buybacks accrued in accounts payable and accrued liabilities	$	598,419	$	—

The accompanying notes are an integral part of these interim unaudited condensed consolidated financial statements

9

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

1. Description of Business

Epsilon Energy Ltd. (the “Company” or “Epsilon” or “we”) was incorporated under the laws of the Province of Alberta, Canada on March 14, 2005. On October 24, 2007, the Company became a publicly traded entity trading on the Toronto Stock Exchange (“TSX”) in Canada. On February 14, 2019, Epsilon’s registration statement on Form 10 was declared effective by the United States Securities and Exchange Commission and on February 19, 2019, the Company began trading in the United States on the NASDAQ Global Market under the trading symbol “EPSN.” Effective as of the close of trading on March 15, 2019 Epsilon voluntarily delisted its common shares from the TSX. The Company is engaged in the acquisition, development, gathering and production of primarily natural gas reserves in the United States.

2. Basis of Preparation

Interim Financial Statements

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and with the appropriate rules and regulations of the SEC. Accordingly, certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. All adjustments which are, in the opinion of management, necessary for a fair presentation of the financial position and results of operations for the interim periods presented have been included. The interim financial information and notes hereto should be read in conjunction with the Company’s consolidated financial statements as of and for the year ended December 31, 2021. The results of operations for interim periods are not necessarily indicative of results to be expected for a full fiscal year.

Principles of Consolidation

The Company’s unaudited condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiary, Epsilon Energy USA, Inc. and its wholly owned subsidiaries, Epsilon Midstream, LLC, Dewey Energy GP, LLC, Dewey Energy Holdings, LLC, Epsilon Operating, LLC, and Altolisa Holdings, LLC. With regard to the gathering system, in which Epsilon owns an undivided interest in the asset, proportionate consolidation accounting is used. All inter-company transactions have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The most significant estimates pertain to proved natural gas and oil reserves and related cash flow estimates used in impairment tests of natural gas and oil, and gathering system properties, asset retirement obligations, accrued natural gas and oil revenues and operating expenses, accrued gathering system revenues and operating expenses, as well as the valuation of commodity derivative instruments. Actual results could differ from those estimates.

Recently Issued Accounting Standards

The Company, an emerging growth company (“EGC”), has elected to take advantage of the benefits of the extended transition period provided for in Section 7(a)(2)(B) of the Securities Act, for complying with new or revised accounting standards which allows the Company to defer adoption of certain accounting standards until those standards would otherwise apply to private companies.

In March 2020, the FASB issued ASU No. 2020-04 - Reference Rate Reform (Topic 848), codified as ASC 848 (“ASC 848”). This was followed by ASU No. 2021-01, Reference Rate Reform (Topic 848): Scope (“ASU 2021-01”), issued in January 2021. The purpose of ASC 848 is to provide optional guidance to ease the potential effects on financial

10

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

reporting of the market-wide migration away from Interbank Offered Rates (“IBORs”) to alternative reference rates. ASC 848 applies only to contracts, hedging relationships, and other transactions that reference a reference rate expected to be discontinued because of reference rate reform. The guidance may be applied upon issuance of ASC 848 through December 31, 2022. We do not expect a material impact from the adoption of this ASU.

In June 2016 the FASB issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, which removes the thresholds that companies apply to measure credit losses on financial instruments measured at amortized cost, such as loans, receivables, and held-to-maturity debt securities. Under current U.S. GAAP, companies generally recognize credit losses when it is probable that the loss has been incurred. The revised guidance will remove all recognition thresholds and will require companies to recognize an allowance for credit losses for the difference between the amortized cost basis of a financial instrument and the amount of amortized cost that the Company expects to collect over the instrument’s contractual life. ASU 2016-13 is effective for fiscal years beginning after December 15, 2022, and interim periods within those fiscal years, and must be applied retrospectively. Early adoption is permitted. Epsilon will adopt ASU 2016-13 as of January 1, 2023.

In February 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, Leases (Topic 842), which will require lessees to recognize a right of use asset and a lease liability on their balance sheet for all leases, including operating leases, with a term of greater than 12 months. In July 2018, the FASB issued ASU 2018-11, which adds a transition option permitting entities to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the consolidated financial statements. Under this transition option, comparative reporting would not be required, and the provisions of the standard would be applied prospectively to leases in effect at the date of adoption.

The Company has determined its portfolio of leased assets and is completing its review of all related contracts to determine the impact the adoption will have on its consolidated financial statements and related disclosures. Upon adoption, the Company will recognize a right of use asset and lease liability for certain commitments related to office space that will be accounted for as an operating lease. To track these lease arrangements and facilitate compliance with this ASU, the Company is in the process of designing processes and internal controls.

The adoption of this ASU will increase asset and liability balances on the consolidated balance sheets due to the required recognition of a right of use asset and corresponding lease liabilities and will result in changes to the Company’s existing accounting policies, business processes, and internal controls. The Company plans to elect the available package practical expedients provided in the standard and adopt Topic 842 as of January 1, 2022 at December 31, 2022 on its Form 10-K for the year ending December 31, 2022, using the optional transition method provided by ASU 2018-11 and continues to assess potential effects of the standard.

3. Cash, Cash Equivalents, and Restricted Cash

Cash and cash equivalents include cash on hand and short term, highly liquid investments with original maturities of three months or less that are readily convertible to known amounts of cash and which are subject to an insignificant risk of changes in value.

Restricted cash consists of amounts deposited to back bonds or letters of credit for potential well liabilities. The Company presents restricted cash with cash and cash equivalents in the Consolidated Statements of Cash Flows.

11

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported in the Consolidated Balance Sheets to the total of the amounts in the Consolidated Statements of Cash Flows as of June 30, 2022 and December, 31 2021:

	June 30,		December 31,
	2022		2021
Cash and cash equivalents	$	30,945,605	$	26,497,305
Restricted cash included in other assets		569,407		568,118
Cash, cash equivalents and restricted cash in the statement of cash flows	$	31,515,012	$	27,065,423

4.  Property and Equipment

The following table summarizes the Company’s property and equipment as of June 30, 2022 and December 31, 2021:

	June 30,		December 31,
	2022		2021
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	145,697,537	$	138,032,413
Unproved properties		18,021,391		21,700,926
Accumulated depletion, depreciation, amortization and impairment		(105,047,754)		(102,480,972)
Total oil and gas properties, net		58,671,174		57,252,367
Gathering system		42,566,495		42,475,086
Accumulated depletion, depreciation, amortization and impairment		(33,995,327)		(33,443,949)
Total gathering system, net		8,571,168		9,031,137
Land		637,764		637,764
Buildings and other property and equipment, net		292,727		309,102
Total property and equipment, net	$	68,172,833	$	67,230,370

Property Impairment

Epsilon performs a quantitative impairment test quarterly or whenever events or changes in circumstances indicate that an asset group's carrying amount may not be recoverable, over proved properties using the published NYMEX forward prices, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, GAAP requires that the Company first compares expected future undiscounted cash flows by asset group to their respective carrying values. If the carrying amount exceeds the estimated undiscounted future cash flows, a reduction of the carrying amount of the oil and natural gas properties to their estimated fair values is required, which is determined based on discounted cash flow techniques using significant assumptions including projected revenues, future commodity prices, and a market-specific weighted average cost of capital which are affected by expectations about future market and economic conditions. During the three and six months ended June 30, 2022 and 2021, no impairment was required.

5. Revolving Line of Credit

The Company has a senior secured revolving credit facility (“Facility”) which includes a total commitment of up to $100 million. The current borrowing base is $14 million, which is subject to semi-annual redetermination. There are currently no borrowings under the Facility. If Epsilon decided to access the Facility, depending on the level of borrowing, the Company might need to increase its hedging activity. Borrowings from the Facility may be used for the acquisition and development of oil and gas properties, investments in cash flow generating assets complimentary to the production of oil and gas, and for letters of credit and other general corporate purposes. Upon each advance, interest is charged at the highest of a) rate of LIBOR plus an applicable margin (2.75%-3.75% based on the percent of the line of credit utilized), b) the Prime Rate, or c) the sum of the Federal Funds Rate plus 0.5%.

12

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Effective April 6, 2021, the agreement was amended to extend the maturity date to March 1, 2024. In addition, the agreement was amended to include a Benchmark Replacement definition and transition plan to be used at such time when the LIBOR rate is discontinued.

On August 2, 2022, the borrowing base of $14 million was reaffirmed until the next periodic redetermination of the borrowing base.

The lender under the Credit Facility has a first priority security interest in the tangible and intangible assets, including the gathering system, of Epsilon Energy USA, Inc. to secure any outstanding amounts under the agreement. Under the terms of the agreement, the Company must maintain the following covenants:

● Interest coverage ratio greater than 3 based on income adjusted for interest, taxes and non-cash amounts.

● Current ratio, adjusted for line of credit amounts used and available and non-cash amounts, greater than 1.

● Leverage ratio less than 3.0 based on income adjusted for interest, taxes and non-cash amounts.

The Company was in compliance with the financial covenants of the Credit Facility as of June 30, 2022 and expects to be in compliance with the financial covenants for the next 12 months.

A commitment fee of 0.50% is assessed quarterly on the daily average unused borrowing base on the Credit Facility.

	Balance at		Balance at
	June 30,		December 31,		Current		Interest Rate
	2022		2021		Borrowing Base		3 mo.
Revolving line of credit	$	—	$	—	$	14,000,000		LIBOR + 3.25% (1)

(1) At June 30, 2022, the interest rate was 4.876%.

6. Shareholders’ Equity

(a)Authorized shares

The Company is authorized to issue an unlimited number of Common Shares with no par value and an unlimited number of Preferred Shares with no par value.

(b)Purchases of Equity Shares

Normal Course Issuer Bid

Commencing on March 8, 2022, the Company conducted a normal course issuer bid (“NCIB”) to repurchase our issued and outstanding common shares, when doing so was accretive to management’s estimates of intrinsic value per share. The NCIB ends on March 7, 2023. The Company uses discretionary cash to fund these repurchases. During the six months ended June 30, 2022, Epsilon repurchased 697,100 common shares of the authorized 1,183,410 purchase amount and spent $4,554,822 under the NCIB. The repurchased stock had an average price of $6.53 per share. The Company cancelled 423,000 common shares during the three months ended June 30, 2022.

Commencing on January 1, 2021, Epsilon conducted a normal course issuer bid (“NCIB”) to repurchase our issued and outstanding common shares, when doing so was accretive to management's estimates of intrinsic value per share. The NCIB ended on December 31, 2021. The Company used discretionary cash to fund these repurchases. During the year ended December 31, 2021, Epsilon repurchased 534,015 common shares of the authorized 1,193,000 purchase

13

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

amount and spent $2,423,007 under the NCIB. The repurchased stock had an average price of $4.54 per share and were subsequently cancelled during the three months ended March 31, 2022.

Repurchases may be made at management’s discretion from time to time through the facilities of the NASDAQ Global Market. The price paid for the common shares will be, subject to applicable securities laws, the prevailing market price of such common shares on the NASDAQ Global Market at the time of such purchase. The Company intends to fund the purchase out of available cash and does not expect to incur debt to fund the share repurchase program. The shares are accounted for as treasury shares until such a time as they are cancelled.

The following table contains activity relating to our acquisition of equity securities during the six months ended June 30, 2022:

				Maximum number
				of shares that
				may yet be
	Total number	Average price		purchased under
	of shares	paid per		the plans or
	purchased	share		programs
Beginning of normal-course issuer bid, March 8, 2022					1,183,410
March 2022 (1)	—	$	—
April 2022 (1)	23,700	$	6.66
May 2022 (1)	254,500	$	7.01
June 2022 (1)	418,900	$	6.24
Total as of June 30, 2022	697,100	$	6.53		486,310

(1) Epsilon repurchased these shares under its share repurchase program that commenced on March 8, 2022, as described above.

(c)Equity Incentive Plan

Epsilon’s board of directors (the “Board”) adopted the 2020 Equity Incentive Plan (the “2020 Plan”) on July 22, 2020 subject to approval by Epsilon’s shareholders at Epsilon’s 2020 Annual General and Special Meeting of Shareholders, which occurred on September 1, 2020 (the “Meeting”). Shareholders approved the 2020 Plan at the Meeting. Following Epsilon’s listing on the NASDAQ Global Market, the Board determined that it is in the best interest of the shareholders to approve a new incentive plan that is compliant with U.S. public company equity plan rules and practices that would replace Epsilon’s Amended and Restated 2017 Stock Option Plan (including its predecessors) and the Share Compensation Plan (collectively referred to as the “Predecessor Plans”). No further awards will be granted under the Predecessor Plans.

The 2020 Plan provides for incentive compensation in the form of stock options, stock appreciation rights, restricted stock and stock units, performance shares and units, other stock-based awards and cash-based awards. Under the 2020 Plan, Epsilon will be authorized to issue up to 2,000,000 Common Shares. As of December 31, 2021, the Company granted, after the Compensation Committee approved the terms, target formulas, and peer group applicable to the performance incentive awards, 20,834 common shares and 48,000 time-based restricted shares to the CEO and the board of directors.

Restricted Stock Awards

For the six months ended June 30, 2022, 89,925 shares of Restricted Stock with a weighted average market price at the grant date of $6.33 were awarded to the Company’s board of directors and employees. For the year ended December 31, 2021, 48,000 common shares of Restricted Stock with a weighted average market price at the grant date of $5.04 were awarded to the Company’s board of directors. These shares vest over a three-year period, with one-third of the shares

14

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

being issued per period on the anniversary of the award resolution. The vesting of the shares is contingent on the individuals’ continued employment or service. The Company determined the fair value of the granted Restricted Stock-based on the market price of the common shares of the Company on the date of grant.

The following table summarizes Restricted Stock activity for the six months ended June 30, 2022, and the year ended December 31, 2021:

	Six months ended		Year ended
	June 30, 2022		December 31, 2021
	Number of	Weighted	Number of	Weighted
	Restricted	Average	Restricted	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested Restricted Stock at beginning of period	166,002	1.38	290,070	1.60
Granted	89,925	1.50	48,000	3.00
Vested	—	—	(137,668)	—
Forfeited	—	—	(34,400)	—
Balance non-vested Restricted Stock at end of period	255,927	1.10	166,002	1.38

Stock compensation expense for the granted Restricted Stock is recognized over the vesting period. Stock compensation expense recognized during the three and six months ended June 30, 2022 was $146,860 and $241,972, respectively (for the three and six months ended June 30, 2021, $137,207 and $274,413, respectively).

At June 30, 2022, the Company had unrecognized stock-based compensation related to these shares of $931,239 to be recognized over a weighted average period of 1.19 years (at December 31, 2021: $696,833 over 1.11 years).

Performance Share Unit Awards (“PSU”)

For the six months ended June 30, 2022, no PSUs were awarded. For the year ended December 31, 2021, a total of 62,501 common shares vested and were issued, of which 20,834 of the common shares were granted as a result of the Company exceeding its 2020 TSR performance target. The Company grants PSUs, which are paid in stock, to certain key employees. PSUs are based on a three-year performance period with performance being measured each year at December 31. The PSUs will vest on the last day of the performance period. The number of PSUs that will ultimately vest is based on two performance targets as follows:

● The targets for the PSUs are based on (i) the relative total stockholder return (“TSR”) percentile ranking and (ii) the relative cash flow per debt adjusted share – growth (“CFDAS Growth”) percentile ranking of the Company, each as compared to the Company’s Performance Peer Group during the applicable one-year performance period ending on December 31.

● Cash Flow per Debt Adjusted Share (“CFDAS”) is defined as EBITDA (earnings before interest, taxes, depreciation and amortization) divided by the sum of the 1) the total debt plus the value of preferred stock minus cash and the amount of dividends paid for the year divided by the share price at the end of the year; and 2) the actual share count at year end.

● The vesting of each PSU Award will be based 50% on TSR performance and 50% based on CFDAS Growth performance.

● The recipient of the award must be employed with the Company at the time of vesting.

The number of shares ultimately issued under these awards can range from zero to 200% of target award amounts.

15

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

The PSUs are accounted for as equity awards. The fair value of the 50% for performance based on CFDAS Growth was determined as the market price of the common shares of the Company on the date of grant. Weighted average fair value of CFDAS PSUs granted during the year ended December 31, 2021 was $3.41 per unit. The fair value of the 50% for performance based on TSR was determined on the grant date by the application of a Monte Carlo simulation model.  For the year ended December 31, 2021, the Compensation Committee did not approve the issuance of any new PSU’s.

The Monte Carlo simulation model utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the performance stock awards, to calculate the fair value of the awards. Expected volatilities in the model were estimated using a historical period consistent with the expected term for each annual performance period of the awards. The risk-free interest rate was based on the United States Treasury rate measured over a term commensurate with the expected term for each annual performance period of the awards. The expected term is based on the time between the valuation date and the end of each annual performance period of the awards. The valuation model assumes dividends are immediately reinvested.

The following table summarizes PSUs for the six months ended June 30, 2022 and the year ended December 31, 2021:

	Six months ended		Year ended
	June 30, 2022		December 31, 2021
	Number of	Weighted	Number of	Weighted
	Performance	Average	Performance	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested PSUs at beginning of period	151,500	0.75	193,167	1.60
Granted	—	—	20,834	—
Vested	—	—	(62,501)	—
Balance non-vested PSUs at end of period	151,500	0.59	151,500	0.75

Stock compensation expense for the granted PSUs is recognized over the vesting period. Stock compensation expense recognized during the three and six months ended June 30, 2022 related to PSUs was $47,190 and $94,380, respectively (for the three and six months ended June 30, 2021, $98,835 and $164,127, respectively.

At June 30, 2022, the Company had unrecognized stock-based compensation related to these shares of $213,035 to be recognized over a weighted average period of 0.83 years (at December 31, 2021: $310,790 over 1.01 years).

Stock Options

As of June 30, 2022, the Company had outstanding stock options covering 97,500 Common Shares at an overall average exercise price of $5.03 per Common Share to directors, officers, and employees of the Company and its subsidiaries. These 97,500 options have a weighted average expected remaining term of approximately 1.56 years.

16

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

The following table summarizes stock option activity for the six months ended June 30, 2022 and the year ended December 31, 2021:

	Six months ended			Year ended
	June 30, 2022			December 31, 2021
		Weighted				Weighted
	Number of	Average		Number of		Average
	Options	Exercise		Options		Exercise
Exercise price in US$	Outstanding	Price		Outstanding		Price (1)
Balance at beginning of period	218,750	$	5.28		245,000	$	5.27
Exercised	(111,250)	$	5.47		(16,250)	$	5.25
Expired/Forfeited	(10,000)	$	5.51		(10,000)	$	5.50
Balance at period-end	97,500	$	5.03		218,750	$	5.28
Exercisable at period-end	97,500	$	5.03		218,750	$	5.28

At June 30, 2022, using the Black Scholes model, the Company had unrecognized stock-based compensation, related to these options, of nil (at December 31, 2021: nil). The aggregate intrinsic value at June 30, 2022 was $83,850 (at December 31, 2021: nil).

During the six months ended June 30, 2022 and the year ended December 31, 2021, the Company awarded no stock options.

(d) Dividends

On February 25, 2022 and May 26, 2022, the Board declared quarterly dividends of $0.0625 per common share (annualized $0.25 per common share) totaling in aggregate an amount of approximately $3.0 million that has been paid for the six months ended June 30, 2022.

7. Revenue Recognition

Revenues are comprised primarily of sales of natural gas along with the revenue generated from the Company’s ownership interest in the Auburn gas gathering system in Northeastern Pennsylvania. Also included are natural gas, crude oil and NGL revenues from Oklahoma.

Overall, product sales revenue generally is recorded in the month when contractual delivery obligations are satisfied, which occurs when control is transferred to the Company’s customers at delivery based on contractual terms and conditions. In addition, gathering and compression revenue generally is recorded in the month when contractual service obligations are satisfied, which occurs as control of those services is transferred to the Company’s customers.

The following table details revenue for the three and six months ended June 30, 2022 and 2021.

	Three months ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Operating revenue
Natural gas	$	15,984,348	$	5,106,922	$	26,687,432	$	11,439,021
Natural gas liquids		688,397		52,529		1,002,825		98,150
Oil and condensate		1,243,091		79,303		1,704,904		140,738
Gathering and compression fees		1,987,168		1,851,095		4,107,941		3,853,252
Total operating revenue	$	19,903,004	$	7,089,849	$	33,503,102	$	15,531,161

17

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Product Sales Revenue

The Company enters into contracts with third party purchasers to sell its natural gas, oil, NGLs and condensate production. Under these product sales arrangements, the sale of each unit of product represents a distinct performance obligation. Product sales revenue is recognized at the point in time that control of the product transfers to the purchaser based on contractual terms which reflect prevailing commodity market prices. To the extent that marketing costs are incurred by the Company prior to the transfer of control of the product, those costs are included in lease operating expenses on the Company’s consolidated statements of operations.

