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, 2025

☐   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.)

500 Dallas Street, Suite 1250

Houston, Texas 77002

(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 12, 2025, there were 22,058,574 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		6
Unaudited Condensed Consolidated Statements of Changes in Shareholders’ Equity		7
Unaudited Condensed Consolidated Statements of Cash Flows		8
Notes to the Unaudited Condensed Consolidated Financial Statements
1.	Description of Business	9
2.	Basis of Preparation	9
	Interim Financial Statements	9
	Principles of Consolidation	9
	Use of Estimates	9
	Recently Issued Accounting Standards	9
3.	Cash, Cash Equivalents, and Restricted Cash	10
4.	Short Term Investments	10
5.	Property and Equipment	11
	Property Impairment	11
6.	Revolving Line of Credit	12
7.	Shareholders’ Equity	12
8.	Revenue Recognition	13
9.	Accumulated Other Comprehensive Income	15
10.	Income Taxes	15
11.	Commitments and Contingencies	16
12.	Leases	16
13.	Net Income Per Share	17
14.	Operating Segments	17
15.	Commodity Risk Management Activities	21
	Commodity Price Risks	21
	Commodity Derivative Contracts	22
16.	Asset Retirement Obligations	23
17.	Fair Value Measurements	23
18.	Subsequent Events	24
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		25
	Overview	25
	Business Strategy	25
	Operational Highlights	26
	Non-GAAP Financial Measures-Adjusted EBITDA	27
	Net Operating Revenues	28
	Operating Costs	29
	Depletion, Depreciation, Amortization and Accretion	30
	General and Administrative	30

	Interest Income	31
	Interest Expense	31
	Gain (Loss) on Derivative Contracts	31
	Capital Resources and Liquidity	31
	Cash Flow	31
	Credit Agreement	32
	Repurchase Transactions	32
	Derivative Transactions	33
	Contractual Obligations	33
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		33
	Gathering System Revenue Risk	34
	Interest Rate Risk	34
	Derivative Contracts	34
ITEM 4. CONTROLS AND PROCEDURES		34
	Disclosure Controls and Procedures	34
	Changes in Internal Control Over Financial Reporting	34
	Inherent Limitations on Effectiveness of Controls	34
PART II OTHER INFORMATION		35
ITEM 1. LEGAL PROCEEDINGS		35
ITEM 1A. RISK FACTORS		35
ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS		35
ITEM 3. DEFAULTS UPON SENIOR SECURITIES		35
ITEM 4. MINE SAFETY DISCLOSURES		35
ITEM 5. OTHER INFORMATION		35
ITEM 6. EXHIBITS		36
SIGNATURES		37

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, 2024, 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, 2024. Our Annual Report on Form 10-K for the year ended December 31, 2024 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,
	2025		2024
ASSETS
Current assets
Cash and cash equivalents	$	9,907,653	$	6,519,793
Accounts receivable		5,496,883		5,843,722
Fair value of derivatives		732,528		—
Prepaid income taxes		—		975,963
Other current assets		396,264		792,041
Total current assets		16,533,328		14,131,519
Non-current assets
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties		197,197,902		191,879,210
Unproved properties		33,496,835		28,364,186
Accumulated depletion, depreciation, amortization and impairment		(131,899,045)		(123,281,395)
Total oil and gas properties, net		98,795,692		96,962,001
Gathering system		43,416,065		43,116,371
Accumulated depletion, depreciation, amortization and impairment		(37,057,605)		(36,449,511)
Total gathering system, net		6,358,460		6,666,860
Land		637,764		637,764
Buildings and other property and equipment, net		245,555		259,335
Total property and equipment, net		106,037,471		104,525,960
Other assets:
Operating lease right-of-use assets, long term		295,317		344,589
Restricted cash		470,000		470,000
Prepaid drilling costs		277,552		982,717
Total non-current assets		107,080,340		106,323,266
Total assets	$	123,613,668	$	120,454,785
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Accounts payable trade	$	2,018,533	$	2,334,732
Gathering fees payable		1,139,057		997,016
Royalties payable		1,553,262		1,400,976
Income taxes payable		1,596,958		—
Accrued capital expenditures		225,923		572,079
Accrued compensation		465,055		695,018
Other accrued liabilities		283,540		371,503
Fair value of derivatives		—		487,548
Operating lease liabilities		121,057		121,135
Total current liabilities		7,403,385		6,980,007
Non-current liabilities
Asset retirement obligations		3,764,816		3,652,296
Deferred income taxes		11,958,901		12,738,577
Operating lease liabilities, long term		296,250		355,776
Total non-current liabilities		16,019,967		16,746,649
Total liabilities		23,423,352		23,726,656
Commitments and contingencies (Note 11)
Shareholders' equity
Preferred shares, no par value, unlimited shares authorized, none issued or outstanding		—		—
Common shares, no par value, unlimited shares authorized and 22,017,405 shares issued and outstanding at June 30, 2025 and 22,008,766 issued and outstanding at December 31, 2024		116,081,031		116,081,031
Additional paid-in capital		12,890,583		12,118,907
Accumulated deficit		(38,688,953)		(41,505,076)
Accumulated other comprehensive income		9,907,655		10,033,267
Total shareholders' equity		100,190,316		96,728,129
Total liabilities and shareholders' equity	$	123,613,668	$	120,454,785

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

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Revenues from contracts with customers:
Gas, oil, NGL, and condensate revenue	$	9,779,728	$	5,863,370	$	24,050,518	$	11,914,415
Gas gathering and compression revenue		1,845,005		1,444,448		3,737,355		3,380,146
Total revenue		11,624,733		7,307,818		27,787,873		15,294,561
Operating costs and expenses:
Lease operating expenses		2,462,785		1,649,867		5,218,683		3,418,329
Gathering system operating expenses		613,795		649,967		1,166,446		1,202,537
Depletion, depreciation, amortization, and accretion		3,201,654		2,048,403		6,677,511		4,428,829
Impairment expense		2,670,000		—		2,676,669		—
General and administrative expenses:
Stock based compensation expense		385,838		313,589		771,676		635,158
Other general and administrative expenses		1,461,878		1,478,215		3,280,296		3,037,238
Total operating costs and expenses		10,795,950		6,140,041		19,791,281		12,722,091
Operating income		828,783		1,167,777		7,996,592		2,572,470
Other income (expense):
Interest income		17,247		108,943		32,546		375,215
Interest expense		(19,906)		(8,759)		(32,117)		(17,519)
Gain (loss) on derivative contracts		2,573,863		(94,891)		1,111,693		(195,617)
Other (expense) income		(10,839)		101,606		(33,338)		101,073
Other income, net		2,560,365		106,899		1,078,784		263,152
Net income before income tax expense		3,389,148		1,274,676		9,075,376		2,835,622
Income tax expense		1,837,687		459,016		3,507,881		513,066
NET INCOME	$	1,551,461	$	815,660	$	5,567,495	$	2,322,556
Currency translation adjustments		(75,496)		22,229		(125,612)		22,593
Unrealized gain (loss) on securities		—		3,011		—		(1,598)
NET COMPREHENSIVE INCOME	$	1,475,965	$	840,900	$	5,441,883	$	2,343,551
Net income per share, basic	$	0.07	$	0.04	$	0.25	$	0.11
Net income per share, diluted	$	0.07	$	0.04	$	0.25	$	0.11
Weighted average number of shares outstanding, basic		22,017,310		21,921,752		22,013,062		21,957,980
Weighted average number of shares outstanding, diluted		22,202,315		22,029,475		22,155,629		21,987,142

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, 2025	22,008,766	$	116,081,031	—	$	—	$	12,118,907	$	10,033,267	$	(41,505,076)	$	96,728,129
Net income	—		—	—		—		—		—		4,016,034		4,016,034
Dividends paid	—		—	—		—		—		—		(1,375,612)		(1,375,612)
Stock-based compensation expense	—		—	—		—		385,838		—		—		385,838
Other comprehensive loss	—		—	—		—		—		(50,116)		—		(50,116)
Balance at March 31, 2025	22,008,766	$	116,081,031	—	$	—	$	12,504,745	$	9,983,151	$	(38,864,654)	$	99,704,273
Net income	—		—	—		—		—		—		1,551,461		1,551,461
Dividends paid	—		—	—		—		—		—		(1,375,760)		(1,375,760)
Stock-based compensation expense	—		—	—		—		385,838		—		—		385,838
Vesting of shares of restricted stock	8,639		—	—		—		—		—		—		—
Other comprehensive loss	—		—	—		—		—		(75,496)		—		(75,496)
Balance at June 30, 2025	22,017,405	$	116,081,031	—	$	—		12,890,583	$	9,907,655	$	(38,688,953)	$	100,190,316