Settlement statements for product sales, and the related cash consideration, are received from the purchaser within 30 days. As a result, the Company must estimate the amount of production delivered to the customer and the consideration that will ultimately be received for sale of the natural gas, oil, NGLs, or condensate. Estimated revenue due to the Company is recorded within the receivables line item on the accompanying consolidated balance sheets until payment is received.

Gas Gathering and Compression Revenue

The Company also provides natural gas gathering and compression services through its ownership interest in the Auburn gas gathering system. For the provision of gas gathering and compression services, the Company collects its share of the gathering and compression fees per unit of gas serviced and recognizes gathering revenue over time using an output method based on units of gas gathered.

The settlement statement from the operator of the Auburn Gas Gathering System is received two months after transmission and compression has occurred. As a result, the Company must estimate the amount of production that was transmitted and compressed within the system. Estimated revenue due to the Company is recorded within the receivables line item on the accompanying consolidated balance sheets until payment is received.

Allowance for Doubtful Accounts

The Company records an allowance for doubtful accounts on a case-by-case basis once there is evidence that collection is not probable. For the three and six months ended June 30, 2022, there were no accounts for which collection was not probable.

The following table details accounts receivable as of June 30, 2022 and December 31, 2021.

	June 30,		December 31,
	2022		2021
Accounts receivable
Natural gas and oil sales	$	8,339,473	$	2,996,344
Joint interest billing		21,381		60,134
Gathering and compression fees		1,435,391		1,539,976
Other		134,646		477
Total accounts receivable	$	9,930,891	$	4,596,931

18

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

8. Income Taxes

Income tax provisions for the three and six months ended June 30, 2022 and 2021 are as follows:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Current:
Federal	$	2,530,805	$	319,557	$	3,997,702	$	474,927
State		1,192,131		89,188		1,884,446		273,032
Total current income tax expense		3,722,936		408,745		5,882,148		747,959
Deferred:
Federal		233,599		(451,044)		255,614		212,159
State		63,041		(123,452)		63,712		18,704
Total deferred tax expense		296,640		(574,496)		319,326		230,863
Income tax expense	$	4,019,576	$	(165,751)	$	6,201,474	$	978,822

The Company files federal income tax returns in the United States and Canada, and various returns in state and local jurisdictions.

The Company believes it has appropriate support for the income tax positions taken and to be taken on our tax returns and that the accruals for tax liabilities are adequate for all open years based on our assessment of various factors including past experience and interpretations of tax law applied to the facts of each matter. The Company's tax returns are open to audit under the statute of limitations for the years ending December 31, 2018 through December 31, 2021. To the extent we utilize net operating losses generated in earlier years, such earlier years may also be subject to audit.

Our effective tax rate will typically differ from the statutory federal rate primarily as a result of state income taxes and the valuation allowance against the Canadian net operating loss. The effective tax rate for the six months ended June 30, 2022 was higher than the statutory federal rate as a result of the state income taxes and the valuation allowance against the Canadian net operating loss.

9. Commitments and Contingencies

The Company’s future minimum lease commitments as of June 30, 2022 are summarized in the following table:

Year ended
December 31,	Payments
2022	$	93,666
2023		62,444
	$	156,110

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of June 30, 2022, the Company had commitments of $1.5 million for capital expenditures.

Litigation

On March 10, 2021, Epsilon filed a complaint against Chesapeake Appalachia, LLC (“Chesapeake”) in the United States District Court for the Middle District of Pennsylvania, Scranton, Pennsylvania (“Middle District”). Epsilon claims that Chesapeake has breached a settlement agreement and several operating agreements (“JOAs”) to which Epsilon and Chesapeake are parties. Epsilon asserts that Chesapeake has failed to cooperate with Epsilon’s efforts to develop resources in the Auburn Development, located in North-Central Pennsylvania, as required under both the settlement agreement and JOAs.

19

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Epsilon requested a preliminary injunction but was unsuccessful in obtaining that injunction.  Epsilon filed a motion to amend its original Complaint.  Chesapeake opposed.  The Court ruled in Epsilon’s favor and allowed Epsilon’s amendment. Chesapeake moved to dismiss the amended Complaint.  The Court granted the motion to dismiss on a narrow issue without prejudice to Epsilon’s right to file a new lawsuit based on new proposals made after the Court’s decision.  Epsilon filed a motion for reconsideration of that decision, but the court denied the motion for reconsideration on January 18, 2022.

Epsilon filed a notice of appeal on February 15, 2022 challenging both the motion to dismiss and motion for reconsideration decisions.  Chesapeake filed a cross-appeal on March 1, 2022.  A briefing schedule was set with briefing to close in October 2022.  A decision on the appeal is not expected until early to mid-2023.

Epsilon re-filed a complaint against Chesapeake in the Middle District on May 9, 2022.  Epsilon generally asserts similar claims as in the previous suit, pursuing declaratory judgment claims regarding Chesapeake’s obligation to Epsilon to cooperate with Epsilon’s efforts in the Auburn Development and regarding Chesapeake’s obstruction of Epsilon’s efforts with the Pennsylvania Department of Environmental Protection permitting process but not based on specific well proposals.  Chesapeake filed a motion to stay pending a decision on the Third Circuit appeal.  The motion to stay has been fully briefed.  Epsilon expects a decision on the motion to stay in fall 2022.  

10. Net Income Per Share

Basic net income per share is computed on the basis of the weighted-average number of common shares outstanding during the period. Diluted net income per share is computed based upon the weighted-average number of common shares outstanding during the period plus the assumed issuance of common shares for all potentially dilutive securities.

The net income used in the calculation of basic and diluted net income per share is as follows:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Net income (loss) available to shareholders	$	10,582,988	$	(485,025)	$	16,388,876	$	2,250,542

In calculating the net income per share, basic and diluted, the following weighted-average shares were used:

	Three months ended June 30,		Six months ended June 30,
	2022	2021	2022	2021
Basic weighted-average number of shares outstanding	23,576,746	23,779,205	23,627,015	23,862,749
Dilutive stock options	25,405	—	19,630	—
Unvested time-based restricted shares	103,258	—	39,340	53,815
Unvested performance-based restricted shares	116,714	—	110,181	24,776
Diluted weighted average shares outstanding	23,822,123	23,779,205	23,796,166	23,941,340

The company excluded the following shares from the diluted EPS because their inclusion would have been anti-dilutive.

	Three months ended June 30,		Six months ended June 30,
	2022	2021	2022	2021
Anti-dilutive options	72,095	—	77,870	—
Anti-dilutive unvested time-based restricted shares	146,740	77,023	169,127	—
Anti-dilutive unvested performance-based restricted shares	34,786	36,567	41,319	—
Total Anti-dilutive shares	253,621	113,590	288,316	—

20

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

11. Operating Segments

Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision-maker. The chief operating decision-maker, who is responsible for allocating resources and assessing performance of the operating segments, has been identified as executive management. Segment performance is evaluated based on operating profit or loss as shown in the table below. Interest income and expense, and income taxes are managed separately on a group basis.

The Company’s reportable segments are as follows:

a. The Upstream segment activities include acquisition, development and production of oil, natural gas, and other liquid reserves on properties within the United States;

b. The Gas Gathering segment partners with two other companies to operate a natural gas gathering system; and

c. The Corporate segment activities include corporate listing and governance functions of the Company.

Segment activity as of, and for the six months ended June 30, 2022 and 2021 is as follows:

	Upstream		Gas Gathering		Corporate			Elimination		Consolidated
As of and for the six months ended June 30, 2022
Operating revenue
Natural gas	$	26,687,432	$	—	$	—		$	—	$	26,687,432
Natural gas liquids		1,002,825		—		—			—		1,002,825
Oil and condensate		1,704,904		—		—			—		1,704,904
Gathering and compression fees		—		4,842,838		—			(734,897)		4,107,941
Total operating revenue (1)	$	29,395,161	$	4,842,838	$	—		$	(734,897)	$	33,503,102
Net earnings (loss) for the period	$	22,359,572	$	3,222,690	$	(9,193,386)	(3)	$	—	$	16,388,876
Operating costs		4,392,404		1,065,603		—			(734,897)		4,723,110
Development geological and geophysical expenses		4,772		—		—			—		4,772
Depletion, depreciation, amortization and accretion		2,638,413		554,545		—			—		3,192,958
Segment assets	$	99,313,811	$	10,732,117	$	754,360		$	—	$	110,800,287
Capital expenditures (2)		4,001,802		91,409		—			—		4,093,211
Proved properties (net)		40,649,783		—		—			—		40,649,783
Unproved properties (net)		18,021,391		—		—			—		18,021,391
Gathering system (net)		—		8,571,168		—			—		8,571,168
Lease right-of-use-asset		—		—		—			—		—
Other property and equipment (net)		930,491		—		—			—		930,491
As of and for the six months ended June 30, 2021
Operating revenue
Natural gas	$	11,439,021	$	—	$	—		$	—	$	11,439,021
Natural gas liquids		98,150		—		—			—		98,150
Oil and condensate		140,738		—		—			—		140,738
Gathering and compression fees		—		4,623,548		—			(770,296)		3,853,252
Total operating revenue (1)	$	11,677,909	$	4,623,548	$	—		$	(770,296)	$	15,531,161
Net earnings (loss) for the period	$	5,684,536	$	2,751,860	$	(6,185,854)	(3)	$	—	$	2,250,542
Operating costs		3,378,327		1,134,790		—			(770,296)		3,742,821
Development geological and geophysical expenses		22,990		—		—			—		22,990
Depletion, depreciation, amortization and accretion		2,592,056		736,898		—			—		3,328,954
Segment assets	$	78,621,390	$	11,941,329	$	133,220		$	—	$	90,695,939
Capital expenditures (2)		2,374,115		70,504		—			—		2,444,619
Proved properties (net)		34,531,736		—		—			—		34,531,736
Unproved properties (net)		21,557,121		—		—			—		21,557,121
Gathering system (net)		—		9,437,587		—			—		9,437,587
Other property and equipment (net)		964,435		—		—			—		964,435

21

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the six months ended June 30, 2022 and 2021 have been eliminated upon consolidation. For the six months ended June 30, 2022, Epsilon sold natural gas to 21 unique customers. The two customers over 10% comprised 23% and 19% of total revenue. For the six months ended June 30, 2021, Epsilon sold natural gas to 25 unique customers. The two customers over 10% comprised 35% and 10% of total revenue.

(2) Capital expenditures for the Upstream segment consist primarily of the acquisition of properties, and the drilling and completing of wells while Gas Gathering consists of expenditures relating to the expansion and completion of the gathering and compression facility.

(3) Segment reporting for net earnings for the period does not include non-monetary compensation, general and administrative expense, interest income, interest expense, both gains and (losses) on derivative contracts, or income tax amounts as they are managed on a group basis and are instead included in the corporate column for reconciliation purposes.

Segment activity for the three months ended June 30, 2022 and 2021 is as follows:

	Upstream			Gas Gathering		Corporate			Elimination		Consolidated
For the three months ended June 30, 2022
Operating revenue
Natural gas	$	15,984,348		$	—	$	—		$	—	$	15,984,348
Natural gas liquids		688,397			—		—			—		688,397
Oil and condensate		1,243,091			—		—			—		1,243,091
Gathering and compression fees		—			2,356,901		—			(369,733)		1,987,168
Total operating revenue	$	17,915,836	(1)	$	2,356,901	$	—		$	(369,733)		19,903,004
Net earnings (loss) for the period	$	13,757,784		$	1,545,850	$	(4,720,646)	(3)		—	$	10,582,988
Operating costs		2,621,750			541,228		—			(369,733)		2,793,245
Development geological and geophysical expenses		2,386			—		—			—		2,386
Depletion, depreciation, amortization and accretion		1,533,916			269,823		—			—		1,803,739
Bad debt expense		—			—		—			—		—
Capital expenditures(2)		1,390,908			76,016		—			—		1,466,924
For the three months ended June 30, 2021
Operating revenue
Natural gas	$	5,106,922		$	—	$	—		$	—	$	5,106,922
Natural gas liquids		52,529			—		—			—		52,529
Oil and condensate		79,303			—		—			—		79,303
Gathering and compression fees		—			2,236,960		—			(385,865)		1,851,095
Total operating revenue	$	5,238,754	(1)	$	2,236,960	$	—		$	(385,865)		7,089,849
Net earnings (loss) for the period	$	2,153,394		$	1,321,225	$	(3,959,644)	(3)	$	—	$	(485,025)
Operating costs		1,784,138			559,412		—			(385,865)		1,957,685
Development geological and geophysical expenses		11,451			—		—			—		11,451
Depletion, depreciation, amortization and accretion		1,289,771			356,323		—			—		1,646,094
Bad Debt Expense		—			—		—			—		—
Capital expenditures(2)		1,459,675			57,220		—			—		1,516,895

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended June 30, 2022 and 2021 have been eliminated upon consolidation. For the three months ended June 30, 2022, Epsilon sold natural gas to 19 unique customers. The four customers over 10% comprised 33%, 17%, 12% and 10% of total revenue. For the three months ended June 30, 2021, Epsilon sold natural gas to 21 unique customers. The two customers over 10% comprised 23% and 19% of total revenue.

22

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

(2) Capital expenditures for the Upstream segment consist primarily of the acquisition of properties, and the drilling and completing of wells while Gas Gathering consists of expenditures relating to the expansion and completion of the gathering and compression facility.

(3) Segment reporting for net earnings for the period does not include non-monetary compensation, general and administrative expense, interest income, interest expense, both gains and (losses) on derivative contracts, or income tax amounts as they are managed on a group basis and are instead included in the corporate column for reconciliation purposes.

12. Commodity Risk Management Activities

Commodity Price Risks

Epsilon engages in price risk management activities from time to time. These activities are intended to manage Epsilon’s exposure to fluctuations in commodity prices for natural gas by securing derivative contracts for a portion of expected sales volumes.

Inherent in the Company’s hedging program, are certain business risks, including market risk and credit risk. Market risk is the risk that the price of natural gas and oil will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by the Company’s counterparty to a contract. Additionally, there is a risk that gas prices could fall to a level low enough to affect the volumes flowing through the gathering system.

The Company enters into certain commodity derivative instruments to mitigate commodity price risk associated with a portion of its future natural gas production and related cash flows. The natural gas revenues and cash flows are affected by changes in commodity product prices, which are volatile and cannot be accurately predicted. The objective for holding these commodity derivatives is to protect the operating revenues and cash flows related to a portion of the future natural gas sales from the risk of significant declines in commodity prices, which helps ensure the Company’s ability to fund the capital budget.

Epsilon has historically elected not to designate any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for these financial commodity derivative contracts using the mark-to-market accounting method. Under this accounting method, changes in the fair value of outstanding financial instruments are recognized as gains or losses in the period of change and are recorded as loss (gain) on derivative contracts on the condensed consolidated statements of operations and comprehensive income (loss). The related cash flow impact is reflected in cash flows from operating activities. During the three and six months ended June 30, 2022, Epsilon recognized gains (losses) on commodity derivative contracts of $776,994 and ($194,910), respectively. This amount included cash paid on settlements on these contracts of $163,559 and $1,375,287, respectively. For the three and six months ended June 30, 2021, Epsilon recognized losses on commodity derivative contracts of $1,827,334 and $1,361,993, respectively. This amount included cash paid on settlements on these contracts of $91,660 and $27,460, respectively.

Commodity Derivative Contracts

Presented below is a summary of Epsilon’s natural gas commodity basis swap and two-way costless collar contracts as of June 30, 2022.

23

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

								Fair Value
	Volume	Ceiling		Floor		Basis		June 30,
Derivative Type	(MMbtu)	Price		Price		Differential		2022
2022
Basis swap	765,000					$	(1.15)		7,788
Two-way costless collar	765,000	$	8.20	$	6.50				932,765
								$	940,553

As of June 30, 2022, all of the Company’s economic derivative hedge positions were with large financial institutions, which are not known to the Company to be in default on their derivative positions. The Company is exposed to credit risk to the extent of non-performance by the counterparties in the derivative contracts discussed above; however, the Company does not anticipate non-performance by such counterparties. None of the Company’s derivative instruments contains credit-risk related contingent features. Derivatives are net on the balance sheet as they are subject to the right to offset the liabilities with the assets.

The following tables summarize the gross fair values of our derivative instruments, presenting the impact of offsetting the derivative assets and liabilities on our condensed consolidated balance sheets as of the dates indicated below:

	Fair Value of Derivative  Assets
	June 30,		December 31,
	2022		2021
Current
Basis swap	$	90,782	$	—
Two-way costless collar	$	1,063,754	$	13,312
	$	1,154,537	$	13,312

	Fair Value of Derivative  Liabilities
	June 30,		December 31,
	2022		2021
Current
Basis swap	$	(82,994)	$	—
Two-way costless collar	$	(130,989)	$	(253,136)
	$	(213,984)	$	(253,136)
Net Fair Value of Derivatives	$	940,553	$	(239,824)

The following table presents the changes in the fair value of Epsilon’s commodity derivatives for the periods indicated:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Fair value of asset (liability), beginning of the period	$	—	$	401,141	$	(239,824)	$	—
Gains (losses) on derivative contracts included in earnings		776,994		(1,827,334)		(194,910)		(1,361,992)
Settlement of commodity derivative contracts		163,559		91,660		1,375,287		27,459
Fair value of asset (liability), end of the period	$	940,553	$	(1,334,533)	$	940,553	$	(1,334,533)

24

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

13. Asset Retirement Obligations

Asset retirement obligations were estimated by management based on Epsilon’s net ownership interest in all wells and the gathering system, estimated costs to reclaim and abandon such assets and the estimated timing of the costs to be incurred in future periods.

The following tables summarize the changes in asset retirement obligations for the periods indicated:

	Six Months Ended		Year ended
		June 30,		December 31,
	2022		2021
Balance beginning of period	$	2,833,656	$	3,150,243
Liabilities acquired		6,684		7,009
Liabilities disposed of		(24,854)		(381,346)
Wells plugged and abandoned		(118,259)		(31,945)
Change in estimates		—		(8,299)
Accretion		38,738		97,994
Balance end of period	$	2,735,965	$	2,833,656

14. Fair Value Measurements

The methodologies used to determine the fair value of our financial assets and liabilities at June 30, 2022 were the same as those used at December 31, 2021.

Cash and cash equivalents, restricted cash, accounts receivable, accounts payable and accrued liabilities are carried at cost, which approximates their fair value because of the short-term maturity of these instruments. The Company’s revolving line of credit has a recorded value that approximates its fair value since its variable interest rate is tied to current market rates and the applicable margins represent market rates.

Commodity derivative instruments consist of two-way costless collar and basis swap contracts for natural gas. The Company’s derivative contracts are valued based on a marked to market approach. These assumptions are observable in the marketplace throughout the full term of the contract, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace, and are therefore designated as Level 2 within the valuation hierarchy. The Company utilizes its counterparties’ valuations to assess the reasonableness of its own valuations.

15. Subsequent Events

Effective July 1, 2022, Epsilon announced that Jason Stabell and Andrew Williamson had joined the Company as Chief Executive Officer and Chief Financial Officer, respectively. Jason had also joined the Board of Directors.  Mike Raleigh, the former CEO of the Company, resigned from the Company and the Board of Directors effective June 30, 2022.  Lane Bond, the Company’s former Chief Financial Officer, also informed the Board of his desire to retire and entered into a transitional consulting role with the Company beginning July 1, 2022.

25

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

The following discussion is intended to assist in the understanding of trends and significant changes in or results of operations and the financial condition of Epsilon Energy Ltd. and its subsidiaries for the periods presented. The following discussion and analysis should be read in conjunction with our unaudited consolidated financial statements and notes thereto presented in this report, including the unaudited condensed consolidated financial statements as of June 30, 2022 and 2021 and for the six months then ended together with accompanying notes, as well as our audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2021. The following discussion contains “forward-looking statements” that reflect our future plans, estimates, beliefs, and expected performance. Actual results and the timing of events may differ materially from those contained in these forward- looking statements due to a number of factors. See “Part II. Item 1A. Risk Factors” and “Forward-Looking Statements.”

Overview

Epsilon Energy Ltd. (the “Company”) is a North American onshore focused independent natural gas and oil company engaged in the acquisition, development, gathering and production of natural gas and oil reserves. Our areas of operations are the Marcellus shale section of the Appalachian basin in Pennsylvania and the NW Anadarko basin in Oklahoma. Our assets are in areas with established hydrocarbon resources with significant existing production. In Pennsylvania, we hold 4,597 net acres producing 28 MMcf/d (1H 2022). In Oklahoma, we hold 8,579 net acres producing 3.3 MMcfe/d (1H 2022).  

In Pennsylvania, the Company owns a 35% interest in the 52 mile Auburn Gas Gathering System (“Auburn GGS") which is operated by a subsidiary of Williams Partners, LP.

Our common shares trade on the NASDAQ Global Market under the ticker symbol “EPSN.”

Business Strategy

The Company is focused on high rate of return capital investments in onshore North American natural gas and oil basins. We are committed to disciplined capital allocation which should include shareholder returns in the form of dividends and share buybacks. We expect that our strong balance sheet and large liquidity position will allow us to opportunistically invest in both our existing project areas and potential new projects.     

To date, our investments have been focused in our position in the prolific Marcellus unconventional reservoir in Pennsylvania (“PA”). Our PA assets are supported by our 35% ownership in the Auburn GGS. More recently, we have been active in our position in the NW Stack area of Oklahoma. We have substantial remaining drillable location inventory within our existing leaseholds.

The Company also seeks to identify new opportunities in onshore North American natural gas and oil basins.

Three and six months ended June 30, 2022 Highlights

Operational Highlights

Marcellus Shale – Pennsylvania

● During the three months ended June 30, 2022, Epsilon’s realized natural gas price was $6.94 per Mcf, a 256% increase over the three months ended June 30, 2021. During the six months ended June 30, 2022, Epsilon’s realized natural gas price was $5.68 per Mcf, a 152% increase over the six months ended June 30, 2021.

● During the three months ended June 30, 2022, Epsilon’s natural gas production was 2.2 Bcf, as compared to 2.5 Bcf during the same period in 2021. During the six months ended June 30, 2022, Epsilon’s natural gas production was 4.4 Bcf as compared to 4.9 Bcf during the same period in 2021.

26

● Gathered and delivered 16.7 Bcf gross (5.8 Bcf net to Epsilon’s interest) during the three months ended June 30, 2022, or 183 MMcf/d through the Auburn Gas Gathering System. Gathered and delivered 35.0 Bcf gross (12.2 Bcf net to Epsilon’s interest) during the six months ended June 30, 2022, or 193 MMcf/d through the Auburn Gas Gathering System.

●At June 30, 2022, the Company had 1 gross (0.18 net) well waiting on completion.

Anadarko, NW Stack Trend – Oklahoma

● During the three months ended June 30, 2022, Epsilon’s realized price for all Oklahoma production was $8.96 per Mcfe, a 71% increase over the three months ended June 30, 2021.  During the six months ended June 30, 2022, Epsilon’s realized price for all Oklahoma production was $8.51 per Mcfe, an 87% increase over the six months ended June 30, 2021.

● Total production for the three months ended June 30, 2022 included natural gas, oil, and other liquids and was 0.32 Bcfe, a 431% increase over the same period in 2021. Total production for the six months ended June 30, 2022 included natural gas, oil, and other liquids and was 0.49 Bcfe, a 272% increase over the same period in 2021.

● In the second quarter of 2022, the Company completed 1 gross (.11 net) well. At June 30, 2022, the Company had 1 gross (.11 net) well waiting on completion.

Non-GAAP Financial Measures-Adjusted EBITDA

Epsilon defines Adjusted EBITDA as earnings before (1) net interest expense, (2) taxes, (3) depreciation, depletion, amortization and accretion expense, (4) impairments of natural gas and oil properties, (5) non-cash stock compensation expense, (6) gain or loss on derivative contracts net of cash received or paid on settlement, and (7) other income. Adjusted EBITDA is not a measure of financial performance as determined under U.S. GAAP and should not be considered in isolation from or as a substitute for net income or cash flow measures prepared in accordance with U.S. GAAP or as a measure of profitability or liquidity.

Additionally, Adjusted EBITDA may not be comparable to other similarly titled measures of other companies. Epsilon has included Adjusted EBITDA as a supplemental disclosure because its management believes that EBITDA provides useful information regarding its ability to service debt and to fund capital expenditures. It further provides investors a helpful measure for comparing operating performance on a normalized or recurring basis with the performance of other companies, without giving effect to certain non-cash expenses and other items. This provides management, investors and analysts with comparative information for evaluating the Company in relation to other natural gas and oil companies providing corresponding non-U.S. GAAP financial measures or that have different financing and capital structures or tax rates. These non-U.S. GAAP financial measures should be considered in addition to, but not as a substitute for, measures for financial performance prepared in accordance with U.S. GAAP.

The table below sets forth a reconciliation of net income to Adjusted EBITDA for the three and six months ended June 30, 2022 and 2021, which is the most directly comparable measure of financial performance calculated under U.S. GAAP and should be reviewed carefully.

27

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Net income	$	10,582,988	$	(485,025)	$	16,388,876	$	2,250,541
Add Back:
Net interest expense		(21,200)		13,441		(21,102)		32,701
Income tax expense		4,019,576		(165,751)		6,201,474		978,822
Depreciation, depletion, amortization, and accretion		1,803,739		1,646,094		3,192,958		3,328,954
Stock based compensation expense		194,050		236,041		336,352		438,540
Loss on derivative contracts net of cash received or paid on settlement		(940,553)		1,735,674		(1,180,377)		1,334,533
Foreign currency translation loss		(1,071)		279		4,331		611
Adjusted EBITDA	$	15,637,529	$	2,980,753	$	24,922,512	$	8,364,702

28

Results of Operations

Net Operating Revenues

For the six months ended June 30, 2022 revenues increased $18.0 million, or 116%, to $33.5 million from $15.5 million during the same period of 2021.

Revenue and volume statistics for the three and six months ended June 30, 2022 and 2021 were as follows:

	Three months ended				Six months ended
	June 30,				June 30,
	2022		2021		2022		2021
Revenues
Natural gas revenue	$	15,984,348	$	5,106,922	$	26,687,432	$	11,439,021
Volume (MMcf)		2,324		2,548		4,675		5,014
Avg. Price ($/Mcf)	$	6.88	$	2.00	$	5.71	$	2.28
Oil and other liquids revenue	$	1,931,488	$	131,832	$	2,707,729	$	238,888
Volume (MBO)		27.6		3.2		42.5		6.9
Avg. Price ($/Bbl)	$	69.92	$	41.68	$	63.73	$	34.58
Gathering system revenue	$	1,987,168	$	1,851,095	$	4,107,941	$	3,853,252
Total Revenues	$	19,903,004	$	7,089,849	$	33,503,102	$	15,531,161

We earn gathering system revenue as a 35% owner of the Auburn Gas Gathering system. This revenue consists of fees paid by Anchor Shippers (parties listed in Anchor Shipper Gas Gathering Agreement for Northern Pennsylvania, including Epsilon Midstream, LLC) of the system to transport gas from the wellhead to the compression facility, and then to the delivery meter at the Tennessee Gas Pipeline. For the six months ended June 30, 2022, approximately 77% of the Auburn GGS revenues earned were gathering fees, while 23% were compression fees. For the three months ended June 30, 2022 approximately 77% of the Auburn GGS revenues earned were gathering fees, while 23% were compression fees. For the six months ended June 30, 2021, approximately 81% of the Auburn GGS revenues earned were gathering fees, while 19% were compression fees. Gathering revenues from third-party customers represented approximately 6% of total gathering revenues and third-party compression revenues represented 3% of total compression revenues. For the three months ended June 30, 2021 approximately 81% of the Auburn GGS revenues earned were gathering fees, while 19% were compression fees. Gathering revenues from third-party customers represented approximately 5% of revenues and third-party compression revenues represented 2% of revenues. Revenues derived from Epsilon’s production which have been eliminated from gathering system revenues amounted to $0.37 million and $0.73 million for the three and six months ended June 30, 2022, respectively, and $0.39 million and $0.77 million for the three and six month ended March 31, 2021, respectively.

Upstream natural gas revenue for the six months ended June 30, 2022 increased by $15.2 million, or 133%, over the same period in 2021. This was primarily a result of higher natural gas prices; however, this was partially offset by lower volumes being produced due to natural decline of the wells. Upstream natural gas revenue for the three months ended June 30, 2022 increased by $10.9 million, or 213%, over the same period in 2021. This was also primarily a result of higher natural gas prices partially offset by lower volumes being produced due to natural decline of the wells.

Upstream oil and other liquids revenue for the six months ended June 30, 2022 increased by $2.5 million, or 1,033%, over the same period in 2021. This was a result of increased production from new wells in Oklahoma in addition to higher prices. Upstream oil and other liquids revenue for the three months ended June 30, 2022 increased by $1.8 million, or 1,365%, over the same period in 2021. This was a result of increased production from new wells in Oklahoma in addition to higher prices.

The Company’s share of gathering system revenue increased by $0.1 million and $0.3 million during the three and six months ended June 30, 2022, increasing by 7% and 7%, respectively over the same period in 2021. The Auburn GGS is subject to a cost of service model, whereby the Anchor Shippers dedicate acreage and reserves to the Auburn GGS. In exchange for this dedication, the owners of the Auburn system agree to a fixed rate of return on capital invested which cannot be exceeded. Therefore, rather than being subject to a fixed gathering rate, the Shippers are subject to a fluctuating gathering rate which is redetermined annually in order to produce the contractual return on capital to the Auburn GGS

29

owners. The term of the model is fixed from 2012 to 2026. Each year, actual throughput, revenue, operating expenses and capital are captured in the model, and the remaining years are forecasted. The model then resolves a gathering rate that yields the contractual rate of return. All else being equal, to the extent that throughput is higher or capital is lower than the preceding year’s forecast, the gathering rate will decline.

Operating Costs

The following table presents total cost and cost per unit of production (Mcfe), including ad valorem, severance, and production taxes for the three and six months ended June 30, 2022 and 2021:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Lease operating costs	$	2,621,750	$	1,784,138	$	4,392,404	$	3,378,327
Gathering system operating costs		171,495		173,547		330,706		364,494
	$	2,793,245	$	1,957,685	$	4,723,110	$	3,742,821
Upstream operating costs—Total $/Mcfe		1.05		0.68		0.89		0.67
Gathering system operating costs $/Mcf		0.09		0.10		0.09		0.10

Upstream operating costs consist of lease operating expenses necessary to extract natural gas and oil, including gathering and treating the natural gas and oil to ready it for sale.

Upstream operating costs for the six months ended June 30, 2022 increased $1.0 million, or 30%, over the same period in 2021. Upstream operating costs for the three months ended June 30, 2022 increased $0.8 million, or 47%, over the same period in 2021. The increase in total cost was primarily due to rising prices for services leading to a $1.05/Mcfe and $0.89/Mcfe for the three and six months ended June 30, 2022, or 33% and 54%, increase, respectively in the cost associated with operating the wells.

Gathering system operating costs consist primarily of rental payments for the natural gas fueled compression units. Other significant gathering system operating costs include chemicals (to prevent corrosion and to reduce water vapor in the gas stream), saltwater disposal, measurement equipment / calibration and general project management.

The gathering system total per unit operating costs reported include the effects of elimination entries to remove the gas gathering fees billed by the gas gathering system operator to Epsilon’s upstream operations, and the volume associated with those fees. The elimination entries amounted to $0.73 million and $0.77 million for the six months ended June 30, 2022 and 2021, respectively and $0.37 million and $0.39 million for the three months ended June 30, 2022 and 2021, respectively (see Note 11, ‘‘Operating Segments,’’ of the Notes to Unaudited Condensed Consolidated Financial Statements).

Gathering system costs (net of intercompany elimination) for the six months ended June 30, 2022 decreased $0.03 million, or 9%, over the same period in 2021. Gathering system costs (net of intercompany elimination) for the three months ended March 31, 2022 stayed constant over the same period in 2021.

The Company’s share of total gathering system costs decreased $0.04 million, or 5%, for the six months ended June 30, 2022 over 2021. The Company’s share of total gathering system costs decreased $0.02 million, or 4%, for the three months ended June 30, 2022 over 2021. This decrease is primarily due to a decrease in throughput volumes into the gathering system.

Depletion, Depreciation, Amortization and Accretion (“DD&A”)

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Depletion, depreciation, amortization and accretion	$	1,803,739	$	1,646,094	$	3,192,958	$	3,328,954

Natural gas and oil and gathering system assets are depleted and depreciated using the units of production method aggregating properties on a field basis. For leasehold acquisition costs and the cost to acquire proved and unproved

30

properties, the reserve base used to calculate depreciation and depletion is total proved reserves. At this time, the Company has only minimal leasehold acquisition costs. For natural gas and oil development and gathering system costs, the reserve base used to calculate depletion and depreciation is proved developed reserves. A reserve report is prepared as of December 31, each year.

Depreciation expense includes primarily amounts pertaining to our office furniture and fixtures, leasehold improvements, and computer hardware. Depreciation is calculated using the straight-line method over the estimated useful lives of the assets, ranging from 3 to 7 years. Also included in depreciation expense is an amount pertaining to buildings owned by the Company. Depreciation for the buildings is calculated using the straight-line method over an estimated useful life of 30 years.

Accretion expense is related to the asset retirement obligations.

DD&A expense for the six months ended June 30, 2022 was constant compared to the same period in 2021. DD&A expense increased $0.16 million, or 10% for the three months ended June 30, 2022 compared to the same period in 2021. This was primarily due to the increase in depletable costs as a result of transferring unproved leasehold costs to proved for depletion purposes as new wells are put into production.

Impairment

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Impairment	$	—	$	—	$	—	$	—

Epsilon performs a quantitative impairment test quarterly or whenever events or changes in circumstances indicate that an asset group's carrying amount may not be recoverable, over proved properties using the published NYMEX and basis differential forward prices, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, GAAP requires that the Company first compares expected future undiscounted cash flows by asset group to their respective carrying values. If the carrying amount exceeds the estimated undiscounted future cash flows, a reduction of the carrying amount of the natural gas properties to their estimated fair values is required, which is determined based on discounted cash flow techniques using significant assumptions including projected revenues, future commodity prices, and a market-specific weighted average cost of capital which are affected by expectations about future market and economic conditions.  

During the three and six months ended June 30, 2022 and 2021, no impairment was required.

General and Administrative

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
General and administrative	$	1,659,193	$	2,284,341	$	2,972,627	$	3,814,001

G&A expenses consist of general corporate expenses such as compensation, legal, accounting and professional fees, consulting services, travel and other related corporate costs such as stock options and restricted stock granted and the related non-cash compensation.

G&A expenses for the six months ended June 30, 2022 and 2021 decreased $0.8 million or 22%. G&A expenses for the three months ended June 30, 2022 and 2021 decreased $0.6 million or 27%. This was mainly due to the decreased legal fees related to the complaint filed against Chesapeake.

Interest Expense

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Interest expense	$	745	$	22,345	$	16,064	$	49,418

31

Interest expense relates to the commitment fees paid on the revolving line of credit.

Interest expense for the three and six months ended June 30, 2022 and 2021 decreased due to the reduction in the borrowing base on our line of credit during this time.

(Loss) Gain on Derivative Contracts

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Gain (loss) on derivative contracts	$	776,994	$	(1,827,334)	$	(194,910)	$	(1,361,993)

For the three and six months ended June 30, 2022 and 2021, Epsilon entered into NYMEX Henry Hub two-way costless collar and Tennessee basis swap derivative contracts for the purpose of hedging its physical natural gas sales revenue. During the three and six months ended June 30, 2022, we paid net cash settlements of $163,559 and $1,375,287, respectively. During the three and six months ended June 30, 2021, we paid net cash settlements of $91,660 and $27,460, respectively.

For the three and six months ended June 30, 2022, realized losses on derivative contracts increased primarily due to the rally in NYMEX Henry Hub Natural Gas Futures resulting in an increased liability for the short call portion of the two-way costless collar position. As of June 30, 2022, the Company had no derivative contracts beyond December 31, 2022.

Other (Expense) Income

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Interest income and other income	$	(39,768)	$	8,625	$	(29,953)	$	18,380

For the three and six months ended June 30, 2022 and 2021, other income decreased as a result of derecognizing and asset retirement obligation after the P&A of an asset. This was offset by an increase in interest received as a result of increasing interest rates.

Capital Resources and Liquidity

Cash Flow

The primary source of cash for Epsilon during the three and six months ended June 30, 2022 and 2021 was funds generated from operations. The primary uses of cash for the three and six months ended June 30, 2022 were development of natural gas properties, the repurchase of shares of common stock, and the distribution of dividends. The primary uses of cash for the three and six months ended June 30, 2021 were development of natural gas properties and the repurchase of shares of common stock.

At June 30, 2022, we had a working capital surplus of $33.3 million, an increase of $9.2 million over the $24.1 million surplus at December 31, 2021. The Company anticipates its current cash balance, cash flows from operations, and available sources of liquidity to be sufficient to meet its cash requirements for at least the next twelve months.

Three and six months ended June 30, 2022 compared to 2021

During the six months ended June 30, 2022, $15.8 million was provided by the Company’s operating activities, compared to $8.0 million provided during the same period in 2021, a $7.7 million, and 96% increase. The increase was mainly due to increased cash from operations as a result of increased commodity prices, partially offset by the losses created on the hedges as they matured. During the three months ended June 30, 2022, $8.1 million was provided by the Company’s operating activities, compared to $2.4 million provided during the same period in 2021, a $5.7 million, and 235% increase. The increase was mainly due to increased cash from operations as a result of increased commodity prices.

32

The Company used $2.1 million and $5.0 million of cash for investing activities during the three and six months ended June 30, 2022, respectively. This was spent primarily on leasehold and development costs targeting increasing production in Pennsylvania and Oklahoma. The Company used $1.2 million and $1.7 million of cash for investing activities during the three and six months ended June 30, 2021, respectively. This was spent primarily on leasehold and development costs targeting increasing production in Pennsylvania.

The Company used $5.0 million and $6.3 million of cash for financing activities during the three and six months ended June 30, 2022, respectively.  This was spent primarily on dividend payments and the repurchase of shares of common stock. The Company used $0.6 million and $1.1 million of cash for financing activities during the three and six months ended June 30, 2021. This cash was spent on the repurchase of common shares of the Company.

Credit Agreement

In addition, the Company has a senior secured credit facility which includes a total commitment of up to $100 million. The current effective borrowing base is $14 million, which is subject to semi-annual redetermination. There are currently no borrowings under the facility. If Epsilon decides to access the facility, depending on the level of borrowing, the Company will need to increase its hedging activity. Borrowings from the Facility may be used for the acquisition and development of oil and gas properties, investments in cash flow generating assets complimentary to the production of oil and gas, and for letters of credit and other general corporate purposes. Upon each advance, interest is charged at the highest of a) rate of LIBOR plus an applicable margin (3.25%-4.25% based on the percent of the line of credit utilized) with the minimum being 0.25%, b) the Prime Rate, or c) the sum of the Federal Funds Rate plus 0.5%.

Effective April 6, 2021 the agreement was amended to extend the maturity date to March 1, 2024. In addition, the agreement was amended to include a Benchmark Replacement definition and transition plan to be used at such time when the LIBOR rate is discontinued.

On August 2, 2022, the borrowing base of $14 million was reaffirmed until the next periodic redetermination of the borrowing base.

The bank has a first priority security interest in the tangible and intangible assets of Epsilon Energy USA, Inc. to secure any outstanding amounts under the agreement. Under the terms of the agreement, the Company must maintain the following covenants:

● Interest coverage ratio greater than 3 based on income adjusted for interest, taxes and non-cash amounts.

● Current ratio, adjusted for line of credit amounts used and available and non-cash amounts, greater than 1.

● Leverage ratio less than 3.0 based on income adjusted for interest, taxes and non-cash amounts.

Epsilon was in compliance with the financial covenants of the agreement as of June 30, 2022 and expect to be in compliance for the next 12 months. We expect to remain in compliance as we currently have no borrowings under the facility and funded all operations for 2021 and all operations through June 30, 2022 out of operating cash flow and cash on hand, and expect to continue to do so through 2022.