									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, 2024	22,222,722	$	118,272,565	(70,874)	$	(360,326)	$	10,874,491	$	9,772,277	$	(37,946,042)	$	100,612,965
Net income	—		—	—		—		—		—		1,506,896		1,506,896
Dividends paid	—		—	—		—		—		—		(1,370,409)		(1,370,409)
Stock-based compensation expense	—		—	—		—		321,569		—		—		321,569
Buyback of common shares	—		—	(248,700)		(1,203,708)		—		—		—		(1,203,708)
Retirement of treasury shares	(319,574)		(1,564,034)	319,574		1,564,034		—		—		—		—
Vesting of shares of restricted stock	10,054		—	—		—		—		—		—		—
Other comprehensive income	—		—	—		—		—		(4,245)		—		(4,245)
Balance at March 31, 2024	21,913,202	$	116,708,531	—	$	—	$	11,196,060	$	9,768,032	$	(37,809,555)	$	99,863,068
Net income	—		—	—		—		—		—		815,660		815,660
Dividends paid	—		—	—		—		—		—		(1,371,940)		(1,371,940)
Stock-based compensation expense	—		—	—		—		313,589		—		—		313,589
Vesting of shares of restricted stock	8,648		—	—		—		—		—		—		—
Other comprehensive income	—		—	—		—		—		25,240		—		25,240
Balance at June 30, 2024	21,921,850	$	116,708,531	—	$	—	$	11,509,649	$	9,793,272	$	(38,365,835)	$	99,645,617

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

7

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Cash Flows

	Six months ended June 30,
	2025		2024
Cash flows from operating activities:
Net income	$	5,567,495	$	2,322,556
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion		6,677,511		4,428,829
Impairment expense		2,676,669		—
Accretion of discount on available for sale securities		—		(297,637)
(Gain) loss on derivative contracts		(1,111,693)		195,617
Settlement (paid) received on derivative contracts		(108,383)		760,542
Settlement of asset retirement obligation		(1,600)		(87,284)
Stock-based compensation expense		771,676		635,158
Deferred income tax benefit		(779,676)		(54,736)
Changes in assets and liabilities:
Accounts receivable		346,839		1,070,784
Prepaid income taxes		—		319,770
Other assets and liabilities		385,445		354,014
Accounts payable, royalties payable, gathering fees payable, and other accrued liabilities		(66,454)		(572,099)
Income taxes payable		2,572,921		—
Net cash provided by operating activities		16,930,750		9,075,514
Cash flows from investing activities:
Additions to unproved oil and gas properties		(5,132,649)		(2,993,155)
Additions to proved oil and gas properties		(5,997,993)		(26,425,017)
Additions to gathering system properties		(228,327)		(70,236)
Additions to land, buildings and property and equipment		(12,102)		(13,912)
Purchases of short term investments - available for sale		—		(4,045,785)
Proceeds from short term investments - held to maturity		—		23,116,930
Prepaid drilling costs		705,165		886,981
Net cash used in investing activities		(10,665,906)		(9,544,194)
Cash flows from financing activities:
Buyback of common shares		—		(1,203,708)
Dividends paid		(2,751,372)		(2,742,349)
Net cash used in financing activities		(2,751,372)		(3,946,057)
Effect of currency rates on cash, cash equivalents, and restricted cash		(125,612)		22,593
Decrease in cash, cash equivalents, and restricted cash		3,387,860		(4,392,144)
Cash, cash equivalents, and restricted cash, beginning of period		6,989,793		13,873,628
Cash, cash equivalents, and restricted cash, end of period	$	10,377,653	$	9,481,484
Supplemental cash flow disclosures:
Income tax paid - federal	$	1,325,000	$	140,000
Income tax paid - state (PA)	$	355,138	$	—
Income tax paid (refund) - state (other)	$	1,710	$	(8,608)
Interest paid	$	9,552	$	—
Non-cash investing activities:
Change in proved properties accrued in accounts payable	$	(690,866)	$	(1,471,985)
Change in gathering system accrued in accounts payable	$	71,366	$	45,862
Asset retirement obligation asset additions and adjustments	$	18,235	$	21,831

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

8

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, pursuant to the Alberta Business Corporations Act. 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, we began trading in the United States on the NASDAQ Global Market under the trading symbol “EPSN.” Epsilon is a North American on-shore focused independent natural gas and oil company engaged in the acquisition, development, gathering and production of natural gas and oil reserves.

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 statement 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, 2024. 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.

Reclassification

The consolidated financial statements for the prior periods include certain reclassifications that were made to conform to the current period presentation. Such reclassifications have no impact on previously reported consolidated financial position, results of operations or cash flows.

Recently Issued Accounting Standards

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures, which requires public entities, on an annual basis, to disclose disaggregated information about a reporting entity’s effective tax rate reconciliation, using both percentages and reporting currency amounts for specific standardized categories, as well as disclosure of income taxes paid disaggregated by jurisdiction. The amendments will be effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The Company is evaluating the impact of

9

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

this new standard and believes that the adoption will result in additional disclosures, but will not have any other impact on its consolidated financial statements.

In March 2024, the FASB issued ASU No. 2024-01, Compensation – Stock Compensation (Topic 718): Scope Applications of Profits Interest and Similar Awards (“ASU 2024-01”). The amendments in ASU 2024-01 improve its overall clarity and operability without changing the guidance and adding illustrative examples to determine whether profits interest award should be accounted for in accordance with Topic 718. The Company has adopted ASU No. 2024-01 as of January 1, 2025. There was no impact as a result of the adoption of this ASU.

In November 2024, the FASB issued ASU 2024-3 "Income Statement – Reporting Comprehensive Income – Expense Disaggregation Disclosures." The ASU will improve the decision usefulness for investors by requiring public business entities to disclose more detailed information about their expenses such as (a) inventory and manufacturing expense, (b) employee compensation, (c) depreciation, (d) intangible asset amortization, etc. The amendments will be effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027, with early adoption permitted. The amendments will be applied prospectively with an option for a retrospective application. The Company is evaluating the impact of this new standard and believes that the adoption will result in additional disclosures, but will not have any other impact on its consolidated financial statements.

In July 2025, the FASB issued ASU 2025-05, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit losses for Accounts Receivable and Contract Assets. The amendments in this update provide (1) all entities with a practical expedient to assume that current conditions as of the balance sheet date do not change for the remaining life of the assets and (2) entities other than public business entities with an accounting policy election to consider collection activity after the balance sheet date when estimating expected credit losses for current accounts receivable and current contract assets arising from transactions accounted for under Topic 606. The amendments will be effective for fiscal years beginning after December 15, 2025, with early adoption permitted. The Company is evaluating the impact of this new standard and believes that the adoption may result in additional disclosures, but will not have any other impact on its consolidated financial statements.

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, 2025 and December 31, 2024:

	June 30,		December 31,
	2025		2024
Cash and cash equivalents	$	9,907,653	$	6,519,793
Restricted cash included in other assets		470,000		470,000
Cash, cash equivalents, and restricted cash in the statement of cash flows	$	10,377,653	$	6,989,793

4. Short Term Investments

Short term investments are highly liquid investments with original maturities between three and twelve months. The Company’s short term investments consist of US Treasury Bills. These investments are classified as available-for-sale. Available-for-sale short term investments are reported at fair value in the Consolidated Balance Sheets. Unrealized gains and losses are excluded from earnings and are reported in Accumulated other comprehensive income in the Consolidated Statements of Operations and Comprehensive Income.

10

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

As of June 30, 2025 and December 31, 2024, the Company had no short term investments.

During the six months ended June 30, 2024, the Company sold securities with a carrying amount of $14,989,595

for total proceeds of $15,336,930. The realized gains on these sales were $347,335. An additional $7,780,000 of securities reached maturity with total realized gains of $234,248. During the three months ended June 30, 2024, the Company sold securities with a carrying amount of $7,986,472 for total proceeds of $8,177,645. The realized gains on these sales were $191,173. An additional $4,145,000 of securities reached maturity with total realized gains of $99,215. The realized gains are included in other income in the consolidated Statements of Operations and Comprehensive Income.

5.  Property and Equipment

The following table summarizes the Company’s property and equipment as of June 30, 2025 and December 31, 2024:

	June 30,		December 31,
	2025		2024
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	197,197,902	$	191,879,210
Unproved properties		33,496,835		28,364,186
Accumulated depletion, depreciation, amortization and impairment		(131,899,045)		(123,281,395)
Total oil and gas properties, net		98,795,692		96,962,001
Gathering system		43,416,065		43,116,371
Accumulated depletion, depreciation, amortization and impairment		(37,057,605)		(36,449,511)
Total gathering system, net		6,358,460		6,666,860
Land		637,764		637,764
Buildings and other property and equipment, net		245,555		259,335
Total property and equipment, net	$	106,037,471	$	104,525,960

Asset Acquisitions

During the six months ended June 30, 2025, Epsilon had no asset acquisitions.

During the six months ended June 30, 2024, Epsilon acquired assets that included the following:

● a 25% working interest in three producing wells located in Ector County, Texas.

● a 25% working interest in an additional 3,620 gross undeveloped acres in Ector County, Texas.

● a 50% working interest in 14,243 gross undeveloped acres in Alberta, Canada.

Management determined that substantially all the fair value of the assets acquired was concentrated in a group of similar identifiable assets. Based on this determination, the acquisition was accounted for as an asset acquisition.

Property Impairment

We perform a quantitative impairment test 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, basis differentials, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, GAAP requires that the Company first compare 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 properties to their estimated fair value is required. Additionally, if an exploratory well is determined not to have found proved reserves, the costs incurred, net of any salvage value, should be charged to expense.

11

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

During the three and six months ended June 30, 2025, Epsilon recorded an impairment of $2.7 million for two wells drilled in Alberta, Canada.  The impairment was a result of a decrease in estimated reserves due to early production coming in below expectations, cost overruns and lower forward commodity prices.

During the three and six months ended June 30, 2024, no impairment was recorded. For the year ended December 31, 2024, the Company had $0.53 million of impairment reflected in proved properties on the Consolidated Balance Sheets. To be consistent with the current presentation, the prior year impairment has been reclassed to accumulated depletion, depreciation, amortization and impairment on the Consolidated Balance Sheets.