	Balance at		Balance at
	June 30,		December 31,		Borrowing Base		Interest
	2022		2021		June 30, 2022		Rate
Revolving line of credit	$	—	$	—	$	14,000,000	3 mo. LIBOR + 3.25%

Repurchase Transactions

Commencing on March 8, 2022, Epsilon conducted a normal course issuer bid (“NCIB”) to repurchase our issued and outstanding common shares, when doing so was accretive to management's estimates of intrinsic value per share. The NCIB ends on March 7, 2023. The Company used discretionary cash to fund these repurchases. During the six months ended June 30, 2022, Epsilon repurchased 697,100 common shares of the authorized 1,183,410 purchase amount and spent

33

$4,554,823 under the NCIB. The repurchased stock had an average price of $6.53 per share. The Company cancelled 423,000 common shares during the three months ended June 30, 2022.

Commencing on January 1, 2021, Epsilon conducted a normal course issuer bid (“NCIB”) to repurchase our issued and outstanding common shares, when doing so was accretive to management's estimates of intrinsic value per share. The NCIB ended on December 31, 2021. The Company used discretionary cash to fund these repurchases. During the six months ended June 30, 2021, Epsilon repurchased 264,215 common shares of the authorized 1,193,000 purchase amount and spent $1,061,468 under the NCIB. The repurchased stock had an average price of $4.01 per share.

Derivative Transactions

The Company has entered into hedging arrangements to reduce the impact of natural gas price volatility on operations. By reducing the price volatility from a significant portion of natural gas production, the potential effects of changing prices on operating cash flows have been mitigated, but not eliminated. While mitigating the negative effects of falling commodity prices, these derivative contracts also limit the benefits we might otherwise receive from increases in commodity prices.

At June 30, 2022, Epsilon’s outstanding natural gas commodity contracts consisted of the following:

	Volume	Ceiling		Floor		Basis		Fair Value of Asset
Derivative Type	(MMbtu)	Price		Price		Differential		June 30, 2022
2022
Basis swap	765,000	$	—	$	—	$	(1.15)		7,788
Two-way costless collar	765,000	$	8.20	$	6.50	$	—		932,765
	1,530,000							$	940,553

Contractual Obligations

The following table summarizes Epsilon’s contractual obligations at June 30, 2022:

	Payments Due by Period
			Less than		1 – 3		Greater than
	Total		1 Year		Years		3 Years
Derivative liabilities(1)	$	213,984	$	213,984	$	—	$	—
Asset retirement obligations, undiscounted		7,357,345		—		—		7,357,345
Capital expenditure commitments		1,487,599		1,487,599		—		—
Operating leases		156,110		93,666		62,444		—
Total future commitments	$	9,215,037	$	1,795,248	$	62,444	$	7,357,345

(1) The liability balance shown represents the gross mark-to-market liability balance of derivative contracts before being offset by contracts in an asset position.

We enter into commitments for capital expenditures in advance of the expenditures being made. Current commitments have been included in the contractual obligations table above.

Based on current natural gas prices and anticipated levels of production, we believe that the estimated net cash generated from operations, together with cash on hand and amounts available under our credit agreement, will be adequate to meet liquidity needs for the next 12 months and beyond, including satisfying our financial obligations and funding our operating and development activities.  To that end, the Company has hedged approximately 15% of its anticipated remaining 2022 production through NYMEX costless collars.

Off-Balance Sheet Arrangements

As of June 30, 2022, the Company had no off-balance sheet arrangements.

34

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our earnings and cash flow are significantly affected by changes in the market price of commodities. The prices of natural gas and oil can fluctuate widely and are influenced by numerous factors such as demand, production levels, world political and economic events, and the strength of the US dollar relative to other currencies. Should the price of natural gas and oil decline substantially, the value of our assets could fall dramatically, impacting our future operations and exploration and development activities, along with our gas gathering system revenues. In addition, our operations are exposed to market risks in the ordinary course of our business, including interest rate and certain exposure as well as risks relating to changes in the general economic conditions in the United States.

Gathering System Revenue Risk

The Auburn Gas Gathering System lies within the Marcellus Basin with historically high levels of recoverable reserves and low cost of production. We believe that a short-term low commodity price environment will not significantly impact the reserves produced and thus the revenue of our gas gathering system.

Interest Rate Risk

Market risk is estimated as the change in fair value resulting from a hypothetical 100 basis point change in the interest rate on the outstanding balance under our credit agreement. The credit agreement allows us to fix the interest rate for all or a portion of the principal balance for a period up to three months. To the extent that the interest rate is fixed, interest rate changes affect the instrument’s fair market value but do not affect results of operations or cash flows. Conversely, for the portion of the credit agreement that has a floating interest rate, interest rate changes will not affect the fair market value but will affect future results of operations and cash flows.

At June 30, 2022 and 2021, the outstanding principal balance under the credit agreement was nil.

Derivative Contracts

The Company’s financial results and condition depend on the prices received for natural gas production. Natural gas prices have fluctuated widely and are determined by economic and political factors. Supply and demand factors, including weather, general economic conditions, the ability to transport the gas to other regions, as well as conditions in other natural gas regions, impact prices. Epsilon has established a hedging strategy and may manage the risk associated with changes in commodity prices by entering into various derivative financial instrument agreements and physical contracts. Although these commodity price risk management activities could expose Epsilon to losses or gains, entering into these contracts helps to stabilize cash flows and support the Company’s capital spending program.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

As required by Rule 13a-15(b) under the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and our principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this 10-Q. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Our principal executive officer and principal financial officer have concluded that our current disclosure controls and procedures were effective as of June 30, 2022 at the reasonable assurance level.

35

Changes in Internal Control over Financial Reporting

No changes in our internal control over financial reporting occurred during the quarter ended June 30, 2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Inherent Limitations on Effectiveness of Controls

Internal control over financial reporting cannot provide absolute assurance of achieving financial reporting objectives because of its inherent limitations. Internal control over financial reporting is a process that involves human diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal control over financial reporting can also be circumvented by collusion or improper management override. Because of such limitations, there is a risk that material misstatements may not be prevented or detected on a timely basis by internal control over financial reporting. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that of limitations are known features of the financial reporting process. Therefore, it is possible to design into the process safeguards to reduce, though not eliminate, the risk.

PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

On March 10, 2021, Epsilon filed a complaint against Chesapeake Appalachia, LLC (“Chesapeake”) in the United States District Court for the Middle District of Pennsylvania, Scranton, Pennsylvania (“Middle District”). Epsilon claims that Chesapeake has breached a settlement agreement and several operating agreements (“JOAs”) to which Epsilon and Chesapeake are parties. Epsilon asserts that Chesapeake has failed to cooperate with Epsilon’s efforts to develop resources in the Auburn Development, located in North-Central Pennsylvania, as required under both the settlement agreement and JOAs.

Epsilon requested a preliminary injunction but was unsuccessful in obtaining that injunction.  Epsilon filed a motion to amend its original Complaint.  Chesapeake opposed.  The Court ruled in Epsilon’s favor and allowed Epsilon’s amendment. Chesapeake moved to dismiss the amended Complaint.  The Court granted the motion to dismiss on a narrow issue without prejudice to Epsilon’s right to file a new lawsuit based on new proposals made after the Court’s decision.  Epsilon filed a motion for reconsideration of that decision, but the court denied the motion for reconsideration on January 18, 2022.

Epsilon filed a notice of appeal on February 15, 2022 challenging both the motion to dismiss and motion for reconsideration decisions.  Chesapeake filed a cross-appeal on March 1, 2022.  A briefing schedule was set with briefing to close in October 2022.  A decision on the appeal is not expected until early to mid-2023.

Epsilon re-filed a complaint against Chesapeake in the Middle District on May 9, 2022.  Epsilon generally asserts similar claims as in the previous suit, pursuing declaratory judgment claims regarding Chesapeake’s obligation to Epsilon to cooperate with Epsilon’s efforts in the Auburn Development and regarding Chesapeake’s obstruction of Epsilon’s efforts with the Pennsylvania Department of Environmental Protection permitting process but not based on specific well proposals.  Chesapeake filed a motion to stay pending a decision on the Third Circuit appeal.  The motion to stay has been fully briefed.  Epsilon expects a decision on the motion to stay in fall 2022.

ITEM 1A. RISK FACTORS

There have been no material changes from the risk factors disclosed in Item 1A. Risk Factors of our Annual Report on Form 10-K for the year ended December 31, 2021.

36

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

(c) Purchases of Equity Securities by Epsilon Energy Ltd.

The following table contains information about our acquisition of equity securities during the six months ended June 30, 2022.

				Maximum number
				of shares that
				may yet be
	Total number	Average price		purchased under
	of shares	paid per		the plans or
	purchased	share		programs
Beginning of normal-course issuer bid, March 8, 2022					1,183,410
March 2022 (1)	—	$	—
April 2022 (1)	23,700	$	6.66
May 2022 (1)	254,500	$	7.01
June 2022 (1)	418,900	$	6.24
Total as of June 30, 2022	697,100	$	6.53		486,310

(1) Commencing on March 8, 2022, the Company entered into a share repurchase program on the NASDAQ conducted in accordance with Rule 10b-18 promulgated under the Securities Exchange Act of 1934. The Company is authorized to repurchase up to 1,183,410 of its outstanding common shares up to an aggregate purchase price limit of $8 million, representing 5% of the outstanding common shares. The program will end on March 7, 2023 unless the common shares or purchase price limits are reached before then or Epsilon provides earlier notice of termination.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

Not applicable.

37

ITEM 6. —EXHIBITS

Exhibit No.	Description of Exhibit
31.1	Sarbanes-Oxley Section 302 certification of Principal Executive Officer.
31.2	Sarbanes-Oxley Section 302 certification of Principal Financial Officer.
32.1	Sarbanes-Oxley Section 906 certification of Principal Executive Officer.
32.2	Sarbanes-Oxley Section 906 certification of Principal Financial Officer.
101.INS	Inline XBRL Instance Document.
101.SCH	Inline XBRL Schema Document.
101.CAL	Inline XBRL Calculation Linkbase Document.
101.DEF	Inline XBRL Definition Linkbase Document.
101.LAB	Inline XBRL Labels Linkbase Document.
101.PRE	Inline XBRL Presentation Linkbase Document.
104	Cover Page Interactive Data File (embedded within the Inline XBRL document)

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Epsilon Energy Ltd.
(Registrant)
Date: August 11, 2022	By:	/s/ J. Andrew Williamson
		J. Andrew Williamson
		Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

38

EX-31.1

Exhibit 31.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, Jason Stabell, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Epsilon Energy Ltd. (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; and

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; and

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 11, 2022

/s/ Jason Stabell

Jason Stabell

Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER

pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, J. Andrew Williamson, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Epsilon Energy Ltd. (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; and

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; and

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 11, 2022

/s/ J. Andrew Williamson

J. Andrew Williamson

Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Epsilon Energy Ltd. (the “Corporation”) on Form 10-Q for the period ending June 30, 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Corporation.

Date: August 11, 2022

/s/ Jason Stabell

Jason Stabell

Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION OF PRINCIPAL EXECUTIVE OFFICER

pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Epsilon Energy Ltd. (the “Corporation”) on Form 10-Q for the period ending June 30, 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Corporation.

Date: August 11, 2022

/s/ J. Andrew Williamson

J. Andrew Williamson

Chief Financial Officer

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2022	Aug. 11, 2022
Document and Entity Information
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Document Period End Date	Jun. 30, 2022
Document Fiscal Year Focus	2022
Entity File Number	001-38770
Entity Registrant Name	EPSILON ENERGY LTD.
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	98-1476367
Entity Address, Address Line One	16945 Northchase Drive
Entity Address, Address Line Two	Suite 1610
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77060
City Area Code	281
Local Phone Number	670-0002
Title of 12(b) Security	Common Shares, no par value
Trading Symbol	EPSN
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	true
Entity Ex Transition Period	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		22,975,512
Entity Central Index Key	0001726126
Current Fiscal Year End Date	--12-31
Document Fiscal Period Focus	Q2
Amendment Flag	false

XML

Condensed Consolidated Balance Sheets - USD ($)	Jun. 30, 2022	Dec. 31, 2021
Current assets
Cash and cash equivalents	$ 30,945,605	$ 26,497,305
Accounts receivable	9,930,891	4,596,931
Fair value of derivatives	940,553	0
Other current assets	240,998	569,870
Total current assets	42,058,047	31,664,106
Oil and gas properties, successful efforts method
Proved properties	145,697,537	138,032,413
Unproved properties	18,021,391	21,700,926
Accumulated depletion, depreciation, amortization and impairment	(105,047,754)	(102,480,972)
Total oil and gas properties, net	58,671,174	57,252,367
Gathering system	42,566,495	42,475,086
Accumulated depletion, depreciation, amortization and impairment	(33,995,327)	(33,443,949)
Total gathering system, net	8,571,168	9,031,137
Land	637,764	637,764
Buildings and other property and equipment, net	292,727	309,102
Total property and equipment, net	68,172,833	67,230,370
Other assets:
Lease right-of-use-asset	0
Restricted cash	569,407	568,118
Total non-current assets	68,742,240	67,798,488
Total assets	110,800,287	99,462,594
Current liabilities
Accounts payable trade	1,786,570	1,189,905
Gathering fees payable	1,052,168	963,546
Royalties payable	2,471,969	1,853,508
Income taxes payable	2,410,790	1,098,425
Accrued capital expenditures	224,179	1,016,830
Other accrued liabilities	834,779	1,098,127
Fair value of derivatives	0	239,824
Asset retirement obligations	0	85,207
Total current liabilities	8,780,455	7,545,372
Non-current liabilities
Asset retirement obligations	2,735,965	2,748,449
Deferred income taxes	10,224,766	9,905,440
Total non-current liabilities	12,960,731	12,653,889
Total liabilities	21,741,186	20,199,261
Commitments and contingencies (Note 9)
Shareholders' equity
Common shares, no par value, unlimited shares authorized and 23,356,453 issued and 23,082,353 outstanding at June 30, 2022 and 24,202,218 issued and 23,668,203 shares outstanding at December 31, 2021	127,093,520	131,815,739
Treasury shares, 274,100 at June 30, 2022 and 534,015 at December 31, 2021	(1,646,823)	(2,423,007)
Additional paid-in capital	9,171,555	8,835,203
Accumulated deficit	(55,364,008)	(68,783,207)
Accumulated other comprehensive income	9,804,857	9,818,605
Total shareholders' equity	89,059,101	79,263,333
Total liabilities and shareholders' equity	$ 110,800,287	$ 99,462,594

XML

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Condensed Consolidated Balance Sheets
Par value	$ 0	$ 0
Common shares authorized	Unlimited	Unlimited
Common shares issued	23,356,453	24,202,218
Common shares outstanding	23,082,353	23,668,203
Treasury shares	274,100	534,015

XML

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Revenues from contracts with customers:
Total revenue	$ 19,903,004	$ 7,089,849	$ 33,503,102	$ 15,531,161
Operating costs and expenses:
Lease operating expenses	2,621,750	1,784,138	4,392,404	3,378,327
Gathering system operating expenses	171,495	173,547	330,706	364,494
Development geological and geophysical expenses	2,386	11,451	4,772	22,990
Depletion, depreciation, amortization, and accretion	1,803,739	1,646,094	3,192,958	3,328,954
Gain on sale of oil and gas properties	(221,642)	0	(221,642)	0
General and administrative expenses:
Stock based compensation expense	194,050	236,041	336,352	438,540
Other general and administrative expenses	1,465,143	2,048,300	2,636,275	3,375,461
Total operating costs and expenses	6,036,921	5,899,571	10,671,825	10,908,766
Operating income	13,866,083	1,190,278	22,831,277	4,622,395
Other income (expense):
Interest income	21,945	8,904	37,166	16,717
Interest expense	(745)	(22,345)	(16,064)	(49,418)
Gain (loss) on derivative contracts	776,994	(1,827,334)	(194,910)	(1,361,993)
Other (expense) income	(61,713)	(279)	(67,119)	1,663
Other income (expense), net	736,481	(1,841,054)	(240,927)	(1,393,031)
Net income (loss) before income tax expense	14,602,564	(650,776)	22,590,350	3,229,364
Income tax expense (benefit)	4,019,576	(165,751)	6,201,474	978,822
NET INCOME(LOSS)	10,582,988	(485,025)	16,388,876	2,250,542
Currency translation adjustments	(19,150)	242	(13,748)	(1,242)
NET COMPREHENSIVE INCOME (LOSS)	$ 10,563,838	$ (484,783)	$ 16,375,128	$ 2,249,300
Net income (loss) per share, basic (in dollars per share)	$ 0.45	$ (0.02)	$ 0.69	$ 0.09
Net income (loss) per share, diluted (in dollars per share)	$ 0.44	$ (0.02)	$ 0.69	$ 0.09
Weighted average number of shares outstanding, basic (in shares)	23,576,746	23,779,205	23,627,015	23,862,749
Weighted average number of shares outstanding, diluted (in shares)	23,822,123	23,779,205	23,796,166	23,941,340
Gas, oil, NGL and condensate revenue
Revenues from contracts with customers:
Total revenue	$ 17,915,836	$ 5,238,754	$ 29,395,161	$ 11,677,909
Gas gathering and compression revenue
Revenues from contracts with customers:
Total revenue	$ 1,987,168	$ 1,851,095	$ 4,107,941	$ 3,853,252

XML

Condensed Consolidated Statements of Changes in Shareholders' Equity - USD ($)	Common stock	Treasury Shares	Additional paid-in Capital	Accumulated Other Comprehensive Income	Accumulated Deficit	Total
Balance at Dec. 31, 2020	$ 131,730,401		$ 7,879,119	$ 9,820,647	$ (80,410,724)	$ 69,019,443
Balance (in shares) at Dec. 31, 2020	23,985,799
Increase (Decrease) in Stockholders' Equity
Net income					2,735,567	2,735,567
Stock-based compensation expenses			202,499			202,499
Buyback of common shares		$ (492,479)				(492,479)
Buyback of common shares (in shares)		(123,200)
Other comprehensive income				242		242
Balance at Mar. 31, 2021	$ 131,730,401	$ (492,479)	8,081,618	9,820,889	(77,675,157)	71,465,272
Balance (in shares) at Mar. 31, 2021	23,985,799	(123,200)
Balance at Dec. 31, 2020	$ 131,730,401		7,879,119	9,820,647	(80,410,724)	69,019,443
Balance (in shares) at Dec. 31, 2020	23,985,799
Balance at Dec. 31, 2021	$ 131,815,739	$ (2,423,007)	8,835,203	9,818,605	(68,783,207)	79,263,333
Balance (in shares) at Dec. 31, 2021	24,202,218	(534,015)
Balance at Mar. 31, 2021	$ 131,730,401	$ (492,479)	8,081,618	9,820,889	(77,675,157)	71,465,272
Balance (in shares) at Mar. 31, 2021	23,985,799	(123,200)
Increase (Decrease) in Stockholders' Equity
Net income					(485,025)	(485,025)
Stock-based compensation expenses			236,041			236,041
Buyback of common shares		$ (568,989)				(568,989)
Buyback of common shares (in shares)		(141,015)
Other comprehensive income				(1,484)		(1,484)
Balance at Jun. 30, 2021	$ 131,730,401	$ (1,061,468)	8,317,659	9,819,405	(78,160,182)	70,645,816
Balance (in shares) at Jun. 30, 2021	23,985,799	(264,215)
Balance at Dec. 31, 2021	$ 131,815,739	$ (2,423,007)	8,835,203	9,818,605	(68,783,207)	79,263,333
Balance (in shares) at Dec. 31, 2021	24,202,218	(534,015)
Increase (Decrease) in Stockholders' Equity
Net income					5,805,888	5,805,888
Dividends					(1,483,027)	(1,483,027)
Stock-based compensation expenses			142,302			142,302
Exercise of stock options	$ 209,312					209,312
Exercise of stock options (in shares)	38,750
Retirement of treasury shares	$ (2,423,007)	$ 2,423,007
Retirement of treasury shares (in shares)	(534,015)	534,015
Other comprehensive income				5,402		5,402
Balance at Mar. 31, 2022	$ 129,602,044		8,977,505	9,824,007	(64,460,346)	83,943,210
Balance (in shares) at Mar. 31, 2022	23,706,953
Balance at Dec. 31, 2021	$ 131,815,739	$ (2,423,007)	8,835,203	9,818,605	(68,783,207)	$ 79,263,333
Balance (in shares) at Dec. 31, 2021	24,202,218	(534,015)
Increase (Decrease) in Stockholders' Equity
Purchase of treasury shares (shares)						(697,100)
Balance at Jun. 30, 2022	$ 127,093,520	$ (1,646,823)	9,171,555	9,804,857	(55,364,008)	$ 89,059,101
Balance (in shares) at Jun. 30, 2022	23,356,453	(274,100)
Balance at Mar. 31, 2022	$ 129,602,044		8,977,505	9,824,007	(64,460,346)	83,943,210
Balance (in shares) at Mar. 31, 2022	23,706,953
Increase (Decrease) in Stockholders' Equity
Net income					10,582,988	10,582,988
Dividends					(1,486,650)	(1,486,650)
Stock-based compensation expenses			194,050			194,050
Exercise of stock options	$ 399,475					399,475
Exercise of stock options (in shares)	72,500
Retirement of treasury shares	$ (2,907,999)	$ 2,907,999
Retirement of treasury shares (in shares)	(423,000)	423,000
Buyback of common shares		$ (4,554,822)				$ (4,554,822)
Buyback of common shares (in shares)		(697,100)				(423,000)
Other comprehensive income				(19,150)		$ (19,150)
Balance at Jun. 30, 2022	$ 127,093,520	$ (1,646,823)	$ 9,171,555	$ 9,804,857	$ (55,364,008)	$ 89,059,101
Balance (in shares) at Jun. 30, 2022	23,356,453	(274,100)