6. Revolving Line of Credit

The Company closed a senior secured reserve based revolving credit facility on June 28, 2023, with Frost Bank as issuing bank and sole lender. The current borrowing base is $45 million (redetermined as of February 10, 2025), supported by the Company’s upstream assets in Pennsylvania and subject to semi-annual redeterminations with a maturity date of June 28, 2027. Interest will be charged at the Daily Simple SOFR rate plus a margin of 3.25%. The facility is secured by the assets of the Company’s Epsilon Energy USA subsidiary (Borrower). There are currently no borrowings under the facility.

Under the terms of the facility, the Company must adhere to the following financial covenants:

● Current ratio of 1.0 to 1.0 (current assets / current liabilities)

● Leverage ratio of less than 2.5 to 1.0 (total debt / income adjusted for interest, taxes and non-cash amounts)

Additionally, if the Leverage ratio is greater than 1.0 to 1.0, or the borrowing base utilization is greater than 50%, the Company is required to hedge 50% of the anticipated production from PDP reserves for a rolling 24-month period.

We were in compliance with the financial covenants of the agreement as of June 30, 2025.

	Balance at		Balance at
	June 30,		December 31,		Current
	2025		2024		Borrowing Base		Interest Rate
Revolving line of credit	$	—	$	—	$	45,000,000		SOFR + 3.25%

7. 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

On February 12, 2025, Epsilon’s board of directors (the “Board”) authorized a new share repurchase program of up to 2,200,876 common shares, representing 10% of the current outstanding common shares of Epsilon, for an aggregate purchase price of not more than US $13.0 million. The program commenced on February 12, 2025 and ends on February 11, 2026, unless the maximum amount of common shares is purchased before then or the Board approves earlier termination.

The previous share repurchase program commenced on March 19, 2024.  During the year ended December 31, 2024, we repurchased 125,000 common shares and spent $627,500 at an average price of $5.00 per share (excluding commissions) under the plan. On February 12, 2025, the Board terminated and revoked authority under the program.

12

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

During the six months ended June 30, 2025, no shares were repurchased under the new or previous program.  

(c)Equity Incentive Plan

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.

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 is authorized to issue up to 2,000,000 Common Shares.

Restricted Stock

For the six months ended June 30, 2025, no restricted common shares were awarded to the Company’s board of directors and employees. For the year ended December 31, 2024, 300,052 restricted common shares with a weighted average grant date fair value of $5.97 were awarded to the Company’s management, employees, and board of directors. These shares vest over a three-year period, with an equal number of 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, 2025, and the year ended December 31, 2024:

	Six months ended				Year ended
	June 30, 2025				December 31, 2024
	Number of	Weighted	Weighted		Number of	Weighted	Weighted
	Restricted	Average	Average		Restricted	Average	Average
	Shares	Remaining Life	Grant Date		Shares	Remaining Life	Grant Date
	Outstanding	(years)	Fair Value		Outstanding	(years)	Fair Value
Balance non-vested Restricted Stock at beginning of period	560,970	1.61	$	5.77	491,536	1.74	$	5.59
Granted	—	—		-	300,052	1.92		5.97
Vested	(8,639)	—		6.15	(230,618)	—		5.65
Balance non-vested Restricted Stock at end of period	552,331	1.11	$	5.77	560,970	1.61	$	5.77

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, 2025 was $385,838 and $771,676, respectively (for the three and six months ended June 30, 2024 was $313,589 and $ 635,158, respectively).

As of June 30, 2025, the Company had unrecognized stock-based compensation related to these shares of $2,426,793 to be recognized over a weighted average period of 1.14 years (at December 31, 2024: $3,198,469 over 1.30 years).

(d)Dividends

On February 26, 2025 and June 3, 2025, the Board declared quarterly a dividend of $0.0625 per common share (annualized $0.25 per common share) totaling in aggregate an amount of approximately $2.8 million that has been paid during the six months ended June 30, 2025.

8. Revenue Recognition

Revenues are comprised of sales of natural gas, oil and natural gas liquids (“NGLs”), along with the revenue generated from the Company’s ownership interest in the gas gathering system in the Auburn field in Northeastern Pennsylvania.

13

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

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 points 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. Gathering System revenues derived from Epsilon’s production, which have been eliminated from total gathering system revenues (“elimination entry”), amounted to $0.5 million and $1.1 million, respectively, for the three and six months ended June 30, 2025 ($0.3 million and $0.6 million, respectively, for the three and six months ended June 30, 2024).

The following table details revenue for the three and six months ended June 30, 2025 and 2024.

	Three months ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Operating revenue
Natural gas	$	6,910,344	$	1,961,230	$	17,523,917	$	4,924,209
Natural gas liquids		145,020		388,423		532,270		761,407
Oil and condensate		2,724,364		3,513,717		5,994,331		6,228,799
Gathering and compression fees (1)		1,845,005		1,444,448		3,737,355		3,380,146
Total operating revenue	$	11,624,733	$	7,307,818	$	27,787,873	$	15,294,561

(1) Net of the elimination entry

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 and Comprehensive Income.

Settlement statements for product sales, and the related cash consideration, are generally 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 in Pennsylvania. 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 GGS 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.

Current Expected Credit Losses

Under ASU 326, Financial Instruments – Credit Losses, estimated losses on financial assets are provided through an allowance for credit losses. The majority of our financial assets are held in cash and cash equivalents and accounts receivable. The accounts receivable are primarily from purchasers of oil and natural gas, counterparties to our financial instruments, and revenues earned for compression and gathering services. Our oil, gas, and natural gas liquids accounts receivable are generally collected within 30 days after the end of the month. Compression and gathering receivables are generally collected within 60 days after the end of the month. We assess collectability through various procedures,

14

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

including review of our trade receivable balances by counterparty, assessing economic events and conditions, our historical experience with counterparties, the counterparty’s financial condition and the amount and age of past due accounts. As of June 30, 2025 and December 31, 2024, we determined that our allowance for credit loss was nil.

	June 30,		December 31,		December 31,
	2025		2024		2023
Accounts receivable
Natural gas and oil sales	$	3,946,643	$	4,888,294	$	4,327,886
Joint interest billing		—		—		17,476
Gathering and compression fees		1,434,591		918,471		1,543,239
Commodity contract		115,649		36,957		72,075
Interest		—		—		54,772
Total accounts receivable	$	5,496,883	$	5,843,722	$	6,015,448

9. Accumulated Other Comprehensive Income

Accumulated other comprehensive income includes certain transactions that have generally been reported in the Consolidated Statements of Changes in Shareholders’ Equity. The activity in accumulated other comprehensive income during the three and six months ended June 30, 2025 and 2024 consisted of the following:

	Three months ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Balance at beginning of period	$	9,983,151	$	9,768,032	$	10,033,267	$	9,772,277
Translation (loss)/gain		(75,496)		22,229		(125,612)		22,593
Unrealized gain/(loss) on securities		—		3,011		—		(1,598)
Balance at end of period	$	9,907,655	$	9,793,272	$	9,907,655	$	9,793,272

10. Income Taxes

Income tax provisions for the three and six months ended June 30, 2025 and 2024 are as follows:

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Current:
Federal	$	1,794,581	$	401,042	$	3,358,642	$	467,310
State		501,330		89,717		928,915		100,492
Total current income tax expense		2,295,911		490,759		4,287,557		567,802
Deferred:
Federal		(413,762)		(23,214)		(704,026)		354,385
State		(44,462)		(8,529)		(75,650)		(409,121)
Total deferred tax expense		(458,224)		(31,743)		(779,676)		(54,736)
Income tax expense	$	1,837,687	$	459,016	$	3,507,881	$	513,066

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

15

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

open to audit under the statute of limitations for the years ending December 31, 2021 through December 31, 2024. To the extent we utilize net operating losses generated in earlier years, such earlier years may also be subject to audit.

Starting in 2023, distributions of Epsilon Energy USA Inc. earnings to Epsilon Energy Ltd. incur a 5% U.S. dividend withholding tax, provided the Company is eligible for benefits under the U.S. / Canada income treaty.

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, 2025 was higher than the statutory federal rate as a result of state income taxes partially offset by the valuation allowance against the Canadian net operating loss.

On July 4, 2025, Public Law No. 119-21, commonly referred to as the One Big Beautiful Bill Act (the “Act”), was enacted by the U.S. government. While the enactment of the Act does not have an impact on the historical financial data, the Company’s future tax liabilities may be impacted. Among other changes, the Act: (i) allows for 100% expensing of the costs of certain qualified property acquired after January 19, 2025; (ii) allows election to immediately deduct R&D costs incurred; and (iii) modifies the provision related to the limitations on deduction of interest expense.

The Company expects to realize net benefits from U.S. tax reform, primarily driven by the accelerated depreciation of qualified assets for tax purposes. However, the Company continues to evaluate the impacts of the Act and further understand its implications, as well as the related, and yet to be issued, regulations and interpretations which could impact this outlook.

11. Commitments and Contingencies

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of June 30, 2025, the Company had commitments of $1.9 million for capital expenditures.