XML

Condensed Consolidated Statements of Cash Flows - USD ($)	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Cash flows from operating activities:
Net income	$ 16,388,876	$ 2,250,542
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion	3,192,958	3,328,954
Loss on derivative contracts	194,910	1,361,993
Gain on sale of oil and gas properties	(221,642)	0
Settlement paid on derivative contracts	(1,375,287)	(27,460)
Settlement of asset retirement obligation	(118,259)	(3,483)
Stock-based compensation expense	336,352	438,540
Deferred income tax expense (benefit)	319,326	230,863
Changes in assets and liabilities:
Accounts receivable	(5,333,960)	388,912
Prepaid income taxes and other current assets	328,872	(12,476)
Accounts payable, royalties payable and other accrued liabilities	738,023	77,248
Income taxes payable	1,312,365	0
Net cash provided by operating activities	15,762,534	8,033,633
Cash flows from investing activities:
Additions to unproved oil and gas properties	(162,445)	(70,058)
Additions to proved oil and gas properties	(4,935,370)	(1,557,869)
Additions to gathering system properties	(82,855)	(79,419)
Additions to land, buildings and property and equipment	(1,234)	(5,745)
Proceeds from sale of oil and gas properties	200,000	0
Prepaid drilling costs	0	273
Net cash used in investing activities	(4,981,904)	(1,712,818)
Cash flows from financing activities:
Buyback of common shares	(3,956,403)	(1,061,468)
Exercise of stock options	608,787	0
Dividends	(2,969,677)	0
Net cash used in financing activities	(6,317,293)	(1,061,468)
Effect of currency rates on cash, cash equivalents and restricted cash (Deprecated 2022)	(13,748)	(1,242)
Increase in cash, cash equivalents and restricted cash	4,449,589	5,258,105
Cash, cash equivalents and restricted cash, beginning of period	27,065,423	13,836,771
Cash, cash equivalents and restricted cash, end of period	31,515,012	19,094,876
Supplemental cash flow disclosures:
Income taxes paid	4,566,000	1,074,025
Interest paid	33,885	27,073
Non-cash investing and financing activities:
Change in unproved properties accrued in accounts payable and accrued liabilities	0	(65,000)
Change in proved properties accrued in accounts payable and accrued liabilities	(1,097,247)	805,443
Change in gathering system accrued in accounts payable and accrued liabilities	8,554	(8,915)
Change in share buybacks accrued in accounts payable and accrued liabilities	598,419
Change in prepaid drilling costs		979,358
Asset retirement obligation asset additions and adjustments	$ 7,666	$ (29,853)

XML

Description of Business

6 Months Ended

Jun. 30, 2022

Description of Business

Description of Business

1. Description of Business

Epsilon Energy Ltd. (the “Company” or “Epsilon” or “we”) was incorporated under the laws of the Province of Alberta, Canada on March 14, 2005. On October 24, 2007, the Company became a publicly traded entity trading on the Toronto Stock Exchange (“TSX”) in Canada. On February 14, 2019, Epsilon’s registration statement on Form 10 was declared effective by the United States Securities and Exchange Commission and on February 19, 2019, the Company began trading in the United States on the NASDAQ Global Market under the trading symbol “EPSN.” Effective as of the close of trading on March 15, 2019 Epsilon voluntarily delisted its common shares from the TSX. The Company is engaged in the acquisition, development, gathering and production of primarily natural gas reserves in the United States.

XML

Basis of Preparation

6 Months Ended

Jun. 30, 2022

Basis of Preparation

Basis of Preparation

2. Basis of Preparation

Interim Financial Statements

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and with the appropriate rules and regulations of the SEC. Accordingly, certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. All adjustments which are, in the opinion of management, necessary for a fair presentation of the financial position and results of operations for the interim periods presented have been included. The interim financial information and notes hereto should be read in conjunction with the Company’s consolidated financial statements as of and for the year ended December 31, 2021. The results of operations for interim periods are not necessarily indicative of results to be expected for a full fiscal year.

Principles of Consolidation

The Company’s unaudited condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiary, Epsilon Energy USA, Inc. and its wholly owned subsidiaries, Epsilon Midstream, LLC, Dewey Energy GP, LLC, Dewey Energy Holdings, LLC, Epsilon Operating, LLC, and Altolisa Holdings, LLC. With regard to the gathering system, in which Epsilon owns an undivided interest in the asset, proportionate consolidation accounting is used. All inter-company transactions have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The most significant estimates pertain to proved natural gas and oil reserves and related cash flow estimates used in impairment tests of natural gas and oil, and gathering system properties, asset retirement obligations, accrued natural gas and oil revenues and operating expenses, accrued gathering system revenues and operating expenses, as well as the valuation of commodity derivative instruments. Actual results could differ from those estimates.

Recently Issued Accounting Standards

The Company, an emerging growth company (“EGC”), has elected to take advantage of the benefits of the extended transition period provided for in Section 7(a)(2)(B) of the Securities Act, for complying with new or revised accounting standards which allows the Company to defer adoption of certain accounting standards until those standards would otherwise apply to private companies.

In March 2020, the FASB issued ASU No. 2020-04 - Reference Rate Reform (Topic 848), codified as ASC 848 (“ASC 848”). This was followed by ASU No. 2021-01, Reference Rate Reform (Topic 848): Scope (“ASU 2021-01”), issued in January 2021. The purpose of ASC 848 is to provide optional guidance to ease the potential effects on financial

reporting of the market-wide migration away from Interbank Offered Rates (“IBORs”) to alternative reference rates. ASC 848 applies only to contracts, hedging relationships, and other transactions that reference a reference rate expected to be discontinued because of reference rate reform. The guidance may be applied upon issuance of ASC 848 through December 31, 2022. We do not expect a material impact from the adoption of this ASU.

In June 2016 the FASB issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, which removes the thresholds that companies apply to measure credit losses on financial instruments measured at amortized cost, such as loans, receivables, and held-to-maturity debt securities. Under current U.S. GAAP, companies generally recognize credit losses when it is probable that the loss has been incurred. The revised guidance will remove all recognition thresholds and will require companies to recognize an allowance for credit losses for the difference between the amortized cost basis of a financial instrument and the amount of amortized cost that the Company expects to collect over the instrument’s contractual life. ASU 2016-13 is effective for fiscal years beginning after December 15, 2022, and interim periods within those fiscal years, and must be applied retrospectively. Early adoption is permitted. Epsilon will adopt ASU 2016-13 as of January 1, 2023.

In February 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, Leases (Topic 842), which will require lessees to recognize a right of use asset and a lease liability on their balance sheet for all leases, including operating leases, with a term of greater than 12 months. In July 2018, the FASB issued ASU 2018-11, which adds a transition option permitting entities to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the consolidated financial statements. Under this transition option, comparative reporting would not be required, and the provisions of the standard would be applied prospectively to leases in effect at the date of adoption.

The Company has determined its portfolio of leased assets and is completing its review of all related contracts to determine the impact the adoption will have on its consolidated financial statements and related disclosures. Upon adoption, the Company will recognize a right of use asset and lease liability for certain commitments related to office space that will be accounted for as an operating lease. To track these lease arrangements and facilitate compliance with this ASU, the Company is in the process of designing processes and internal controls.

The adoption of this ASU will increase asset and liability balances on the consolidated balance sheets due to the required recognition of a right of use asset and corresponding lease liabilities and will result in changes to the Company’s existing accounting policies, business processes, and internal controls. The Company plans to elect the available package practical expedients provided in the standard and adopt Topic 842 as of January 1, 2022 at December 31, 2022 on its Form 10-K for the year ending December 31, 2022, using the optional transition method provided by ASU 2018-11 and continues to assess potential effects of the standard.

XML

Cash, Cash Equivalents, and Restricted Cash

6 Months Ended

Jun. 30, 2022

Cash, Cash Equivalents, and Restricted Cash

Cash, Cash Equivalents, and Restricted Cash

3. Cash, Cash Equivalents, and Restricted Cash

Cash and cash equivalents include cash on hand and short term, highly liquid investments with original maturities of three months or less that are readily convertible to known amounts of cash and which are subject to an insignificant risk of changes in value.

Restricted cash consists of amounts deposited to back bonds or letters of credit for potential well liabilities. The Company presents restricted cash with cash and cash equivalents in the Consolidated Statements of Cash Flows.

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported in the Consolidated Balance Sheets to the total of the amounts in the Consolidated Statements of Cash Flows as of June 30, 2022 and December, 31 2021:

	June 30,		December 31,
	2022		2021
Cash and cash equivalents	$	30,945,605	$	26,497,305
Restricted cash included in other assets		569,407		568,118
Cash, cash equivalents and restricted cash in the statement of cash flows	$	31,515,012	$	27,065,423

XML

Property and Equipment

6 Months Ended

Jun. 30, 2022

Property and Equipment

Property and Equipment

4.  Property and Equipment

The following table summarizes the Company’s property and equipment as of June 30, 2022 and December 31, 2021:

	June 30,		December 31,
	2022		2021
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	145,697,537	$	138,032,413
Unproved properties		18,021,391		21,700,926
Accumulated depletion, depreciation, amortization and impairment		(105,047,754)		(102,480,972)
Total oil and gas properties, net		58,671,174		57,252,367
Gathering system		42,566,495		42,475,086
Accumulated depletion, depreciation, amortization and impairment		(33,995,327)		(33,443,949)
Total gathering system, net		8,571,168		9,031,137
Land		637,764		637,764
Buildings and other property and equipment, net		292,727		309,102
Total property and equipment, net	$	68,172,833	$	67,230,370

Property Impairment

Epsilon performs a quantitative impairment test quarterly or whenever events or changes in circumstances indicate that an asset group's carrying amount may not be recoverable, over proved properties using the published NYMEX forward prices, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, GAAP requires that the Company first compares expected future undiscounted cash flows by asset group to their respective carrying values. If the carrying amount exceeds the estimated undiscounted future cash flows, a reduction of the carrying amount of the oil and natural gas properties to their estimated fair values is required, which is determined based on discounted cash flow techniques using significant assumptions including projected revenues, future commodity prices, and a market-specific weighted average cost of capital which are affected by expectations about future market and economic conditions. During the three and six months ended June 30, 2022 and 2021, no impairment was required.

XML

Revolving Line of Credit

6 Months Ended

Jun. 30, 2022

Revolving Line of Credit

Revolving Line of Credit

5. Revolving Line of Credit

The Company has a senior secured revolving credit facility (“Facility”) which includes a total commitment of up to $100 million. The current borrowing base is $14 million, which is subject to semi-annual redetermination. There are currently no borrowings under the Facility. If Epsilon decided to access the Facility, depending on the level of borrowing, the Company might need to increase its hedging activity. Borrowings from the Facility may be used for the acquisition and development of oil and gas properties, investments in cash flow generating assets complimentary to the production of oil and gas, and for letters of credit and other general corporate purposes. Upon each advance, interest is charged at the highest of a) rate of LIBOR plus an applicable margin (2.75%-3.75% based on the percent of the line of credit utilized), b) the Prime Rate, or c) the sum of the Federal Funds Rate plus 0.5%.

Effective April 6, 2021, the agreement was amended to extend the maturity date to March 1, 2024. In addition, the agreement was amended to include a Benchmark Replacement definition and transition plan to be used at such time when the LIBOR rate is discontinued.

On August 2, 2022, the borrowing base of $14 million was reaffirmed until the next periodic redetermination of the borrowing base.

The lender under the Credit Facility has a first priority security interest in the tangible and intangible assets, including the gathering system, of Epsilon Energy USA, Inc. to secure any outstanding amounts under the agreement. Under the terms of the agreement, the Company must maintain the following covenants:

● Interest coverage ratio greater than 3 based on income adjusted for interest, taxes and non-cash amounts.

● Current ratio, adjusted for line of credit amounts used and available and non-cash amounts, greater than 1.

● Leverage ratio less than 3.0 based on income adjusted for interest, taxes and non-cash amounts.

The Company was in compliance with the financial covenants of the Credit Facility as of June 30, 2022 and expects to be in compliance with the financial covenants for the next 12 months.

A commitment fee of 0.50% is assessed quarterly on the daily average unused borrowing base on the Credit Facility.

	Balance at		Balance at
	June 30,		December 31,		Current		Interest Rate
	2022		2021		Borrowing Base		3 mo.
Revolving line of credit	$	—	$	—	$	14,000,000		LIBOR + 3.25% (1)

(1) At June 30, 2022, the interest rate was 4.876%.

XML

Shareholders Equity

6 Months Ended

Jun. 30, 2022

Shareholders' Equity

Shareholders' Equity

6. Shareholders’ Equity

(a)Authorized shares

The Company is authorized to issue an unlimited number of Common Shares with no par value and an unlimited number of Preferred Shares with no par value.

(b)Purchases of Equity Shares

Normal Course Issuer Bid

Commencing on March 8, 2022, the Company conducted a normal course issuer bid (“NCIB”) to repurchase our issued and outstanding common shares, when doing so was accretive to management’s estimates of intrinsic value per share. The NCIB ends on March 7, 2023. The Company uses discretionary cash to fund these repurchases. During the six months ended June 30, 2022, Epsilon repurchased 697,100 common shares of the authorized 1,183,410 purchase amount and spent $4,554,822 under the NCIB. The repurchased stock had an average price of $6.53 per share. The Company cancelled 423,000 common shares during the three months ended June 30, 2022.

Commencing on January 1, 2021, Epsilon conducted a normal course issuer bid (“NCIB”) to repurchase our issued and outstanding common shares, when doing so was accretive to management's estimates of intrinsic value per share. The NCIB ended on December 31, 2021. The Company used discretionary cash to fund these repurchases. During the year ended December 31, 2021, Epsilon repurchased 534,015 common shares of the authorized 1,193,000 purchase

amount and spent $2,423,007 under the NCIB. The repurchased stock had an average price of $4.54 per share and were subsequently cancelled during the three months ended March 31, 2022.

Repurchases may be made at management’s discretion from time to time through the facilities of the NASDAQ Global Market. The price paid for the common shares will be, subject to applicable securities laws, the prevailing market price of such common shares on the NASDAQ Global Market at the time of such purchase. The Company intends to fund the purchase out of available cash and does not expect to incur debt to fund the share repurchase program. The shares are accounted for as treasury shares until such a time as they are cancelled.

The following table contains activity relating to our acquisition of equity securities during the six months ended June 30, 2022:

				Maximum number
				of shares that
				may yet be
	Total number	Average price		purchased under
	of shares	paid per		the plans or
	purchased	share		programs
Beginning of normal-course issuer bid, March 8, 2022					1,183,410
March 2022 (1)	—	$	—
April 2022 (1)	23,700	$	6.66
May 2022 (1)	254,500	$	7.01
June 2022 (1)	418,900	$	6.24
Total as of June 30, 2022	697,100	$	6.53		486,310

(1) Epsilon repurchased these shares under its share repurchase program that commenced on March 8, 2022, as described above.

(c)Equity Incentive Plan

Epsilon’s board of directors (the “Board”) adopted the 2020 Equity Incentive Plan (the “2020 Plan”) on July 22, 2020 subject to approval by Epsilon’s shareholders at Epsilon’s 2020 Annual General and Special Meeting of Shareholders, which occurred on September 1, 2020 (the “Meeting”). Shareholders approved the 2020 Plan at the Meeting. Following Epsilon’s listing on the NASDAQ Global Market, the Board determined that it is in the best interest of the shareholders to approve a new incentive plan that is compliant with U.S. public company equity plan rules and practices that would replace Epsilon’s Amended and Restated 2017 Stock Option Plan (including its predecessors) and the Share Compensation Plan (collectively referred to as the “Predecessor Plans”). No further awards will be granted under the Predecessor Plans.

The 2020 Plan provides for incentive compensation in the form of stock options, stock appreciation rights, restricted stock and stock units, performance shares and units, other stock-based awards and cash-based awards. Under the 2020 Plan, Epsilon will be authorized to issue up to 2,000,000 Common Shares. As of December 31, 2021, the Company granted, after the Compensation Committee approved the terms, target formulas, and peer group applicable to the performance incentive awards, 20,834 common shares and 48,000 time-based restricted shares to the CEO and the board of directors.

Restricted Stock Awards

For the six months ended June 30, 2022, 89,925 shares of Restricted Stock with a weighted average market price at the grant date of $6.33 were awarded to the Company’s board of directors and employees. For the year ended December 31, 2021, 48,000 common shares of Restricted Stock with a weighted average market price at the grant date of $5.04 were awarded to the Company’s board of directors. These shares vest over a three-year period, with one-third of the shares

being issued per period on the anniversary of the award resolution. The vesting of the shares is contingent on the individuals’ continued employment or service. The Company determined the fair value of the granted Restricted Stock-based on the market price of the common shares of the Company on the date of grant.

The following table summarizes Restricted Stock activity for the six months ended June 30, 2022, and the year ended December 31, 2021:

	Six months ended		Year ended
	June 30, 2022		December 31, 2021
	Number of	Weighted	Number of	Weighted
	Restricted	Average	Restricted	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested Restricted Stock at beginning of period	166,002	1.38	290,070	1.60
Granted	89,925	1.50	48,000	3.00
Vested	—	—	(137,668)	—
Forfeited	—	—	(34,400)	—
Balance non-vested Restricted Stock at end of period	255,927	1.10	166,002	1.38

Stock compensation expense for the granted Restricted Stock is recognized over the vesting period. Stock compensation expense recognized during the three and six months ended June 30, 2022 was $146,860 and $241,972, respectively (for the three and six months ended June 30, 2021, $137,207 and $274,413, respectively).

At June 30, 2022, the Company had unrecognized stock-based compensation related to these shares of $931,239 to be recognized over a weighted average period of 1.19 years (at December 31, 2021: $696,833 over 1.11 years).

Performance Share Unit Awards (“PSU”)

For the six months ended June 30, 2022, no PSUs were awarded. For the year ended December 31, 2021, a total of 62,501 common shares vested and were issued, of which 20,834 of the common shares were granted as a result of the Company exceeding its 2020 TSR performance target. The Company grants PSUs, which are paid in stock, to certain key employees. PSUs are based on a three-year performance period with performance being measured each year at December 31. The PSUs will vest on the last day of the performance period. The number of PSUs that will ultimately vest is based on two performance targets as follows:

● The targets for the PSUs are based on (i) the relative total stockholder return (“TSR”) percentile ranking and (ii) the relative cash flow per debt adjusted share – growth (“CFDAS Growth”) percentile ranking of the Company, each as compared to the Company’s Performance Peer Group during the applicable one-year performance period ending on December 31.

● Cash Flow per Debt Adjusted Share (“CFDAS”) is defined as EBITDA (earnings before interest, taxes, depreciation and amortization) divided by the sum of the 1) the total debt plus the value of preferred stock minus cash and the amount of dividends paid for the year divided by the share price at the end of the year; and 2) the actual share count at year end.

● The vesting of each PSU Award will be based 50% on TSR performance and 50% based on CFDAS Growth performance.

● The recipient of the award must be employed with the Company at the time of vesting.

The number of shares ultimately issued under these awards can range from zero to 200% of target award amounts.

The PSUs are accounted for as equity awards. The fair value of the 50% for performance based on CFDAS Growth was determined as the market price of the common shares of the Company on the date of grant. Weighted average fair value of CFDAS PSUs granted during the year ended December 31, 2021 was $3.41 per unit. The fair value of the 50% for performance based on TSR was determined on the grant date by the application of a Monte Carlo simulation model.  For the year ended December 31, 2021, the Compensation Committee did not approve the issuance of any new PSU’s.