12. Leases

Under ASC 842, Leases, the Company recognized an operating lease related to its corporate office as of June 30, 2025 and December 31, 2024 as summarized in the following table:

	June 30,		December 31,
	2025		2024
Asset
Operating lease right-of-use assets, long term	$	295,317	$	344,589
Total operating lease right-of-use assets	$	295,317	$	344,589
Liabilities
Operating lease liabilities	$	121,057	$	121,135
Operating lease liabilities, long term		296,250		355,776
Total operating lease liabilities	$	417,307	$	476,911
Operating lease costs	$	120,926	$	236,044
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	152,709	$	214,230
Weighted average remaining lease term (years) - operating lease		2.29		2.50
Weighted average discount rate (annualized) - operating lease		8.25%		8.25%

On March 1, 2023, the Company commenced a new office lease with a 70 month lease term and future lease payments estimated to be approximately $0.85 million. There are no other pending leases, and no lease arrangements in which the Company is the lessor.

Lease expense for operating leases was $0.12 million and $0.24 million for the six months ended June 30, 2025 and

16

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

the year ended December 31, 2024, respectively. This lease expense is presented in other general and administrative expenses in the Consolidated Statements of Operations and Comprehensive Income.

Future minimum lease payments as of June 30, 2025 are as follows:

	Operating Leases
2025	$	86,775
2026		177,021
2027		180,492
2028		183,963
Total minimum lease payments		628,251
Less: imputed interest		(210,944)
Present value of future minimum lease payments		417,307
Less: current obligations under leases		(121,057)
Long-term lease obligations	$	296,250

13.    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,
	2025		2024		2025		2024
Net income	$	1,551,461	$	815,660	$	5,567,495	$	2,322,556

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,
	2025	2024	2025	2024
Basic weighted-average number of shares outstanding	22,017,310	21,921,752	22,013,062	21,957,980
Unvested time-based restricted shares	185,005	107,723	142,567	29,162
Diluted weighted-average shares outstanding	22,202,315	22,029,475	22,155,629	21,987,142

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,
	2025	2024	2025	2024
Anti-dilutive unvested time-based restricted shares	367,421	492,463	411,203	512,389

14. Operating Segments

Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision-maker (CODM). The CODM, who is responsible for allocating resources and assessing performance of the operating segments, has been identified as executive management consisting of the Chief Executive Officer, Chief Financial Officer, and Chief Operating Officer. The CODM uses the Company’s consolidated financial results, including operating income or loss by segment, to make key operating decisions, assess performance, and to allocate resources.

17

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Segment performance is evaluated based on operating income or loss as shown in the table below. Interest income 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 natural gas and oil reserves on properties within the United States and Canada; and

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

Segment activity for the six months ended June 30, 2025 and 2024 is as follows:

	Upstream		Gas Gathering		Consolidated
As of and for the six months ended June 30, 2025
Operating revenue
Natural gas	$	17,523,917	$	—	$	17,523,917
Natural gas liquids		532,270		—		532,270
Oil and condensate		5,994,331		—		5,994,331
Gathering and compression fees		—		3,737,355		3,737,355
Intersegment gathering and compression fees		—		1,064,223		1,064,223
		24,050,518		4,801,578		28,852,096
Reconciliation of operating revenue
Elimination of intersegment revenues						(1,064,223)
Total consolidated operating revenue(1)						27,787,873
Operating costs
Gathering, transportation, and compression		3,978,175		—		3,978,175
Other lease operating expense		1,240,508		—		1,240,508
Gathering system operating expenses		—		1,166,446		1,166,446
Intersegment other lease operating expense		1,064,223		—		1,064,223
Impairment		2,676,669		—		2,676,669
Depletion, depreciation, amortization and accretion		6,065,544		611,967		6,677,511
Segment operating income	$	9,025,399	$	3,023,165	$	10,984,341
Reconciliation of segment operating income
Salary expense						1,789,792
Stock based compensation						771,676
Other general and administrative						1,490,504
Elimination of intersegment other lease operating expenses						(1,064,223)
Total consolidated operating income						7,996,592
Other income (expense)
Interest income						32,546
Interest expense						(32,117)
Loss on derivative contracts						1,111,693
Other expense						(33,338)
Other expense, net						1,078,784
Net income before income tax expense					$	9,075,376
Capital expenditures (2)	$	11,142,744	$	228,327	$	11,371,071
Segment assets	$	99,073,244	$	6,358,460	$	105,431,704
Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	105,431,704
Current assets, net						16,533,328
Other property and equipment						883,319
Operating lease right-of-use asset						295,317
Restricted cash						470,000
					$	123,613,668

18

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

	Upstream		Gas Gathering		Consolidated
As of and for the six months ended June 30, 2024
Operating revenue
Natural gas	$	4,924,209	$	—	$	4,924,209
Natural gas liquids		761,407		—		761,407
Oil and condensate		6,228,799		—		6,228,799
Gathering and compression fees		—		3,380,146		3,380,146
Intersegment gathering and compression fees		—		591,907		591,907
		11,914,415		3,972,053		15,886,468
Reconciliation of operating revenue
Elimination of intersegment revenues						(591,907)
Total consolidated operating revenue(1)						15,294,561
Operating costs
Gathering, transportation, and compression		2,602,378		—		2,602,378
Other lease operating expense		815,951		—		815,951
Gathering system operating expenses		—		1,202,537		1,202,537
Intersegment other lease operating expense		591,907		—		591,907
Depletion, depreciation, amortization and accretion		4,007,320		421,509		4,428,829
Segment operating income	$	3,896,859	$	2,348,007	$	5,652,959
Reconciliation of segment operating income
Salary expense						1,461,549
Stock based compensation						635,158
Other general and administrative						1,575,689
Elimination of intersegment other lease operating expenses						(591,907)
Total consolidated operating income						2,572,470
Other income (expense)
Interest income						375,215
Interest expense						(17,519)
Gain on derivative contracts						(195,617)
Other expense						101,073
Other income, net						263,152
Net income before income tax expense					$	2,835,622
Capital expenditures (2)	$	29,432,084	$	70,236	$	29,502,320
Segment assets	$	97,059,040	$	6,896,509	$	103,955,549
Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	103,955,549
Current assets, net						14,977,407
Other property and equipment						919,208
Operating lease right-of-use asset						392,792
Restricted cash						900,000
					$	121,144,956

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the six months ended June 30, 2025 and 2024 have been eliminated upon consolidation. For the six months ended June 30, 2025, Epsilon sold natural gas to 34 unique customers. The one customer over 10% comprised 34% of total revenue. For the six months ended June 30, 2024, Epsilon sold natural gas to 29 unique customers. The three customers over 10% comprised 14%, 11%, 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, completion, and maintenance of the gathering and compression facility.

19

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Segment activity for the three months ended June 30, 2025 and 2024 is as follows:

	Upstream		Gas Gathering		Consolidated
As of and for the three months ended June 30, 2025
Operating revenue
Natural gas	$	6,910,344	$	—	$	6,910,344
Natural gas liquids		145,020		—		145,020
Oil and condensate		2,724,364		—		2,724,364
Gathering and compression fees		—		1,845,005		1,845,005
Intersegment gathering and compression fees		—		507,365		507,365
		9,779,728		2,352,370		12,132,098
Reconciliation of operating revenue
Elimination of intersegment revenues						(507,365)
Total consolidated operating revenue(1)						11,624,733
Operating costs
Gathering, transportation, and compression		1,924,460		—		1,924,460
Other lease operating expense		538,325		—		538,325
Gathering system operating expenses		—		613,795		613,795
Intersegment other lease operating expense		507,365		—		507,365
Impairment		2,670,000		—		2,670,000
Depletion, depreciation, amortization and accretion		2,919,238		282,416		3,201,654
Segment operating income	$	1,220,340	$	1,456,159	$	2,169,134
Reconciliation of segment operating income
Salary expense						710,122
Stock based compensation						385,838
Other general and administrative						751,756
Elimination of intersegment other lease operating expenses						(507,365)
Total consolidated operating income						828,783
Other income (expense)
Interest income						17,247
Interest expense						(19,906)
Gain on derivative contracts						2,573,863
Other expense						(10,839)
Other expense, net						2,560,365
Net income before income tax expense					$	3,389,148
Capital expenditures (2)	$	3,502,977	$	124,052	$	3,627,029

20

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

	Upstream		Gas Gathering		Consolidated
As of and for the three months ended June 30, 2024
Operating revenue
Natural gas	$	1,961,230	$	—	$	1,961,230
Natural gas liquids		388,423		—		388,423
Oil and condensate		3,513,717		—		3,513,717
Gathering and compression fees		—		1,444,448		1,444,448
Intersegment gathering and compression fees		—		277,509		277,509
		5,863,370		1,721,957		7,585,327
Reconciliation of operating revenue
Elimination of intersegment revenues						(277,509)
Total consolidated operating revenue(1)						7,307,818
Operating costs
Gathering, transportation, and compression		1,231,981		—		1,231,981
Other lease operating expense		417,886		—		417,886
Gathering system operating expenses		—		649,967		649,967
Intersegment other lease operating expense		277,509		—		277,509
Depletion, depreciation, amortization and accretion		1,877,611		170,792		2,048,403
Segment operating income	$	2,058,383	$	901,198	$	2,682,072
Reconciliation of segment operating income
Salary expense						15,838
Stock based compensation						313,589
Other general and administrative						1,462,377
Elimination of intersegment other lease operating expenses						(277,509)
Total consolidated operating income						1,167,777
Other income (expense)
Interest income						108,943
Interest expense						(8,759)
Gain on derivative contracts						(94,891)
Other expense						101,606
Other income, net						106,899
Net income before income tax expense					$	1,274,676
Capital expenditures (2)	$	9,109,756	$	47,586	$	9,157,342

(3) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended June 30, 2025 and 2024 have been eliminated upon consolidation. For the three months ended June 30, 2025, Epsilon sold natural gas to 31 unique customers. The two customers over 10% comprised 44% and 14% of total revenue. For the three months ended June 30, 2024, Epsilon sold natural gas to 26 unique customers. The three customers over 10% comprised 20%, 15% and 14% of total revenue.

(4) 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, completion, and maintenance of the gathering and compression facility.

15. 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 and oil by securing derivative contracts for a portion of expected sales volumes.

Inherent in the Company’s fixed price contracts, are certain business risks, including market risk and credit risk. Market risk is the risk that the price of oil and natural gas 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. The Company does not currently require collateral from any of its counterparties nor do its counterparties currently require collateral from the Company.

21

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

The Company enters into certain commodity derivative instruments to mitigate commodity price risk associated with a portion of its future natural gas and oil production and related cash flows. The natural gas and oil 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 and oil 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 on derivative contracts on the condensed Consolidated Statements of Operations and Comprehensive Income. The related cash flow impact is reflected in cash flows from operating activities. During the three and six months ended June 30, 2025, Epsilon recognized gains on commodity derivative contracts of $2,573,863 and $1,111,693, respectively. These amounts included cash received of $306,660 and cash paid of $108,383 on settlements on these contracts, respectively. For the three and six months ended June 30, 2024, Epsilon recognized losses on commodity derivative contracts of $94,891 and $195,617, respectively. These amounts included cash received on settlements on these contracts of $272,257 and $760,542, respectively.

Commodity Derivative Contracts

At June 30, 2025, the Company had outstanding natural gas NYMEX Henry Hub (“HH”) swaps totaling 2.67 Bcf, natural gas Tennessee Z4 basis swaps totaling 0.78 Bcf, natural gas NYMEX HH options totaling 0.93 Bcf, and crude oil NYMEX WTI CMA swaps totaling 40 MBbls.

	Fair Value of Derivative  Assets
	June 30,		December 31,
	2025		2024
Current
Henry Hub Nymex Swap	$	322,385	$	151,274
Tennessee Z4 Basis swap		351,769		195,211
Henry Hub Nymex Option - Put		181,254		—
Crude Oil NYMEX WTI CMA		263,462		56,547
Long-term
Henry Hub Nymex Swap		7,225		—
Henry Hub Nymex Option - Put		222,199		—
	$	1,348,294	$	403,032

	Fair Value of Derivative  Liabilities
	June 30,		December 31,
	2025		2024
Current
Henry Hub Nymex Swap	$	(264,965)	$	(448,852)
Tennessee Z4 Basis swap		—		(441,728)
Henry Hub Nymex Option - Call		(105,437)		—
Long-term
Henry Hub Nymex Swap		(51,406)		—
Henry Hub Nymex Option - Call		(193,958)		—
	$	(615,766)	$	(890,580)
Net Fair Value of Derivatives	$	732,528	$	(487,548)

22

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

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,
	2025		2024		2025		2024
Fair value of (liability) asset, beginning of the period	$	(1,534,675)	$	511,244	$	(487,548)	$	1,100,255
Gain/(loss) on derivative contracts included in earnings		2,573,863		(94,891)		1,111,693		(195,617)
Settlement of commodity derivative contracts		(306,660)		(272,257)		108,383		(760,542)
Fair value of asset, end of the period	$	732,528	$	144,096	$	732,528	$	144,096

16. Asset Retirement Obligations

Asset retirement obligations are 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, and the forecast risk free cost of capital. Each year we review, and to the extent necessary, revise our asset retirement obligations estimates in accordance with recent activity and current service costs.

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

	Six Months Ended		Year ended
		June 30,		December 31,
	2025		2024
Balance beginning of period	$	3,652,296	$	3,502,952
Liabilities acquired		18,235		48,207
Wells plugged and abandoned		(1,600)		(88,992)
Change in estimates		—		6,695
Accretion		95,885		183,434
Balance end of period	$	3,764,816	$	3,652,296

17. Fair Value Measurements

The methodologies used to determine the fair value of our financial assets and liabilities at June 30, 2025 were the same as those used at December 31, 2024.

Cash and cash equivalents, restricted cash, accounts receivable, and accounts payable 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. The revolving line of credit is classified within Level 2 of the fair value hierarchy.

Commodity derivative instruments consist of NYMEX HH swap, NYMEX HH option, and Tennessee Z4 basis swap contracts for natural gas, and NYMEX WTI CMA swap contracts for crude oil. 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.

	June 30, 2025
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	1,348,294	$	—	$	(615,766)	$	732,528
Cash equivalents	$	261,512	$	—	$	—	$	—	$	261,512
Liabilities
Derivative contracts	$	—	$	615,766	$	—	$	(615,766)	$	—

23

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

	December 31, 2024
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	403,032	$	—	$	(403,032)	$	—
Cash equivalents	$	298,767	$	—	$	—	$	—	$	298,767
Liabilities
Derivative contracts	$	—	$	890,580	$	—	$	(403,032)	$	487,548

Non-Recurring Fair Value Measurements

The Company performed an impairment test on our oil and gas properties and it was determined that the carrying amount of the Canada asset exceeded the estimated undiscounted future cash flows resulting in a reduction of the carrying amount of the properties to their estimated fair values by $2.7 million. This nonrecurring fair value measurement is classified within Level 3 of the fair value hierarchy. For the year ended December 31, 2024, there was an impairment of $1.45 million.

The table below summarizes the fair value of the impaired assets at June 30, 2025.

			Quoted Prices		Significant
			in Active		Other		Significant
			Markets for		Observable		Unobservable
	June 30,		Identical Assets		Inputs		Inputs
	2025		(Level 1)		(Level 2)		(Level 3)
Nonrecurring fair value measurement
Long-lived assets held and used	$	1,342,942	$	—	$	—	$	1,342,942
Total Nonrecurring fair value measurement	$	1,342,942	$	—	$	—	$	1,342,942

The table below summarizes the fair value of the impaired assets at December 31, 2024.

			Quoted Prices		Significant
			in Active		Other		Significant
			Markets for		Observable		Unobservable
	December 31,		Identical Assets		Inputs		Inputs
	2024		(Level 1)		(Level 2)		(Level 3)
Nonrecurring fair value measurement
Long-lived assets held and used	$	492,253	$	—	$	—	$	492,253
Total Nonrecurring fair value measurement	$	492,253	$	—	$	—	$	492,253

18. Subsequent Events

On August 11, 2025, Epsilon signed definitive agreements to acquire two entities, Peak Exploration and Production LLC and Peak BLM Lease LLC (together, “Peak”). Consideration at closing is proposed as the issuance of 6 million Epsilon common shares and the assumption of approximately $49 million in debt. Additional consideration is proposed as the issuance of 1.5 - 2.5 million Epsilon common shares are contingent on the receipt of drilling permits on, and the ability to access, leasehold currently affected by a drilling moratorium in Converse County, Wyoming.  If the conditions are not met by year-end 2027, Epsilon has a $6.5 million cash option to retain the affected undeveloped leasehold.

The acquired assets include an operated position of 40,500 net acres producing 2.2 MBoepd in the Powder River Basin in Campbell and Converse County, Wyoming.

The transaction is subject to a shareholder vote; the associated proxy process will run in the interim period between signing and closing. If approved, the transaction is expected to close in the fourth quarter of 2025.

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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 our 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, 2025 and 2024 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, 2024. 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 primary areas of operations are the Marcellus shale section of the Appalachian basin in Pennsylvania, the Permian Basin in Texas and New Mexico, the NW Anadarko Basin in Oklahoma, and the Western Canadian Sedimentary Basin in Alberta, Canada.

At June 30, 2025 we held leasehold rights to 24,316 net acres. We have natural gas production from our non-operated wells in Pennsylvania, and oil, natural gas liquids, and natural gas production from our non-operated wells in Texas, New Mexico, Oklahoma, and Alberta, Canada.

At December 31, 2024 our total estimated net proved reserves were 69,401 MMcf of natural gas, 876,808 Bbls of NGLs, and 1,572,465 Bbls of oil and condensate.

In Pennsylvania, the Company owns a 35% interest in the 45-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

We are committed to disciplined capital allocation including shareholder returns in the form of dividends and share buybacks. We plan to maintain a strong balance sheet and liquidity position to allow us to opportunistically invest in both our existing project areas and potential new projects.     

Historically, our investments have been focused on our position in the Marcellus unconventional reservoir in Pennsylvania (“PA”). Our PA assets are supported by our 35% ownership in the Auburn GGS and we have a substantial remaining drillable location inventory within our existing leaseholds.

More recently, our investments have been focused in the Permian Basin in Texas and the Western Canadian Sedimentary Basin in Alberta, Canada.

On February 26, 2024, Epsilon acquired a 25% interest in three producing wells and 3,620 gross undeveloped acres in Ector County, Texas from a private operator. The Company participated in the drilling and completion of 2 gross (0.5 net) wells during 2024 which were put on production in May 2024 and July 2024. Together with the transaction completed in 2023, the Company holds a 25% working interest in 16,592 gross acres and 7 producing wells in Texas. Total capital expenditures (net to Epsilon) through June 30, 2025 in the project (including undeveloped leasehold) are $40 million.