The Monte Carlo simulation model utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the performance stock awards, to calculate the fair value of the awards. Expected volatilities in the model were estimated using a historical period consistent with the expected term for each annual performance period of the awards. The risk-free interest rate was based on the United States Treasury rate measured over a term commensurate with the expected term for each annual performance period of the awards. The expected term is based on the time between the valuation date and the end of each annual performance period of the awards. The valuation model assumes dividends are immediately reinvested.

The following table summarizes PSUs for the six months ended June 30, 2022 and the year ended December 31, 2021:

	Six months ended		Year ended
	June 30, 2022		December 31, 2021
	Number of	Weighted	Number of	Weighted
	Performance	Average	Performance	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested PSUs at beginning of period	151,500	0.75	193,167	1.60
Granted	—	—	20,834	—
Vested	—	—	(62,501)	—
Balance non-vested PSUs at end of period	151,500	0.59	151,500	0.75

Stock compensation expense for the granted PSUs is recognized over the vesting period. Stock compensation expense recognized during the three and six months ended June 30, 2022 related to PSUs was $47,190 and $94,380, respectively (for the three and six months ended June 30, 2021, $98,835 and $164,127, respectively.

At June 30, 2022, the Company had unrecognized stock-based compensation related to these shares of $213,035 to be recognized over a weighted average period of 0.83 years (at December 31, 2021: $310,790 over 1.01 years).

Stock Options

As of June 30, 2022, the Company had outstanding stock options covering 97,500 Common Shares at an overall average exercise price of $5.03 per Common Share to directors, officers, and employees of the Company and its subsidiaries. These 97,500 options have a weighted average expected remaining term of approximately 1.56 years.

The following table summarizes stock option activity for the six months ended June 30, 2022 and the year ended December 31, 2021:

	Six months ended			Year ended
	June 30, 2022			December 31, 2021
		Weighted				Weighted
	Number of	Average		Number of		Average
	Options	Exercise		Options		Exercise
Exercise price in US$	Outstanding	Price		Outstanding		Price (1)
Balance at beginning of period	218,750	$	5.28		245,000	$	5.27
Exercised	(111,250)	$	5.47		(16,250)	$	5.25
Expired/Forfeited	(10,000)	$	5.51		(10,000)	$	5.50
Balance at period-end	97,500	$	5.03		218,750	$	5.28
Exercisable at period-end	97,500	$	5.03		218,750	$	5.28

At June 30, 2022, using the Black Scholes model, the Company had unrecognized stock-based compensation, related to these options, of nil (at December 31, 2021: nil). The aggregate intrinsic value at June 30, 2022 was $83,850 (at December 31, 2021: nil).

During the six months ended June 30, 2022 and the year ended December 31, 2021, the Company awarded no stock options.

(d) Dividends

On February 25, 2022 and May 26, 2022, the Board declared quarterly dividends of $0.0625 per common share (annualized $0.25 per common share) totaling in aggregate an amount of approximately $3.0 million that has been paid for the six months ended June 30, 2022.

XML

Revenue Recognition

6 Months Ended

Jun. 30, 2022

Revenue Recognition

Revenue Recognition

7. Revenue Recognition

Revenues are comprised primarily of sales of natural gas along with the revenue generated from the Company’s ownership interest in the Auburn gas gathering system in Northeastern Pennsylvania. Also included are natural gas, crude oil and NGL revenues from Oklahoma.

Overall, product sales revenue generally is recorded in the month when contractual delivery obligations are satisfied, which occurs when control is transferred to the Company’s customers at delivery based on contractual terms and conditions. In addition, gathering and compression revenue generally is recorded in the month when contractual service obligations are satisfied, which occurs as control of those services is transferred to the Company’s customers.

The following table details revenue for the three and six months ended June 30, 2022 and 2021.

	Three months ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Operating revenue
Natural gas	$	15,984,348	$	5,106,922	$	26,687,432	$	11,439,021
Natural gas liquids		688,397		52,529		1,002,825		98,150
Oil and condensate		1,243,091		79,303		1,704,904		140,738
Gathering and compression fees		1,987,168		1,851,095		4,107,941		3,853,252
Total operating revenue	$	19,903,004	$	7,089,849	$	33,503,102	$	15,531,161

Product Sales Revenue

The Company enters into contracts with third party purchasers to sell its natural gas, oil, NGLs and condensate production. Under these product sales arrangements, the sale of each unit of product represents a distinct performance obligation. Product sales revenue is recognized at the point in time that control of the product transfers to the purchaser based on contractual terms which reflect prevailing commodity market prices. To the extent that marketing costs are incurred by the Company prior to the transfer of control of the product, those costs are included in lease operating expenses on the Company’s consolidated statements of operations.

Settlement statements for product sales, and the related cash consideration, are received from the purchaser within 30 days. As a result, the Company must estimate the amount of production delivered to the customer and the consideration that will ultimately be received for sale of the natural gas, oil, NGLs, or condensate. Estimated revenue due to the Company is recorded within the receivables line item on the accompanying consolidated balance sheets until payment is received.

Gas Gathering and Compression Revenue

The Company also provides natural gas gathering and compression services through its ownership interest in the Auburn gas gathering system. For the provision of gas gathering and compression services, the Company collects its share of the gathering and compression fees per unit of gas serviced and recognizes gathering revenue over time using an output method based on units of gas gathered.

The settlement statement from the operator of the Auburn Gas Gathering System is received two months after transmission and compression has occurred. As a result, the Company must estimate the amount of production that was transmitted and compressed within the system. Estimated revenue due to the Company is recorded within the receivables line item on the accompanying consolidated balance sheets until payment is received.

Allowance for Doubtful Accounts

The Company records an allowance for doubtful accounts on a case-by-case basis once there is evidence that collection is not probable. For the three and six months ended June 30, 2022, there were no accounts for which collection was not probable.

The following table details accounts receivable as of June 30, 2022 and December 31, 2021.

	June 30,		December 31,
	2022		2021
Accounts receivable
Natural gas and oil sales	$	8,339,473	$	2,996,344
Joint interest billing		21,381		60,134
Gathering and compression fees		1,435,391		1,539,976
Other		134,646		477
Total accounts receivable	$	9,930,891	$	4,596,931

XML

Income Taxes

6 Months Ended

Jun. 30, 2022

Income Taxes

Income Taxes

8. Income Taxes

Income tax provisions for the three and six months ended June 30, 2022 and 2021 are as follows:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Current:
Federal	$	2,530,805	$	319,557	$	3,997,702	$	474,927
State		1,192,131		89,188		1,884,446		273,032
Total current income tax expense		3,722,936		408,745		5,882,148		747,959
Deferred:
Federal		233,599		(451,044)		255,614		212,159
State		63,041		(123,452)		63,712		18,704
Total deferred tax expense		296,640		(574,496)		319,326		230,863
Income tax expense	$	4,019,576	$	(165,751)	$	6,201,474	$	978,822

The Company files federal income tax returns in the United States and Canada, and various returns in state and local jurisdictions.

The Company believes it has appropriate support for the income tax positions taken and to be taken on our tax returns and that the accruals for tax liabilities are adequate for all open years based on our assessment of various factors including past experience and interpretations of tax law applied to the facts of each matter. The Company's tax returns are open to audit under the statute of limitations for the years ending December 31, 2018 through December 31, 2021. To the extent we utilize net operating losses generated in earlier years, such earlier years may also be subject to audit.

Our effective tax rate will typically differ from the statutory federal rate primarily as a result of state income taxes and the valuation allowance against the Canadian net operating loss. The effective tax rate for the six months ended June 30, 2022 was higher than the statutory federal rate as a result of the state income taxes and the valuation allowance against the Canadian net operating loss.

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies

Commitments and Contingencies

9. Commitments and Contingencies

The Company’s future minimum lease commitments as of June 30, 2022 are summarized in the following table:

Year ended
December 31,	Payments
2022	$	93,666
2023		62,444
	$	156,110

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of June 30, 2022, the Company had commitments of $1.5 million for capital expenditures.

Litigation

On March 10, 2021, Epsilon filed a complaint against Chesapeake Appalachia, LLC (“Chesapeake”) in the United States District Court for the Middle District of Pennsylvania, Scranton, Pennsylvania (“Middle District”). Epsilon claims that Chesapeake has breached a settlement agreement and several operating agreements (“JOAs”) to which Epsilon and Chesapeake are parties. Epsilon asserts that Chesapeake has failed to cooperate with Epsilon’s efforts to develop resources in the Auburn Development, located in North-Central Pennsylvania, as required under both the settlement agreement and JOAs.

Epsilon requested a preliminary injunction but was unsuccessful in obtaining that injunction.  Epsilon filed a motion to amend its original Complaint.  Chesapeake opposed.  The Court ruled in Epsilon’s favor and allowed Epsilon’s amendment. Chesapeake moved to dismiss the amended Complaint.  The Court granted the motion to dismiss on a narrow issue without prejudice to Epsilon’s right to file a new lawsuit based on new proposals made after the Court’s decision.  Epsilon filed a motion for reconsideration of that decision, but the court denied the motion for reconsideration on January 18, 2022.

Epsilon filed a notice of appeal on February 15, 2022 challenging both the motion to dismiss and motion for reconsideration decisions.  Chesapeake filed a cross-appeal on March 1, 2022.  A briefing schedule was set with briefing to close in October 2022.  A decision on the appeal is not expected until early to mid-2023.

Epsilon re-filed a complaint against Chesapeake in the Middle District on May 9, 2022.  Epsilon generally asserts similar claims as in the previous suit, pursuing declaratory judgment claims regarding Chesapeake’s obligation to Epsilon to cooperate with Epsilon’s efforts in the Auburn Development and regarding Chesapeake’s obstruction of Epsilon’s efforts with the Pennsylvania Department of Environmental Protection permitting process but not based on specific well proposals.  Chesapeake filed a motion to stay pending a decision on the Third Circuit appeal.  The motion to stay has been fully briefed.  Epsilon expects a decision on the motion to stay in fall 2022.  

XML

Net Income Per Share

6 Months Ended

Jun. 30, 2022

Net Income Per Share

Net Income Per Share

10. Net Income Per Share

Basic net income per share is computed on the basis of the weighted-average number of common shares outstanding during the period. Diluted net income per share is computed based upon the weighted-average number of common shares outstanding during the period plus the assumed issuance of common shares for all potentially dilutive securities.

The net income used in the calculation of basic and diluted net income per share is as follows:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Net income (loss) available to shareholders	$	10,582,988	$	(485,025)	$	16,388,876	$	2,250,542

In calculating the net income per share, basic and diluted, the following weighted-average shares were used:

	Three months ended June 30,		Six months ended June 30,
	2022	2021	2022	2021
Basic weighted-average number of shares outstanding	23,576,746	23,779,205	23,627,015	23,862,749
Dilutive stock options	25,405	—	19,630	—
Unvested time-based restricted shares	103,258	—	39,340	53,815
Unvested performance-based restricted shares	116,714	—	110,181	24,776
Diluted weighted average shares outstanding	23,822,123	23,779,205	23,796,166	23,941,340

The company excluded the following shares from the diluted EPS because their inclusion would have been anti-dilutive.

	Three months ended June 30,		Six months ended June 30,
	2022	2021	2022	2021
Anti-dilutive options	72,095	—	77,870	—
Anti-dilutive unvested time-based restricted shares	146,740	77,023	169,127	—
Anti-dilutive unvested performance-based restricted shares	34,786	36,567	41,319	—
Total Anti-dilutive shares	253,621	113,590	288,316	—

XML

Operating Segments

6 Months Ended

Jun. 30, 2022

Operating Segments.

Operating Segments

11. Operating Segments

Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision-maker. The chief operating decision-maker, who is responsible for allocating resources and assessing performance of the operating segments, has been identified as executive management. Segment performance is evaluated based on operating profit or loss as shown in the table below. Interest income and expense, and income taxes are managed separately on a group basis.

The Company’s reportable segments are as follows:

a. The Upstream segment activities include acquisition, development and production of oil, natural gas, and other liquid reserves on properties within the United States;

b. The Gas Gathering segment partners with two other companies to operate a natural gas gathering system; and

c. The Corporate segment activities include corporate listing and governance functions of the Company.

Segment activity as of, and for the six months ended June 30, 2022 and 2021 is as follows:

	Upstream		Gas Gathering		Corporate			Elimination		Consolidated
As of and for the six months ended June 30, 2022
Operating revenue
Natural gas	$	26,687,432	$	—	$	—		$	—	$	26,687,432
Natural gas liquids		1,002,825		—		—			—		1,002,825
Oil and condensate		1,704,904		—		—			—		1,704,904
Gathering and compression fees		—		4,842,838		—			(734,897)		4,107,941
Total operating revenue (1)	$	29,395,161	$	4,842,838	$	—		$	(734,897)	$	33,503,102
Net earnings (loss) for the period	$	22,359,572	$	3,222,690	$	(9,193,386)	(3)	$	—	$	16,388,876
Operating costs		4,392,404		1,065,603		—			(734,897)		4,723,110
Development geological and geophysical expenses		4,772		—		—			—		4,772
Depletion, depreciation, amortization and accretion		2,638,413		554,545		—			—		3,192,958
Segment assets	$	99,313,811	$	10,732,117	$	754,360		$	—	$	110,800,287
Capital expenditures (2)		4,001,802		91,409		—			—		4,093,211
Proved properties (net)		40,649,783		—		—			—		40,649,783
Unproved properties (net)		18,021,391		—		—			—		18,021,391
Gathering system (net)		—		8,571,168		—			—		8,571,168
Lease right-of-use-asset		—		—		—			—		—
Other property and equipment (net)		930,491		—		—			—		930,491
As of and for the six months ended June 30, 2021
Operating revenue
Natural gas	$	11,439,021	$	—	$	—		$	—	$	11,439,021
Natural gas liquids		98,150		—		—			—		98,150
Oil and condensate		140,738		—		—			—		140,738
Gathering and compression fees		—		4,623,548		—			(770,296)		3,853,252
Total operating revenue (1)	$	11,677,909	$	4,623,548	$	—		$	(770,296)	$	15,531,161
Net earnings (loss) for the period	$	5,684,536	$	2,751,860	$	(6,185,854)	(3)	$	—	$	2,250,542
Operating costs		3,378,327		1,134,790		—			(770,296)		3,742,821
Development geological and geophysical expenses		22,990		—		—			—		22,990
Depletion, depreciation, amortization and accretion		2,592,056		736,898		—			—		3,328,954
Segment assets	$	78,621,390	$	11,941,329	$	133,220		$	—	$	90,695,939
Capital expenditures (2)		2,374,115		70,504		—			—		2,444,619
Proved properties (net)		34,531,736		—		—			—		34,531,736
Unproved properties (net)		21,557,121		—		—			—		21,557,121
Gathering system (net)		—		9,437,587		—			—		9,437,587
Other property and equipment (net)		964,435		—		—			—		964,435

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the six months ended June 30, 2022 and 2021 have been eliminated upon consolidation. For the six months ended June 30, 2022, Epsilon sold natural gas to 21 unique customers. The two customers over 10% comprised 23% and 19% of total revenue. For the six months ended June 30, 2021, Epsilon sold natural gas to 25 unique customers. The two customers over 10% comprised 35% and 10% of total revenue.

(2) Capital expenditures for the Upstream segment consist primarily of the acquisition of properties, and the drilling and completing of wells while Gas Gathering consists of expenditures relating to the expansion and completion of the gathering and compression facility.

(3) Segment reporting for net earnings for the period does not include non-monetary compensation, general and administrative expense, interest income, interest expense, both gains and (losses) on derivative contracts, or income tax amounts as they are managed on a group basis and are instead included in the corporate column for reconciliation purposes.

Segment activity for the three months ended June 30, 2022 and 2021 is as follows:

	Upstream			Gas Gathering		Corporate			Elimination		Consolidated
For the three months ended June 30, 2022
Operating revenue
Natural gas	$	15,984,348		$	—	$	—		$	—	$	15,984,348
Natural gas liquids		688,397			—		—			—		688,397
Oil and condensate		1,243,091			—		—			—		1,243,091
Gathering and compression fees		—			2,356,901		—			(369,733)		1,987,168
Total operating revenue	$	17,915,836	(1)	$	2,356,901	$	—		$	(369,733)		19,903,004
Net earnings (loss) for the period	$	13,757,784		$	1,545,850	$	(4,720,646)	(3)		—	$	10,582,988
Operating costs		2,621,750			541,228		—			(369,733)		2,793,245
Development geological and geophysical expenses		2,386			—		—			—		2,386
Depletion, depreciation, amortization and accretion		1,533,916			269,823		—			—		1,803,739
Bad debt expense		—			—		—			—		—
Capital expenditures(2)		1,390,908			76,016		—			—		1,466,924
For the three months ended June 30, 2021
Operating revenue
Natural gas	$	5,106,922		$	—	$	—		$	—	$	5,106,922
Natural gas liquids		52,529			—		—			—		52,529
Oil and condensate		79,303			—		—			—		79,303
Gathering and compression fees		—			2,236,960		—			(385,865)		1,851,095
Total operating revenue	$	5,238,754	(1)	$	2,236,960	$	—		$	(385,865)		7,089,849
Net earnings (loss) for the period	$	2,153,394		$	1,321,225	$	(3,959,644)	(3)	$	—	$	(485,025)
Operating costs		1,784,138			559,412		—			(385,865)		1,957,685
Development geological and geophysical expenses		11,451			—		—			—		11,451
Depletion, depreciation, amortization and accretion		1,289,771			356,323		—			—		1,646,094
Bad Debt Expense		—			—		—			—		—
Capital expenditures(2)		1,459,675			57,220		—			—		1,516,895

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended June 30, 2022 and 2021 have been eliminated upon consolidation. For the three months ended June 30, 2022, Epsilon sold natural gas to 19 unique customers. The four customers over 10% comprised 33%, 17%, 12% and 10% of total revenue. For the three months ended June 30, 2021, Epsilon sold natural gas to 21 unique customers. The two customers over 10% comprised 23% and 19% of total revenue.

(2) Capital expenditures for the Upstream segment consist primarily of the acquisition of properties, and the drilling and completing of wells while Gas Gathering consists of expenditures relating to the expansion and completion of the gathering and compression facility.

(3) Segment reporting for net earnings for the period does not include non-monetary compensation, general and administrative expense, interest income, interest expense, both gains and (losses) on derivative contracts, or income tax amounts as they are managed on a group basis and are instead included in the corporate column for reconciliation purposes.

XML

Commodity Risk Management Activities

6 Months Ended

Jun. 30, 2022

Commodity Risk Management Activities

Commodity Risk Management Activities

12. Commodity Risk Management Activities

Commodity Price Risks

Epsilon engages in price risk management activities from time to time. These activities are intended to manage Epsilon’s exposure to fluctuations in commodity prices for natural gas by securing derivative contracts for a portion of expected sales volumes.

Inherent in the Company’s hedging program, are certain business risks, including market risk and credit risk. Market risk is the risk that the price of natural gas and oil will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by the Company’s counterparty to a contract. Additionally, there is a risk that gas prices could fall to a level low enough to affect the volumes flowing through the gathering system.

The Company enters into certain commodity derivative instruments to mitigate commodity price risk associated with a portion of its future natural gas production and related cash flows. The natural gas revenues and cash flows are affected by changes in commodity product prices, which are volatile and cannot be accurately predicted. The objective for holding these commodity derivatives is to protect the operating revenues and cash flows related to a portion of the future natural gas sales from the risk of significant declines in commodity prices, which helps ensure the Company’s ability to fund the capital budget.

Epsilon has historically elected not to designate any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for these financial commodity derivative contracts using the mark-to-market accounting method. Under this accounting method, changes in the fair value of outstanding financial instruments are recognized as gains or losses in the period of change and are recorded as loss (gain) on derivative contracts on the condensed consolidated statements of operations and comprehensive income (loss). The related cash flow impact is reflected in cash flows from operating activities. During the three and six months ended June 30, 2022, Epsilon recognized gains (losses) on commodity derivative contracts of $776,994 and ($194,910), respectively. This amount included cash paid on settlements on these contracts of $163,559 and $1,375,287, respectively. For the three and six months ended June 30, 2021, Epsilon recognized losses on commodity derivative contracts of $1,827,334 and $1,361,993, respectively. This amount included cash paid on settlements on these contracts of $91,660 and $27,460, respectively.