On April 11, 2024, Epsilon acquired a 50% working interest in 14,243 gross undeveloped acres in Alberta, Canada. The Company participated in the drilling and completion of 2 gross (0.5 net) wells. One well was put on production in September 2024. One well was deemed non-commercial. Total capital expenditures (net to Epsilon) through June 30, 2025 in the project (including undeveloped leasehold) are $3.5 million (pre-impairment).

25

In October 2024, Epsilon formed a joint venture with a private operator covering approximately 130,000 gross acres in Garrington and Harmattan areas in Alberta, Canada. The Company provided a $7 million drilling carry in favor of the operator in exchange for a 25% working interest in the leasehold. To date, the Company participated in the drilling and completion of 2 gross (0.5 net) wells. Total capital expenditures (net to Epsilon) through June 30, 2025 are $8.9 million (pre-impairment).

We continue to evaluate new opportunities in numerous onshore North American basins.

Three and six months ended June 30, 2025 Highlights

Operational Highlights

Marcellus Shale – Pennsylvania

● During the three months ended June 30, 2025, Epsilon's realized natural gas price was $2.53 per Mcf, a 76% increase over the three months ended June 30, 2024. During the six months ended June 30, 2025, Epsilon's realized natural gas price was $3.22 per Mcf, a 99% increase over the six months ended June 30, 2024.

● During the three months ended June 30, 2025, Epsilon’s net revenue interest natural gas production was 2.7 Bcf, a 107% increase over the three months ended June 30, 2024. During the six months ended June 30, 2025, Epsilon’s net revenue interest natural gas production was 5.3 Bcf, an 86% increase over the six months ended June 30, 2024.

● Gathered and delivered 11.2 Bcf gross (3.9 net to Epsilon's interest) during the three months ended June 30, 2025, or 123 MMcf/d through the Auburn Gas Gathering System. Gathered and delivered 22.8 Bcf gross (8.0 net to Epsilon's interest) during the six months ended June 30, 2025, or 126 MMcf/d through the Auburn Gas Gathering System.

Permian Basin – Texas and New Mexico

● During the three months ended June 30, 2025, Epsilon's realized price for all Permian Basin production was $51.79 per Boe (88% liquids), a 4% decrease over the three months ended June 30, 2024. During the six months ended June 30, 2025, Epsilon's realized price for all Permian Basin production was $53.46 per Boe (87% liquids), a 0.02% decrease over the six months ended June 30, 2024.

● Total net revenue interest production for the three months ended June 30, 2025, which included oil, natural gas liquids, and natural gas, was 42.9 Mboe compared to 65.9 Mboe during the same period in 2024, an 35% decrease. Total net revenue interest production for the six months ended June 30, 2025, which included oil, natural gas liquids, and natural gas, was 104.9 Mboe compared to 118.2 Mboe during the same period in 2024, an 11% decrease.

● At June 30, 2025, the Company had 1 gross (.25 net) well drilled and awaiting completion in Texas.

Anadarko, NW Stack Trend – Oklahoma

● During the three months ended June 30, 2025, Epsilon's realized price for all Oklahoma production was $4.40 per Mcfe (60% natural gas), a 3% increase from the three months ended June 30, 2024. During the six months ended June 30, 2025, Epsilon's realized price for all Oklahoma production was $4.85 per Mcfe (60% natural gas), a 10% increase from the six months ended June 30, 2024.

● Total net revenue interest production for the three months ended June 30, 2025 included natural gas, oil and other liquids and was 0.09 Bcfe, a 22% decrease from the same period in 2024. Total net revenue interest production for the six months ended June 30, 2025 included natural gas, oil and other liquids and was 0.2 Bcfe, a 10% decrease from the same period in 2024.

26

Western Canadian Sedimentary Basin—Alberta, Canada

● During the three months ended June 30, 2025, Epsilon's realized price for all Canada production was $42.23 per Boe (75% liquids). During the six months ended June 30, 2025, Epsilon's realized price for all Canada production was $43.48 per Boe (78% liquids). The Company had no Canada production in 2024.

● Total net revenue interest production for the three months ended June 30, 2025, which included oil, natural gas liquids, and natural gas, was 11.3 Mboe. Total net revenue interest production for the six months ended June 30, 2025, which included oil, natural gas liquids, and natural gas, was 13.1 Mboe.

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 sale of assets, (7) gain or loss on derivative contracts net of cash received or paid on settlement, and (8) net other income(expense). 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 Adjusted 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, 2025 and 2024, which is the most directly comparable measure of financial performance calculated under U.S. GAAP and should be reviewed carefully.

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Net income	$	1,551,461	$	815,660	$	5,567,495	$	2,322,556
Add Back:
Interest expense (income), net		2,659		(100,184)		(429)		(357,696)
Income tax expense		1,837,687		459,016		3,507,881		513,066
Depreciation, depletion, amortization, and accretion		3,201,654		2,048,403		6,677,511		4,428,829
Impairment expense		2,670,000		—		2,676,669		—
Stock based compensation expense		385,838		313,589		771,676		635,158
(Gain) loss on derivative contracts net of cash received or paid on settlement		(2,267,203)		367,148		(1,220,076)		956,159
Foreign currency translation loss		14,021		—		24,310		570
Adjusted EBITDA	$	7,396,117	$	3,903,632	$	18,005,037	$	8,498,642

27

Results of Operations

Net Operating Revenues

For the six months ended June 30, 2025 revenues increased $12.5 million, or 82%, to $27.8 million from $15.3 million during the same period of 2024.

Revenue and volume statistics for the three and six months ended June 30, 2025 and 2024 were as follows:

	Three months ended				Six months ended
	June 30,				June 30,
	2025		2024		2025		2024
Revenues
Pennsylvania
Natural gas revenue	$	6,702,131	$	1,843,548	$	17,030,025	$	4,601,656
Volume (MMcf)		2,653		1,285		5,290		2,841
Avg. Price ($/Mcf)	$	2.53	$	1.44	$	3.22	$	1.62
Gathering system revenue (net of elimination)	$	1,845,005	$	1,444,448	$	3,737,355	$	3,380,146
Total PA Revenues	$	8,547,136	$	3,287,996	$	20,767,380	$	7,981,802
Permian Basin
Natural gas revenue	$	17,189	$	(2,757)	$	95,528	$	38,821
Volume (MMcf)		30		58		80		101
Avg. Price ($/Mcf)	$	0.56	$	(0.05)	$	1.19	$	0.38
Natural gas liquids revenue	$	41,837	$	281,770	$	326,798	$	541,684
Volume (MBOE)		3.2		14.5		15.3		26.0
Avg. Price ($/Bbl)	$	13.06	$	19.38	$	21.36	$	20.85
Oil and condensate revenue	$	2,163,481	$	3,266,693	$	5,182,976	$	5,753,206
Volume (MBbl)		34.6		41.7		76.2		75.4
Avg. Price ($/Bbl)	$	62.47	$	78.35	$	68.06	$	76.35
Total Permian Basin Revenues	$	2,222,507	$	3,545,706	$	5,605,302	$	6,333,711
Oklahoma
Natural gas revenue	$	166,635	$	120,439	$	373,975	$	283,732
Volume (MMcf)		52		65		105		131
Avg. Price ($/Mcf)	$	3.20	$	1.86	$	3.57	$	2.17
Natural gas liquids revenue	$	79,789	$	106,653	$	182,078	$	219,723
Volume (MBOE)		3.7		4.7		7.4		9.3
Avg. Price ($/Bbl)	$	21.61	$	22.78	$	24.64	$	23.52
Oil and condensate revenue	$	133,446	$	247,024	$	291,383	$	475,593
Volume (MBbl)		2.0		3.1		4.3		6.1
Avg. Price ($/Bbl)	$	66.00	$	79.66	$	68.29	$	78.38
Total OK Revenues	$	379,870	$	474,116	$	847,436	$	979,048
Canada
Natural gas revenue	$	24,389	$	—	$	24,389	$	—
Volume (MMcf)		17		—		17		—
Avg. Price ($/Mcf)	$	1.44	$	—	$	1.44	$	—
Natural gas liquids revenue	$	23,394	$	—	$	23,394	$	—
Volume (MBOE)		0.9		—		0.9		—
Avg. Price ($/Bbl)	$	24.91	$	—	$	24.91	$	—
Oil and condensate revenue	$	427,437	$	—	$	519,972	$	—
Volume (MBbl)		7.5		—		9.3		—
Avg. Price ($/Bbl)	$	57.11	$	—	$	55.98	$	—
Total Canada Revenues	$	475,220	$	—	$	567,755	$	—
Total Revenues	$	11,624,733	$	7,307,818	$	27,787,873	$	15,294,561

Upstream natural gas revenue for the six months ended June 30, 2025 increased by $12.6 million, or 256%, over the same period in 2024. An increase of $8.7 million was due to higher natural gas prices and an increase of $3.9 million was a result of previously delayed turn in line wells coming online in Pennsylvania and the end of operator-elected well

28

shut-ins in Pennsylvania. Upstream natural gas revenue for the three months ended June 30, 2025 increased by $5.0 million, or 252%, over the same period in 2024. An increase of $3.1 million was due to higher natural gas prices and an increase of $1.9 million was a result of previously delayed turn in line wells coming online in Pennsylvania and the end of operator-elected well shut-ins in Pennsylvania.

Upstream natural gas liquids revenue for the six months ended June 30, 2025 decreased by $0.2 million, or 30%, over the same period in 2024. This decrease was mostly due to lower volumes in the Permian Basin as a result of processing disruptions at the Goldsmith plant in Texas in the second quarter. Upstream natural gas liquids revenue for the three months ended June 30, 2025 decreased by $0.2 million, or 63%, over the same period in 2024. This decrease was mostly due to lower volumes in the Permian Basin as a result of the aforementioned processing disruption.

Upstream oil and condensate revenue for the six months ended June 30, 2025 decreased by $0.2 million, or 4% over the same period in 2024.  An increase of $0.6 million was due to additional sales volumes from new wells drilled and acquired in the Permian Basin and Canada partially offset by a decrease of $0.9 million due to lower prices. Upstream oil and condensate revenue for the three months ended June 30, 2025 decreased by $0.8 million, or 22% over the same period in 2024.  A decrease of $0.05 million was due to constant sales volumes and a decrease of $0.75 million was due to lower prices.

Gathering system revenue for the six months ended June 30, 2025 increased by $0.4 million, or 11%, compared with the same period in 2024 as a result of crossflow gas being displaced with Anchor Shipper gas which is charged a higher gathering fee. Gathering system revenue for the three months ended June 30, 2025 increased by $0.4 million, or 28%, compared with the same period in 2024 due to higher volumes and a higher percentage of Anchor Shipper gas. Revenues derived from transporting and compressing our production, which have been eliminated from gathering system revenues amounted to $0.5 million and $1.1 million, respectively, for the three and six months ended June 30, 2025, and $0.3 million and $0.6 million, respectively, for the three and six months ended June 30, 2024.

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, 2025 and 2024:

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Lease operating costs (net of elimination)	$	2,462,785	$	1,649,867	$	5,218,683	$	3,418,329
Gathering system operating costs		613,795		649,967		1,166,446		1,202,537
	$	3,076,580	$	2,299,834	$	6,385,129	$	4,620,866
Upstream operating costs—Total $/Mcfe		0.80		0.92	$	0.85	$	0.91
Gathering system operating costs $/Mcf		0.15		0.20	$	0.14	$	0.14

Operating costs include the effects of elimination entries to remove the gathering fees paid to Epsilon’s ownership in the gathering system.

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. For the six months ended June 30, 2025 these costs increased by $1.8 million, or 53%, over the same period in 2024. The increase is primarily due to higher volumes. For the three months ended June 30, 2025 these costs increased by $0.8 million, or 49%, over the same period in 2024. The increase is primarily due to higher volumes.

Gathering system operating costs consist primarily of rental payments for the natural gas fueled compression units and overhead fees due to the system’s operator. For the three and six months ended June 30, 2025, gathering system operating costs were constant compared to the same period in 2024.

29

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

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Depletion, depreciation, amortization and accretion	$	3,201,654	$	2,048,403	$	6,677,511	$	4,428,829

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 properties, the reserve base used to calculate depreciation and depletion is total proved reserves. For natural gas and oil development and gathering system costs, the reserve base used to calculate depletion and depreciation is proved developed reserves.

Depreciation expense includes amounts pertaining to our office furniture and fixtures, leasehold improvements, 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 costs.

DD&A expense for the three and six months ended June 30, 2025 increased by $1.2 million, or 56%, and $2.2 million, or 51%, respectively, from the same period in 2024. This increase was a result of higher produced volumes in Pennsylvania and the Permian Basin.

Impairment

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Impairment	$	2,670,000	$	—	$	2,676,669	$	—

We perform a quantitative impairment test whenever events or changes in circumstances indicate that an asset group's carrying amount may not be recoverable, over proved properties using the market forward prices, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, GAAP requires that the Company first compare 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 value is required. Additionally, GAAP requires that if an exploratory well is determined not to have found proved reserves, the costs incurred, net of any salvage value, should be charged to expense.

For the three and six months ended June 30, 2025, the Company recorded an impairment of $2.7 million for two wells drilled in Alberta, Canada. The impairment was a result of a decrease in estimated reserves due to early production coming in below expectations, cost overruns and lower forward commodity prices. For the three and six months ended June 30, 2024, there was no impairment.

General and Administrative (“G&A”)

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
General and administrative	$	1,847,716	$	1,791,804	$	4,051,972	$	3,672,396

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 restricted stock granted.

30

G&A expenses for the six months ended June 30, 2025 increased by $0.4 million, or 10% from the same period in 2024. This was primarily due to higher compensation expenses. G&A expenses for the three months ended June 30, 2025 was constant from the same period in 2024.

Interest Income

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Interest income	$	17,247	$	108,943	$	32,546	$	375,215

Interest income for the three and six months ended June 30, 2025 decreased by $0.1 million, or 84%, and $0.3 million, or 91%, respectively, from the same period in 2024.  This was primarily due to a reduction in the balance of cash and short term investments.

Interest Expense

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Interest expense	$	19,906	$	8,759	$	32,117	$	17,519

Interest expense is related to the fees paid on the revolving credit facility.

Interest expense during the three and six months ended June 30, 2025 and 2024 was relatively flat.

Gain (Loss) on Derivative Contracts

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Gain (Loss) on derivative contracts	$	2,573,863	$	(94,891)	$	1,111,693	$	(195,617)

For the six months ended June 30, 2025, Epsilon had NYMEX HH Natural Gas futures swaps, Tennessee Gas Pipeline Zone 4 basis swaps, NYMEX HH options, and crude oil NYMEX WTI CMA swaps derivative contracts for the purpose of hedging a portion of its physical natural gas and oil sales revenue. The amounts recorded represent the fair value changes on our derivative instruments during the year.

During the three months ended June 30, 2025, we received net cash settlements of $306,660. During the six months ended June 30, 2025, we paid net cash settlements of $108,383.  During the three and six months ended June 30, 2024, we received net cash settlements of $272,257 and $760,542, respectively.

For the three and six months ended June 30, 2025, realized gains on derivative contracts increased by $2.7 million and $1.3 million, respectively. This increase was primarily the result of a significant decrease in Henry Hub natural gas prices during the quarter.

Capital Resources and Liquidity

Cash Flow

The primary source of cash for Epsilon during the three and six months ended June 30, 2025 and 2024 was funds generated from operations. The primary uses of cash for the three and six months ended June 30, 2025 were the development of upstream properties and the distribution of dividends. The primary uses of cash for the three months ended

31

June 30, 2024 were the development of upstream properties, investment in U.S. Treasury Bills, the repurchase of shares of common stock, and the distribution of dividends.

At June 30, 2025, we had a working capital surplus of $9.1 million, an increase of $1.9 million from the $7.2 million surplus at December 31, 2024. The Company anticipates its current cash balance, available borrowings, and cash flows from operations to be sufficient to meet its cash requirements for at least the next twelve months.

Six months ended June 30, 2025 compared to 2024

During the six months ended June 30, 2025, $16.9 million was provided by the Company’s operating activities, compared to $9.1 million during the same period in 2024, representing an 87% increase. The increase was primarily due to higher produced volumes and realized prices in Pennsylvania.

The Company used $10.7 million and $9.5 million of cash for investing activities during the six months ended June 30, 2025 and 2024, respectively. During the six months ended June 30, 2025, the Company had net investments of $10.7 million primarily in well costs and leasehold in Pennsylvania, Texas, and Canada. During the six months ended June 30, 2024, the Company had net investments of $28.6 million in leasehold and well costs in Pennsylvania and Texas offset by net proceeds of $19.1 million in U.S. Treasury Bills.

The Company used $2.8 million and $3.9 million of cash for financing activities during the six months ended June 30, 2025 and 2024, respectively. During the six months ended June 30, 2025, this was spent on dividend payments. During the six months ended June 30, 2024, this was spent on dividend payments and the repurchase of shares of common stock.

Credit Agreement

The Company closed a senior secured reserve based revolving credit facility on June 28, 2023 with Frost Bank as issuing bank and sole lender. The current borrowing base is $45 million (redetermined as of February 10, 2025), supported by the Company’s upstream assets in Pennsylvania and subject to semi-annual redeterminations with a maturity date of June 28, 2027. Interest will be charged at the Daily Simple SOFR rate plus a margin of 3.25%. The facility is secured by the assets of the Company’s Epsilon Energy USA subsidiary (Borrower). There are currently no borrowings under the facility.

Under the terms of the facility, the Company must adhere to the following financial covenants:

● Current ratio of 1.0 to 1.0 (current assets / current liabilities)

● Leverage ratio of less than 2.5 to 1.0 (total debt / income adjusted for interest, taxes and non-cash amounts)

Additionally, if the Leverage ratio is greater than 1.0 to 1.0, or the borrowing base utilization is greater than 50%, the Company is required to hedge 50% of the anticipated production from PDP reserves for a rolling 24 month period.

Repurchase Transactions

On February 12, 2025, Epsilon’s board of directors (the “Board”) authorized a new share repurchase program of up to 2,200,876 common shares, representing 10% of the current outstanding common shares of Epsilon, for an aggregate purchase price of not more than US $13.0 million. The program commenced on February 12, 2025 and ends on February 11, 2026, unless the maximum amount of common shares is purchased before then or the Board approves earlier termination.

The previous share repurchase program commenced on March 19, 2024.  During the year ended December 31, 2024, we repurchased 125,000 common shares and spent $627,500 at an average price of $5.00 per share (excluding commissions) under the plan. On February 12, 2025, the Board terminated and revoked authority under the program.