Commodity Derivative Contracts

Presented below is a summary of Epsilon’s natural gas commodity basis swap and two-way costless collar contracts as of June 30, 2022.

								Fair Value
	Volume	Ceiling		Floor		Basis		June 30,
Derivative Type	(MMbtu)	Price		Price		Differential		2022
2022
Basis swap	765,000					$	(1.15)		7,788
Two-way costless collar	765,000	$	8.20	$	6.50				932,765
								$	940,553

As of June 30, 2022, all of the Company’s economic derivative hedge positions were with large financial institutions, which are not known to the Company to be in default on their derivative positions. The Company is exposed to credit risk to the extent of non-performance by the counterparties in the derivative contracts discussed above; however, the Company does not anticipate non-performance by such counterparties. None of the Company’s derivative instruments contains credit-risk related contingent features. Derivatives are net on the balance sheet as they are subject to the right to offset the liabilities with the assets.

The following tables summarize the gross fair values of our derivative instruments, presenting the impact of offsetting the derivative assets and liabilities on our condensed consolidated balance sheets as of the dates indicated below:

	Fair Value of Derivative  Assets
	June 30,		December 31,
	2022		2021
Current
Basis swap	$	90,782	$	—
Two-way costless collar	$	1,063,754	$	13,312
	$	1,154,537	$	13,312

	Fair Value of Derivative  Liabilities
	June 30,		December 31,
	2022		2021
Current
Basis swap	$	(82,994)	$	—
Two-way costless collar	$	(130,989)	$	(253,136)
	$	(213,984)	$	(253,136)
Net Fair Value of Derivatives	$	940,553	$	(239,824)

The following table presents the changes in the fair value of Epsilon’s commodity derivatives for the periods indicated:

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Fair value of asset (liability), beginning of the period	$	—	$	401,141	$	(239,824)	$	—
Gains (losses) on derivative contracts included in earnings		776,994		(1,827,334)		(194,910)		(1,361,992)
Settlement of commodity derivative contracts		163,559		91,660		1,375,287		27,459
Fair value of asset (liability), end of the period	$	940,553	$	(1,334,533)	$	940,553	$	(1,334,533)

XML

Asset Retirement Obligations

6 Months Ended

Jun. 30, 2022

Asset Retirement Obligations

Asset Retirement Obligations

13. Asset Retirement Obligations

Asset retirement obligations were estimated by management based on Epsilon’s net ownership interest in all wells and the gathering system, estimated costs to reclaim and abandon such assets and the estimated timing of the costs to be incurred in future periods.

The following tables summarize the changes in asset retirement obligations for the periods indicated:

	Six Months Ended		Year ended
		June 30,		December 31,
	2022		2021
Balance beginning of period	$	2,833,656	$	3,150,243
Liabilities acquired		6,684		7,009
Liabilities disposed of		(24,854)		(381,346)
Wells plugged and abandoned		(118,259)		(31,945)
Change in estimates		—		(8,299)
Accretion		38,738		97,994
Balance end of period	$	2,735,965	$	2,833,656

XML

Fair Value Measurements

6 Months Ended

Jun. 30, 2022

Fair Value Measurements

Fair Value Measurements

14. Fair Value Measurements

The methodologies used to determine the fair value of our financial assets and liabilities at June 30, 2022 were the same as those used at December 31, 2021.

Cash and cash equivalents, restricted cash, accounts receivable, accounts payable and accrued liabilities are carried at cost, which approximates their fair value because of the short-term maturity of these instruments. The Company’s revolving line of credit has a recorded value that approximates its fair value since its variable interest rate is tied to current market rates and the applicable margins represent market rates.

Commodity derivative instruments consist of two-way costless collar and basis swap contracts for natural gas. The Company’s derivative contracts are valued based on a marked to market approach. These assumptions are observable in the marketplace throughout the full term of the contract, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace, and are therefore designated as Level 2 within the valuation hierarchy. The Company utilizes its counterparties’ valuations to assess the reasonableness of its own valuations.

XML

Basis of Preparation (Policies)

6 Months Ended

Jun. 30, 2022

Basis of Preparation

Interim Financial Statements

Interim Financial Statements

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and with the appropriate rules and regulations of the SEC. Accordingly, certain information and footnote disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations. All adjustments which are, in the opinion of management, necessary for a fair presentation of the financial position and results of operations for the interim periods presented have been included. The interim financial information and notes hereto should be read in conjunction with the Company’s consolidated financial statements as of and for the year ended December 31, 2021. The results of operations for interim periods are not necessarily indicative of results to be expected for a full fiscal year.

Principles of Consolidation

Principles of Consolidation

The Company’s unaudited condensed consolidated financial statements include the accounts of the Company and its wholly owned subsidiary, Epsilon Energy USA, Inc. and its wholly owned subsidiaries, Epsilon Midstream, LLC, Dewey Energy GP, LLC, Dewey Energy Holdings, LLC, Epsilon Operating, LLC, and Altolisa Holdings, LLC. With regard to the gathering system, in which Epsilon owns an undivided interest in the asset, proportionate consolidation accounting is used. All inter-company transactions have been eliminated.

Use of Estimates

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The most significant estimates pertain to proved natural gas and oil reserves and related cash flow estimates used in impairment tests of natural gas and oil, and gathering system properties, asset retirement obligations, accrued natural gas and oil revenues and operating expenses, accrued gathering system revenues and operating expenses, as well as the valuation of commodity derivative instruments. Actual results could differ from those estimates.

Recently Issued Accounting Standards

Recently Issued Accounting Standards

The Company, an emerging growth company (“EGC”), has elected to take advantage of the benefits of the extended transition period provided for in Section 7(a)(2)(B) of the Securities Act, for complying with new or revised accounting standards which allows the Company to defer adoption of certain accounting standards until those standards would otherwise apply to private companies.

In March 2020, the FASB issued ASU No. 2020-04 - Reference Rate Reform (Topic 848), codified as ASC 848 (“ASC 848”). This was followed by ASU No. 2021-01, Reference Rate Reform (Topic 848): Scope (“ASU 2021-01”), issued in January 2021. The purpose of ASC 848 is to provide optional guidance to ease the potential effects on financial

reporting of the market-wide migration away from Interbank Offered Rates (“IBORs”) to alternative reference rates. ASC 848 applies only to contracts, hedging relationships, and other transactions that reference a reference rate expected to be discontinued because of reference rate reform. The guidance may be applied upon issuance of ASC 848 through December 31, 2022. We do not expect a material impact from the adoption of this ASU.

In June 2016 the FASB issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, which removes the thresholds that companies apply to measure credit losses on financial instruments measured at amortized cost, such as loans, receivables, and held-to-maturity debt securities. Under current U.S. GAAP, companies generally recognize credit losses when it is probable that the loss has been incurred. The revised guidance will remove all recognition thresholds and will require companies to recognize an allowance for credit losses for the difference between the amortized cost basis of a financial instrument and the amount of amortized cost that the Company expects to collect over the instrument’s contractual life. ASU 2016-13 is effective for fiscal years beginning after December 15, 2022, and interim periods within those fiscal years, and must be applied retrospectively. Early adoption is permitted. Epsilon will adopt ASU 2016-13 as of January 1, 2023.

In February 2016, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, Leases (Topic 842), which will require lessees to recognize a right of use asset and a lease liability on their balance sheet for all leases, including operating leases, with a term of greater than 12 months. In July 2018, the FASB issued ASU 2018-11, which adds a transition option permitting entities to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the consolidated financial statements. Under this transition option, comparative reporting would not be required, and the provisions of the standard would be applied prospectively to leases in effect at the date of adoption.

The Company has determined its portfolio of leased assets and is completing its review of all related contracts to determine the impact the adoption will have on its consolidated financial statements and related disclosures. Upon adoption, the Company will recognize a right of use asset and lease liability for certain commitments related to office space that will be accounted for as an operating lease. To track these lease arrangements and facilitate compliance with this ASU, the Company is in the process of designing processes and internal controls.

The adoption of this ASU will increase asset and liability balances on the consolidated balance sheets due to the required recognition of a right of use asset and corresponding lease liabilities and will result in changes to the Company’s existing accounting policies, business processes, and internal controls. The Company plans to elect the available package practical expedients provided in the standard and adopt Topic 842 as of January 1, 2022 at December 31, 2022 on its Form 10-K for the year ending December 31, 2022, using the optional transition method provided by ASU 2018-11 and continues to assess potential effects of the standard.

XML

Cash, Cash Equivalents, and Restricted Cash (Tables)

6 Months Ended

Jun. 30, 2022

Cash, Cash Equivalents, and Restricted Cash

Schedule of cash, cash equivalents and restricted cash

	June 30,		December 31,
	2022		2021
Cash and cash equivalents	$	30,945,605	$	26,497,305
Restricted cash included in other assets		569,407		568,118
Cash, cash equivalents and restricted cash in the statement of cash flows	$	31,515,012	$	27,065,423

XML

Property and Equipment (Tables)

6 Months Ended

Jun. 30, 2022

Property and Equipment

Schedule of property and equipment

	June 30,		December 31,
	2022		2021
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	145,697,537	$	138,032,413
Unproved properties		18,021,391		21,700,926
Accumulated depletion, depreciation, amortization and impairment		(105,047,754)		(102,480,972)
Total oil and gas properties, net		58,671,174		57,252,367
Gathering system		42,566,495		42,475,086
Accumulated depletion, depreciation, amortization and impairment		(33,995,327)		(33,443,949)
Total gathering system, net		8,571,168		9,031,137
Land		637,764		637,764
Buildings and other property and equipment, net		292,727		309,102
Total property and equipment, net	$	68,172,833	$	67,230,370

XML

Revolving Line of Credit (Tables)

6 Months Ended

Jun. 30, 2022

Revolving Line of Credit

Schedule of revolving line of credit

	Balance at		Balance at
	June 30,		December 31,		Current		Interest Rate
	2022		2021		Borrowing Base		3 mo.
Revolving line of credit	$	—	$	—	$	14,000,000		LIBOR + 3.25% (1)

(1) At June 30, 2022, the interest rate was 4.876%.

XML

Shareholders Equity (Tables)

6 Months Ended

Jun. 30, 2022

Shareholders' Equity

Schedule of purchases of equity Shares

Schedule of restricted stock activity

	Six months ended		Year ended
	June 30, 2022		December 31, 2021
	Number of	Weighted	Number of	Weighted
	Restricted	Average	Restricted	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested Restricted Stock at beginning of period	166,002	1.38	290,070	1.60
Granted	89,925	1.50	48,000	3.00
Vested	—	—	(137,668)	—
Forfeited	—	—	(34,400)	—
Balance non-vested Restricted Stock at end of period	255,927	1.10	166,002	1.38

Schedule of PSU activity

	Six months ended		Year ended
	June 30, 2022		December 31, 2021
	Number of	Weighted	Number of	Weighted
	Performance	Average	Performance	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested PSUs at beginning of period	151,500	0.75	193,167	1.60
Granted	—	—	20,834	—
Vested	—	—	(62,501)	—
Balance non-vested PSUs at end of period	151,500	0.59	151,500	0.75

Summary of stock option activity

	Six months ended			Year ended
	June 30, 2022			December 31, 2021
		Weighted				Weighted
	Number of	Average		Number of		Average
	Options	Exercise		Options		Exercise
Exercise price in US$	Outstanding	Price		Outstanding		Price (1)
Balance at beginning of period	218,750	$	5.28		245,000	$	5.27
Exercised	(111,250)	$	5.47		(16,250)	$	5.25
Expired/Forfeited	(10,000)	$	5.51		(10,000)	$	5.50
Balance at period-end	97,500	$	5.03		218,750	$	5.28
Exercisable at period-end	97,500	$	5.03		218,750	$	5.28

XML

Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2022

Revenue Recognition

Summary of revenue

	Three months ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Operating revenue
Natural gas	$	15,984,348	$	5,106,922	$	26,687,432	$	11,439,021
Natural gas liquids		688,397		52,529		1,002,825		98,150
Oil and condensate		1,243,091		79,303		1,704,904		140,738
Gathering and compression fees		1,987,168		1,851,095		4,107,941		3,853,252
Total operating revenue	$	19,903,004	$	7,089,849	$	33,503,102	$	15,531,161

Schedule of accounts receivable net of allowance for doubtful accounts

	June 30,		December 31,
	2022		2021
Accounts receivable
Natural gas and oil sales	$	8,339,473	$	2,996,344
Joint interest billing		21,381		60,134
Gathering and compression fees		1,435,391		1,539,976
Other		134,646		477
Total accounts receivable	$	9,930,891	$	4,596,931

XML

Income Taxes (Tables)

6 Months Ended

Jun. 30, 2022

Income Taxes

Schedule of current and deferred tax expense (benefit)

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Current:
Federal	$	2,530,805	$	319,557	$	3,997,702	$	474,927
State		1,192,131		89,188		1,884,446		273,032
Total current income tax expense		3,722,936		408,745		5,882,148		747,959
Deferred:
Federal		233,599		(451,044)		255,614		212,159
State		63,041		(123,452)		63,712		18,704
Total deferred tax expense		296,640		(574,496)		319,326		230,863
Income tax expense	$	4,019,576	$	(165,751)	$	6,201,474	$	978,822

XML

Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies

Schedule of future minimum lease commitments

Year ended
December 31,	Payments
2022	$	93,666
2023		62,444
	$	156,110

XML

Net Income Per Share (Tables)

6 Months Ended

Jun. 30, 2022

Net Income Per Share

Schedule of net income used in the calculation of basic and diluted net income per share

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Net income (loss) available to shareholders	$	10,582,988	$	(485,025)	$	16,388,876	$	2,250,542

Schedule of weighted-average shares used in calculation of net income per share

	Three months ended June 30,		Six months ended June 30,
	2022	2021	2022	2021
Basic weighted-average number of shares outstanding	23,576,746	23,779,205	23,627,015	23,862,749
Dilutive stock options	25,405	—	19,630	—
Unvested time-based restricted shares	103,258	—	39,340	53,815
Unvested performance-based restricted shares	116,714	—	110,181	24,776
Diluted weighted average shares outstanding	23,822,123	23,779,205	23,796,166	23,941,340

Schedule of anti-dilutive shares

	Three months ended June 30,		Six months ended June 30,
	2022	2021	2022	2021
Anti-dilutive options	72,095	—	77,870	—
Anti-dilutive unvested time-based restricted shares	146,740	77,023	169,127	—
Anti-dilutive unvested performance-based restricted shares	34,786	36,567	41,319	—
Total Anti-dilutive shares	253,621	113,590	288,316	—

XML

Operating Segments (Tables)

6 Months Ended

Jun. 30, 2022

Operating Segments.

Schedule of segment financial information

	Upstream		Gas Gathering		Corporate			Elimination		Consolidated
As of and for the six months ended June 30, 2022
Operating revenue
Natural gas	$	26,687,432	$	—	$	—		$	—	$	26,687,432
Natural gas liquids		1,002,825		—		—			—		1,002,825
Oil and condensate		1,704,904		—		—			—		1,704,904
Gathering and compression fees		—		4,842,838		—			(734,897)		4,107,941
Total operating revenue (1)	$	29,395,161	$	4,842,838	$	—		$	(734,897)	$	33,503,102
Net earnings (loss) for the period	$	22,359,572	$	3,222,690	$	(9,193,386)	(3)	$	—	$	16,388,876
Operating costs		4,392,404		1,065,603		—			(734,897)		4,723,110
Development geological and geophysical expenses		4,772		—		—			—		4,772
Depletion, depreciation, amortization and accretion		2,638,413		554,545		—			—		3,192,958
Segment assets	$	99,313,811	$	10,732,117	$	754,360		$	—	$	110,800,287
Capital expenditures (2)		4,001,802		91,409		—			—		4,093,211
Proved properties (net)		40,649,783		—		—			—		40,649,783
Unproved properties (net)		18,021,391		—		—			—		18,021,391
Gathering system (net)		—		8,571,168		—			—		8,571,168
Lease right-of-use-asset		—		—		—			—		—
Other property and equipment (net)		930,491		—		—			—		930,491
As of and for the six months ended June 30, 2021
Operating revenue
Natural gas	$	11,439,021	$	—	$	—		$	—	$	11,439,021
Natural gas liquids		98,150		—		—			—		98,150
Oil and condensate		140,738		—		—			—		140,738
Gathering and compression fees		—		4,623,548		—			(770,296)		3,853,252
Total operating revenue (1)	$	11,677,909	$	4,623,548	$	—		$	(770,296)	$	15,531,161
Net earnings (loss) for the period	$	5,684,536	$	2,751,860	$	(6,185,854)	(3)	$	—	$	2,250,542
Operating costs		3,378,327		1,134,790		—			(770,296)		3,742,821
Development geological and geophysical expenses		22,990		—		—			—		22,990
Depletion, depreciation, amortization and accretion		2,592,056		736,898		—			—		3,328,954
Segment assets	$	78,621,390	$	11,941,329	$	133,220		$	—	$	90,695,939
Capital expenditures (2)		2,374,115		70,504		—			—		2,444,619
Proved properties (net)		34,531,736		—		—			—		34,531,736
Unproved properties (net)		21,557,121		—		—			—		21,557,121
Gathering system (net)		—		9,437,587		—			—		9,437,587
Other property and equipment (net)		964,435		—		—			—		964,435

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the six months ended June 30, 2022 and 2021 have been eliminated upon consolidation. For the six months ended June 30, 2022, Epsilon sold natural gas to 21 unique customers. The two customers over 10% comprised 23% and 19% of total revenue. For the six months ended June 30, 2021, Epsilon sold natural gas to 25 unique customers. The two customers over 10% comprised 35% and 10% of total revenue.

(2) Capital expenditures for the Upstream segment consist primarily of the acquisition of properties, and the drilling and completing of wells while Gas Gathering consists of expenditures relating to the expansion and completion of the gathering and compression facility.

(3) Segment reporting for net earnings for the period does not include non-monetary compensation, general and administrative expense, interest income, interest expense, both gains and (losses) on derivative contracts, or income tax amounts as they are managed on a group basis and are instead included in the corporate column for reconciliation purposes.

Segment activity for the three months ended June 30, 2022 and 2021 is as follows:

XML

Commodity Risk Management Activities (Tables)

6 Months Ended

Jun. 30, 2022

Commodity Risk Management Activities

Schedule of fair value of derivatives

	Fair Value of Derivative  Assets
	June 30,		December 31,
	2022		2021
Current
Basis swap	$	90,782	$	—
Two-way costless collar	$	1,063,754	$	13,312
	$	1,154,537	$	13,312

	Fair Value of Derivative  Liabilities
	June 30,		December 31,
	2022		2021
Current
Basis swap	$	(82,994)	$	—
Two-way costless collar	$	(130,989)	$	(253,136)
	$	(213,984)	$	(253,136)
Net Fair Value of Derivatives	$	940,553	$	(239,824)

Schedule of fair value of derivatives rollforward

	Three months ended June 30,				Six months ended June 30,
	2022		2021		2022		2021
Fair value of asset (liability), beginning of the period	$	—	$	401,141	$	(239,824)	$	—
Gains (losses) on derivative contracts included in earnings		776,994		(1,827,334)		(194,910)		(1,361,992)
Settlement of commodity derivative contracts		163,559		91,660		1,375,287		27,459
Fair value of asset (liability), end of the period	$	940,553	$	(1,334,533)	$	940,553	$	(1,334,533)

XML

Asset Retirement Obligations (Tables)

6 Months Ended

Jun. 30, 2022

Asset Retirement Obligations

Schedule of activity in asset retirement obligations

	Six Months Ended		Year ended
		June 30,		December 31,
	2022		2021
Balance beginning of period	$	2,833,656	$	3,150,243
Liabilities acquired		6,684		7,009
Liabilities disposed of		(24,854)		(381,346)
Wells plugged and abandoned		(118,259)		(31,945)
Change in estimates		—		(8,299)
Accretion		38,738		97,994
Balance end of period	$	2,735,965	$	2,833,656

XML

Cash, Cash Equivalents, and Restricted Cash - Reconciliation of Cash (Details) - USD ($)	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
Summary of Significant Accounting Policies
Cash and cash equivalents	$ 30,945,605	$ 26,497,305
Restricted cash included in other assets	569,407	568,118
Cash, cash equivalents and restricted cash in the statement of cash flows	$ 31,515,012	$ 27,065,423	$ 19,094,876	$ 13,836,771

XML

Property and Equipment (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2021	Dec. 31, 2021	Jun. 30, 2022
Oil and gas properties, successful efforts method
Proved properties		$ 138,032,413	$ 145,697,537
Unproved properties	$ 21,557,121	21,700,926	18,021,391
Accumulated depletion, depreciation, amortization and impairment		(102,480,972)	(105,047,754)
Total oil and gas properties, net		57,252,367	58,671,174
Gathering system		42,475,086	42,566,495
Accumulated depletion, depreciation, amortization and impairment		(33,443,949)	(33,995,327)
Total gathering system, net	9,437,587	9,031,137	8,571,168
Land		637,764	637,764
Buildings and other property and equipment, net		309,102	292,727
Total property and equipment, net		67,230,370	$ 68,172,833
Impairment	$ 0	$ 0

XML

Revolving Line of Credit (Details) - Revolving Credit Facility - USD ($)	6 Months Ended
	Jun. 30, 2022	Nov. 23, 2021
Revolving Credit Facility
Total commitments	$ 100,000,000
Current borrowing base	$ 14,000,000	$ 14,000,000
Minimum
Revolving Credit Facility
Leverage ratio	3.0
LIBOR
Revolving Credit Facility
Margin added to variable interest rate	3.25%
LIBOR | Minimum
Revolving Credit Facility
Margin added to variable interest rate	2.75%
LIBOR | Maximum
Revolving Credit Facility
Margin added to variable interest rate	3.75%
Federal Funds Rate
Revolving Credit Facility
Margin added to variable interest rate	0.50%

XML

Revolving Line of Credit - Ratios (Details) - Revolving Credit Facility	6 Months Ended
	Jun. 30, 2022 USD ($)	Nov. 23, 2021 USD ($)
Revolving Credit Facility
Interest coverage ratio	3
Current ratio	1
Commitment fee assessed quarterly on the daily average unused commitments	0.50%
Current borrowing base	$ 14,000,000	$ 14,000,000
Interest rate during the period	4.876%
LIBOR
Revolving Credit Facility
Margin added to variable interest rate	3.25%

XML

Shareholders Equity - Share Capital (Details) - $ / shares	Jun. 30, 2022	Dec. 31, 2021
Components of share capital:
Common Stock, No Par Value	$ 0	$ 0
Preferred Stock, No Par Value	$ 0	$ 0

XML

Shareholders Equity - Purchases of Equity Shares (Details) - USD ($)	1 Months Ended			3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2022	May 31, 2022	Apr. 30, 2022	Jun. 30, 2022	Jun. 30, 2022	Dec. 31, 2021	Mar. 08, 2022
Shareholders' Equity
Authorized shares to be repurchased	486,310			486,310	486,310	1,193,000	1,183,410
Purchased shares				423,000
Number of shares purchased	418,900	254,500	23,700		697,100
Authorized amount repurchase							$ 4,554,822
Shares purchased						534,015
Consideration for shares repurchased						$ 2,423,007
Average price paid per share	$ 6.24	$ 7.01	$ 6.66		$ 6.53	$ 4.54

XML

Shareholders Equity - Equity Incentive Plan (Details) - shares	6 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized to be issued	2,000,000
Performance stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)	0	20,834
Time-based restricted shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)		48,000

XML

Shareholders Equity - Restricted Stock (Details) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Share Compensation Plan
Weighted average market price at grant date (in dollars per share)			$ 6.33
Restricted stock awards
Share Compensation Plan
Grant date fair value (in dollars per share)					$ 5.04
Vesting period					3 years
Vesting percentage					33.33%
Stock based compensation expense	$ 146,860	$ 137,207	$ 241,972	$ 274,413
Compensation cost not yet recognized	$ 931,239		$ 931,239		$ 696,833
Weighted average period for recognition			1 year 2 months 8 days		1 year 1 month 9 days
Number outstanding
Balance non-vested Restricted Stock at beginning of period (in shares)			166,002	290,070	290,070
Granted (in shares)			89,925		48,000
Vested (in shares)			0		(137,668)
Forfeited (in shares)			0		(34,400)
Balance non-vested Restricted Stock at end of period (in shares)	255,927		255,927		166,002	290,070
Weighted Average Remaining Life
Granted (in years)			1 year 6 months		3 years
Balance non-vested Restricted Stock at end of period (in years)			1 year 1 month 6 days		1 year 4 months 17 days	1 year 7 months 6 days

XML

Shareholders Equity - Performance Stock Units Assumptions (Details) - Performance stock units	6 Months Ended	12 Months Ended
	Jun. 30, 2022 item shares	Dec. 31, 2021 $ / shares shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of performance targets | item	2
Performance period	3 years
Vesting percentage		50.00%
Vested (in shares)		62,501
Granted (in shares)	0	20,834
CFDAS
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average grant-date fair value per PSU | $ / shares		$ 3.41
Vesting percentage	50.00%	50.00%
TSR performance
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance period	1 year
Vesting percentage	50.00%
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of number of shares issued on target award amounts	0.00%
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of number of shares issued on target award amounts	200.00%

XML

Shareholders Equity - Performance Stock Units (Details) - Performance stock units - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Share Compensation Plan
Stock based compensation expense	$ 47,190	$ 98,835	$ 94,380	$ 164,127
Compensation cost not yet recognized	$ 213,035		$ 213,035		$ 310,790
Weighted average period for recognition			9 months 29 days		1 year 3 days
Number outstanding
Balance non-vested Restricted Stock at beginning of period (in shares)			151,500	193,167	193,167
Granted (in shares)			0		20,834
Vested (in shares)					(62,501)
Balance non-vested Restricted Stock at end of period (in shares)	151,500		151,500		151,500	193,167
Weighted Average Remaining Life
Balance non-vested Restricted Stock at end of period (in years)			7 months 2 days		9 months	1 year 7 months 6 days

XML

Shareholders Equity - Stock Option Activity (Details) - Stock option - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Number of Options Outstanding
Balance at beginning of period (in shares)	218,750	245,000
Exercised (in shares)	(111,250)	(16,250)
Expired/Forfeited (in shares)	(10,000)	(10,000)
Balance at period-end (in shares)	97,500	218,750
Exercisable at period-end (in shares)	97,500	218,750
Weighted average exercise price
Balance at beginning of period (in dollars per share)	$ 5.28	$ 5.27
Exercised (in dollars per share)	5.47	5.25
Expired/Forfeited (in dollars per share)	5.51	5.50
Balance at period-end (in dollars per share)	5.03	5.28
Exercisable at period-end (in dollars per share)	$ 5.03	$ 5.28
Additional disclosures
Weighted average expected remaining term	1 year 6 months 21 days

XML

Shareholders Equity - Stock Option Activity, Narrative (Details) - Stock option - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Share Compensation Plan
Unrecognized stock based compensation to be recognized over a period	$ 0	$ 0
Aggregate intrinsic value of options outstanding	$ 83,850	$ 0
Granted (in shares)	0	0

XML

Shareholders' Equity - Dividends (Details) - USD ($)		6 Months Ended
	Feb. 25, 2022	Jun. 30, 2022	Jun. 30, 2021
Shareholders' Equity
Cash dividend of common stock (in dollars per share)	$ 0.0625
Annual dividend (in dollars per share)	$ 0.25
Payment of aggregate amount of dividend		$ 2,969,677	$ 0

XML

Revenue Recognition - Summary of revenue (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Revenue recognition
Total operating revenue	$ 19,903,004	$ 7,089,849	$ 33,503,102	$ 15,531,161
Natural gas
Revenue recognition
Total operating revenue	15,984,348	5,106,922	26,687,432	11,439,021
Natural gas liquids
Revenue recognition
Total operating revenue	688,397	52,529	1,002,825	98,150
Oil and condensate
Revenue recognition
Total operating revenue	1,243,091	79,303	1,704,904	140,738
Gas gathering and compression revenue
Revenue recognition
Total operating revenue	$ 1,987,168	$ 1,851,095	$ 4,107,941	$ 3,853,252

XML

Revenue Recognition - Additional Information (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022
Revenue recognition
Bad debt expense	$ 0	$ 0	$ 0
Gas, oil, NGL and condensate revenue
Revenue recognition
Period settlement statement received			30 days
Gas gathering and compression revenue | Auburn Gas Gathering System
Revenue recognition
Period settlement statement received			2 months

XML

Revenue Recognition - Accounts receivable (Details) - USD ($)	Jun. 30, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 9,930,891	$ 4,596,931
Natural gas and oil sales
Disaggregation of Revenue [Line Items]
Accounts receivable	8,339,473	2,996,344
Joint interest billing
Disaggregation of Revenue [Line Items]
Accounts receivable	21,381	60,134
Gas gathering and compression revenue
Disaggregation of Revenue [Line Items]
Accounts receivable	1,435,391	1,539,976
Other
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 134,646	$ 477

XML

Income Taxes - Current and Deferred Tax Expense (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Current:
Federal	$ 2,530,805	$ 319,557	$ 3,997,702	$ 474,927
State	1,192,131	89,188	1,884,446	273,032
Total current income tax expense	3,722,936	408,745	5,882,148	747,959
Deferred:
Federal	233,599	(451,044)	255,614	212,159
State	63,041	(123,452)	63,712	18,704
Total deferred tax expense	296,640	(574,496)	319,326	230,863
Income tax expense	$ 4,019,576	$ (165,751)	$ 6,201,474	$ 978,822

XML

Commitments and Contingencies (Details)	Jun. 30, 2022 USD ($)
Leases
Lease right-of-use-asset	$ 0
Commitments for capital expenditures	$ 1,500,000

XML

Commitments and Contingencies - Future Minimum Lease Commitments (Details) $ in Thousands	Jun. 30, 2022 USD ($)
Future Minimum Lease Commitments
2022	$ 93,666
2023	62,444
Total	$ 156,110

XML

Net Income Per Share (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Net income available to shareholders	$ 10,582,988	$ (485,025)	$ 16,388,876	$ 2,250,542
Weighted average number of shares - basic and diluted
Basic weighted-average number of shares outstanding	23,576,746	23,779,205	23,627,015	23,862,749
Diluted weighted average shares outstanding	23,822,123	23,779,205	23,796,166	23,941,340
Total Anti-dilutive shares	253,621	113,590	288,316	0
Stock option
Weighted average number of shares - basic and diluted
Incremental common shares	25,405	0	19,630	0
Total Anti-dilutive shares	72,095	0	77,870	0
Time-based restricted shares
Weighted average number of shares - basic and diluted
Incremental common shares	103,258	0	39,340	53,815
Total Anti-dilutive shares	146,740	77,023	169,127	0
Performance stock units
Weighted average number of shares - basic and diluted
Incremental common shares	116,714	0	110,181	24,776
Total Anti-dilutive shares	34,786	36,567	41,319	0

XML

Operating Segments - Segments (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($) segment	Jun. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Segment information
Total operating revenue	$ 19,903,004	$ 7,089,849	$ 33,503,102	$ 15,531,161
Net earnings (loss) for the period	10,582,988	(485,025)	16,388,876	2,250,542
Operating costs	2,793,245	1,957,685	4,723,110	3,742,821
Development geological and geophysical expenses	2,386	11,451	4,772	22,990
Depletion, depreciation, amortization, and accretion	1,803,739	1,646,094	3,192,958	3,328,954
Bad debt expense	0	0	0
Segment assets	110,800,287	90,695,939	110,800,287	90,695,939
Capital expenditures	1,466,924	1,516,895	4,093,211	2,444,619
Proved properties (net)	40,649,783	34,531,736	40,649,783	34,531,736
Unproved properties (net)	18,021,391	21,557,121	18,021,391	21,557,121	$ 21,700,926
Gathering system (net)	8,571,168	9,437,587	8,571,168	9,437,587	$ 9,031,137
Lease right-of-use-asset	0		0
Other property and equipment (net)	930,491	964,435	930,491	964,435
Corporate
Segment information
Total operating revenue	0	0	0	0
Net earnings (loss) for the period	(4,720,646)	(3,959,644)	(9,193,386)	(6,185,854)
Operating costs	0	0	0	0
Development geological and geophysical expenses	0	0	0	0
Depletion, depreciation, amortization, and accretion	0	0	0	0
Bad debt expense	0	0
Segment assets	754,360	133,220	754,360	133,220
Capital expenditures	0	0	0	0
Proved properties (net)	0	0	0	0
Unproved properties (net)	0	0	0	0
Gathering system (net)	0	0	0	0
Lease right-of-use-asset	0		0
Other property and equipment (net)	0	0	0	0
Elimination
Segment information
Total operating revenue	(369,733)	(385,865)	(734,897)	(770,296)
Net earnings (loss) for the period	0	0	0	0
Operating costs	(369,733)	(385,865)	(734,897)	(770,296)
Development geological and geophysical expenses	0	0	0	0
Depletion, depreciation, amortization, and accretion	0	0	0	0
Bad debt expense	0	0
Segment assets	0	0	0	0
Capital expenditures	0	0	0	0
Proved properties (net)	0	0	0	0
Unproved properties (net)	0	0	0	0
Gathering system (net)	0	0	0	0
Lease right-of-use-asset	0		0
Other property and equipment (net)	0	0	0	0
Natural gas
Segment information
Total operating revenue	15,984,348	5,106,922	26,687,432	11,439,021
Natural gas | Corporate
Segment information
Total operating revenue	0	0	0	0
Natural gas | Elimination
Segment information
Total operating revenue	0	0	0	0
Natural gas liquids
Segment information
Total operating revenue	688,397	52,529	1,002,825	98,150
Natural gas liquids | Corporate
Segment information
Total operating revenue	0	0	0	0
Natural gas liquids | Elimination
Segment information
Total operating revenue	0	0	0	0
Oil and condensate
Segment information
Total operating revenue	1,243,091	79,303	1,704,904	140,738
Oil and condensate | Corporate
Segment information
Total operating revenue	0	0	0	0
Oil and condensate | Elimination
Segment information
Total operating revenue	0	0	0	0
Gas gathering and compression revenue
Segment information
Total operating revenue	1,987,168	1,851,095	4,107,941	3,853,252
Gas gathering and compression revenue | Corporate
Segment information
Total operating revenue	0	0	0	0
Gas gathering and compression revenue | Elimination
Segment information
Total operating revenue	(369,733)	(385,865)	(734,897)	(770,296)
Upstream | Operating Segments
Segment information
Total operating revenue	17,915,836	5,238,754	29,395,161	11,677,909
Net earnings (loss) for the period	13,757,784	2,153,394	22,359,572	5,684,536
Operating costs	2,621,750	1,784,138	4,392,404	3,378,327
Development geological and geophysical expenses	2,386	11,451	4,772	22,990
Depletion, depreciation, amortization, and accretion	1,533,916	1,289,771	2,638,413	2,592,056
Bad debt expense	0	0
Segment assets	99,313,811	78,621,390	99,313,811	78,621,390
Capital expenditures	1,390,908	1,459,675	4,001,802	2,374,115
Proved properties (net)	40,649,783	34,531,736	40,649,783	34,531,736
Unproved properties (net)	18,021,391	21,557,121	18,021,391	21,557,121
Gathering system (net)	0	0	0	0
Lease right-of-use-asset	0		0
Other property and equipment (net)	930,491	964,435	930,491	964,435
Upstream | Natural gas | Operating Segments
Segment information
Total operating revenue	15,984,348	5,106,922	26,687,432	11,439,021
Upstream | Natural gas liquids | Operating Segments
Segment information
Total operating revenue	688,397	52,529	1,002,825	98,150
Upstream | Oil and condensate | Operating Segments
Segment information
Total operating revenue	1,243,091	79,303	1,704,904	140,738
Upstream | Gas gathering and compression revenue | Operating Segments
Segment information
Total operating revenue	0	0	$ 0	0
Gas Gathering | Operating Segments
Operating Segments
Number of companies partnered to operate natural gas gathering system | segment			2
Segment information
Total operating revenue	2,356,901	2,236,960	$ 4,842,838	4,623,548
Net earnings (loss) for the period	1,545,850	1,321,225	3,222,690	2,751,860
Operating costs	541,228	559,412	1,065,603	1,134,790
Development geological and geophysical expenses	0	0	0	0
Depletion, depreciation, amortization, and accretion	269,823	356,323	554,545	736,898
Bad debt expense	0	0
Segment assets	10,732,117	11,941,329	10,732,117	11,941,329
Capital expenditures	76,016	57,220	91,409	70,504
Proved properties (net)	0	0	0	0
Unproved properties (net)	0	0	0	0
Gathering system (net)	8,571,168	9,437,587	8,571,168	9,437,587
Lease right-of-use-asset	0		0
Other property and equipment (net)	0	0	0	0
Gas Gathering | Natural gas | Operating Segments
Segment information
Total operating revenue	0	0	0	0
Gas Gathering | Natural gas liquids | Operating Segments
Segment information
Total operating revenue	0	0	0	0
Gas Gathering | Oil and condensate | Operating Segments
Segment information
Total operating revenue	0	0	0	0
Gas Gathering | Gas gathering and compression revenue | Operating Segments
Segment information
Total operating revenue	$ 2,356,901	$ 2,236,960	$ 4,842,838	$ 4,623,548

XML

Operating Segments - Customers (Details) - customer	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Concentration risk
Number of customers	19	21	21	25
Customer Concentration risk
Concentration risk
Number of customers	4	2	2	2
Threshold concentration risk for reporting (as a percent)	10.00%	10.00%	10.00%	10.00%
Total Revenue | Customer Concentration risk | Customer One
Concentration risk
Concentration risk (as a percent)	33.00%	23.00%	23.00%	35.00%
Total Revenue | Customer Concentration risk | Customer Two
Concentration risk
Concentration risk (as a percent)	17.00%	19.00%	19.00%	10.00%
Total Revenue | Customer Concentration risk | Customer Three
Concentration risk
Concentration risk (as a percent)	12.00%
Total Revenue | Customer Concentration risk | Customer Four
Concentration risk
Concentration risk (as a percent)	10.00%

XML

Commodity Risk Management Activities - Commodity Price Risks (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Commodity Risk Management Activities
Recognized gains (losses) on financial commodity derivative contracts	$ 776,994	$ (1,827,334)	$ (194,910)	$ (1,361,993)
Cash (paid) received from settlements of derivative contracts	$ (163,559)	$ (91,660)	$ (1,375,287)	$ (27,460)

XML

Commodity Risk Management Activities - Commodity Derivative Contracts (Details)	6 Months Ended
	Jun. 30, 2022 USD ($) MMBTU $ / MMBTU	Dec. 31, 2021 USD ($)
Risk Management Activities
Fair Value | $	$ 940,553	$ (239,824)
2022 Contracts
Risk Management Activities
Basis Differential | $ / MMBTU	(1.15)
2022 Contracts | Basis swap
Risk Management Activities
Volume (Mmbtu) | MMBTU	765,000
Fair Value | $	$ 7,788
2022 Contracts | Two-way costless collar
Risk Management Activities
Volume (Mmbtu) | MMBTU	765,000
Ceiling Price | $ / MMBTU	8.20
Floor Price | $ / MMBTU	6.50
Fair Value | $	$ 932,765

XML

Commodity Risk Management Activities - Fair Value of Derivative Instruments (Details) - USD ($)	Jun. 30, 2022	Dec. 31, 2021
Risk Management Activities
Fair Value of Derivative Assets	$ 1,154,537	$ 13,312
Fair Value of Derivative Liabilities	(213,984)	(253,136)
Net Fair Value of Derivatives	940,553	(239,824)
Basis swap
Risk Management Activities
Fair Value of Derivative Assets	90,782	0
Fair Value of Derivative Liabilities	(82,994)	0
Two-way costless collar
Risk Management Activities
Fair Value of Derivative Assets	1,063,754	13,312
Fair Value of Derivative Liabilities	$ (130,989)	$ (253,136)

XML

Commodity Risk Management Activities - Fair value of asset (liability) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Commodity Risk Management Activities
Fair value of asset (liability), beginning of the period	$ 0	$ 401,141	$ (239,824)	$ 0
Gains (losses) on derivative contracts included in earnings	776,994	(1,827,334)	(194,910)	(1,361,992)
Settlement of commodity derivative contracts	163,559	91,660	1,375,287	27,459
Fair value of asset, end of the period	$ 940,553	$ (1,334,533)	$ 940,553	$ (1,334,533)

XML

Asset Retirement Obligations (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Reconciliation of provision for asset retirement obligations
Balance beginning of period	$ 2,833,656	$ 3,150,243
Liabilities acquired (disposed of)	6,684	7,009
Liabilities acquired (disposed of)	(24,854)	(381,346)
Wells plugged and abandoned	(118,259)	(31,945)
Change in estimates	0	(8,299)
Accretion	38,738	97,994
Balance end of period	$ 2,735,965	$ 2,833,656