32

During the six months ended June 30, 2025, no shares were repurchased under the new or previous program.

Derivative Transactions

The Company has entered into hedging arrangements to reduce the impact of commodity price volatility on operations. By reducing the price volatility from a portion of natural gas and crude oil production, the potential effects of changing prices on operating cash flows have been partially 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, 2025, Epsilon’s outstanding natural gas and crude oil commodity contracts consisted of the following:

		Weighted Average Price ($/Mmbtu)
	Volume			Ceiling		Floor		Basis		Fair Value of Asset
Derivative Type	(MMbtu)	Swaps		Price		Price		Differential		June 30, 2025
2025
Henry Hub Nymex Swap	1,026,000	$	3.65	$	—	$	—	$	—	$	(144,265)
Tennessee Z4 Basis swap	782,000	$	—	$	—	$	—	$	(0.95)	$	351,769
Henry Hub Nymex Option - Put	122,000	$	—	$	—	$	4.00	$	—	$	48,138
Henry Hub Nymex Option - Call	—	$	—	$	6.17	$	—	$	—	$	(15,996)
2026
Henry Hub Nymex Swap	1,644,000	$	4.24	$	—	$	—	$	—	$	157,504
Henry Hub Nymex Option - Put	623,000	$	—	$	—	$	4.72	$	—	$	250,131
Henry Hub Nymex Option - Call	—	$	—	$	4.79	$	—	$	—	$	(191,398)
2027
Henry Hub Nymex Option - Put	180,000	$	—	$	—	$	4.00	$	—	$	105,184
Henry Hub Nymex Option - Call	—	$	—	$	6.18	$	—	$	—	$	(92,002)
	4,377,000									$	469,065

				Fair Value
	Volume	Weighted Average		June 30,
Derivative Type	(Bbl)	Price ($/Bbl)		2025
2025
Crude Oil NYMEX WTI CMA	39,600	$	69.19	$	263,462
	39,600			$	263,462

Contractual Obligations

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of June 30, 2025, the Company has commitments of $1.9 million for capital expenditures and has undiscounted long term commitments of $15.7 million for asset retirement obligations.

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.

33

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.

At June 30, 2025 and 2024, 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 production. Natural gas, natural gas liquids, and crude oil 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 to other regions, as well as conditions in other 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 chief executive officer and our chief 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 chief executive officer and chief 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 chief executive officer and chief financial officer have concluded that our current disclosure controls and procedures were effective as of June 30, 2025 at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

No changes in our internal control over financial reporting occurred during the quarter ended June 30, 2025 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.

34

PART II OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

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, 2024.

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

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

For the six months ended June 30, 2025, no shares had been repurchased.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

Not applicable.

35

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)

36

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 13, 2025	By:	/s/ J. Andrew Williamson
		J. Andrew Williamson
		Chief Financial Officer

37

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 13, 2025

/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 13, 2025

/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, 2025 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 13, 2025

/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, 2025 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 13, 2025

/s/ J. Andrew Williamson

J. Andrew Williamson

Chief Financial Officer

XML

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	Jun. 30, 2025	Aug. 12, 2025
Cover [Abstract]
Document Type	10-Q
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Document Period End Date	Jun. 30, 2025
Document Fiscal Year Focus	2025
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Securities Act 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	500 Dallas Street
Entity Address, Address Line Two	Suite 1250
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
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
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Unaudited Condensed Consolidated Balance Sheets - USD ($)	Jun. 30, 2025	Dec. 31, 2024
Current assets
Cash and cash equivalents	$ 9,907,653	$ 6,519,793
Accounts receivable	5,496,883	5,843,722
Fair value of derivatives	732,528	0
Prepaid income taxes	0	975,963
Other current assets	396,264	792,041
Total current assets	16,533,328	14,131,519
Oil and gas properties, successful efforts method
Proved properties	197,197,902	191,879,210
Unproved properties	33,496,835	28,364,186
Accumulated depletion, depreciation, amortization and impairment	(131,899,045)	(123,281,395)
Total oil and gas properties, net	98,795,692	96,962,001
Gathering system	43,416,065	43,116,371
Accumulated depletion, depreciation, amortization and impairment	(37,057,605)	(36,449,511)
Total gathering system, net	6,358,460	6,666,860
Land	637,764	637,764
Buildings and other property and equipment, net	245,555	259,335
Total property and equipment, net	106,037,471	104,525,960
Other assets:
Operating lease right-of-use assets, long term	295,317	344,589
Restricted cash	470,000	470,000
Prepaid drilling costs	277,552	982,717
Total non-current assets	107,080,340	106,323,266
Total assets	123,613,668	120,454,785
Current liabilities
Accounts payable trade	2,018,533	2,334,732
Gathering fees payable	1,139,057	997,016
Royalties payable	1,553,262	1,400,976
Income taxes payable	1,596,958	0
Accrued capital expenditures	225,923	572,079
Accrued compensation	465,055	695,018
Other accrued liabilities	283,540	371,503
Fair value of derivatives	0	487,548
Operating lease liabilities	121,057	121,135
Total current liabilities	7,403,385	6,980,007
Non-current liabilities
Asset retirement obligations	3,764,816	3,652,296
Deferred income taxes	11,958,901	12,738,577
Operating lease liabilities, long term	296,250	355,776
Total non-current liabilities	16,019,967	16,746,649
Total liabilities	23,423,352	23,726,656
Commitments and contingencies (Note 11)
Shareholders' equity
Preferred shares, no par value, unlimited shares authorized, none issued or outstanding	0	0
Common shares, no par value, unlimited shares authorized and 22,017,405 shares issued and outstanding at June 30, 2025 and 22,008,766 issued and outstanding at December 31, 2024	116,081,031	116,081,031
Additional paid-in capital	12,890,583	12,118,907
Accumulated deficit	(38,688,953)	(41,505,076)
Accumulated other comprehensive income	9,907,655	10,033,267
Total shareholders' equity	100,190,316	96,728,129
Total liabilities and shareholders' equity	$ 123,613,668	$ 120,454,785

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Unaudited Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2025	Dec. 31, 2024
Stockholders' Equity, Number of Shares, Par Value and Other Disclosure [Abstract]
Preferred shares, no par value	$ 0	$ 0
Preferred shares, unlimited authorized	Unlimited	Unlimited
Preferred shares issued	0	0
Preferred shares outstanding	0	0
Common shares, no par value	$ 0	$ 0
Common shares, unlimited authorized	Unlimited	Unlimited
Common shares issued	22,017,405	22,008,766
Common shares outstanding	22,017,405	22,008,766

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Unaudited Condensed Consolidated Statements of Operations and Comprehensive Income - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Revenues from contracts with customers:
Total revenue	$ 11,624,733	$ 7,307,818	$ 27,787,873	$ 15,294,561
Operating costs and expenses:
Lease operating expenses	2,462,785	1,649,867	5,218,683	3,418,329
Gathering system operating expenses	613,795	649,967	1,166,446	1,202,537
Depletion, depreciation, amortization, and accretion	3,201,654	2,048,403	6,677,511	4,428,829
Impairment expense	2,670,000	0	2,676,669	0
General and administrative expenses:
Stock based compensation expense	385,838	313,589	771,676	635,158
Other general and administrative expenses	1,461,878	1,478,215	3,280,296	3,037,238
Total operating costs and expenses	10,795,950	6,140,041	19,791,281	12,722,091
Operating income	828,783	1,167,777	7,996,592	2,572,470
Other income (expense):
Interest income	17,247	108,943	32,546	375,215
Interest expense	(19,906)	(8,759)	(32,117)	(17,519)
Gain (loss) on derivative contracts	2,573,863	(94,891)	1,111,693	(195,617)
Other (expense) income	(10,839)	101,606	(33,338)	101,073
Other income, net	2,560,365	106,899	1,078,784	263,152
Net income before income tax expense	3,389,148	1,274,676	9,075,376	2,835,622
Income tax expense	1,837,687	459,016	3,507,881	513,066
NET INCOME	1,551,461	815,660	5,567,495	2,322,556
Currency translation adjustments	(75,496)	22,229	(125,612)	22,593
Unrealized gain (loss) on securities	0	3,011	0	(1,598)
NET COMPREHENSIVE INCOME	$ 1,475,965	$ 840,900	$ 5,441,883	$ 2,343,551
Net income per share, basic (in dollars per share)	$ 0.07	$ 0.04	$ 0.25	$ 0.11
Net income per share, diluted (in dollars per share)	$ 0.07	$ 0.04	$ 0.25	$ 0.11
Weighted average number of shares outstanding, basic (in shares)	22,017,310	21,921,752	22,013,062	21,957,980
Weighted average number of shares outstanding, diluted (in shares)	22,202,315	22,029,475	22,155,629	21,987,142
Gas, oil, NGL, and condensate revenue
Revenues from contracts with customers:
Total revenue	$ 9,779,728	$ 5,863,370	$ 24,050,518	$ 11,914,415
Gas gathering and compression revenue
Revenues from contracts with customers:
Total revenue	$ 1,845,005	$ 1,444,448	$ 3,737,355	$ 3,380,146

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Unaudited Condensed Consolidated Statements of Changes in Shareholders' Equity - USD ($)	Common Shares	Treasury Shares	Additional paid-in Capital	Accumulated Other Comprehensive Income	Accumulated Deficit	Total
Balance at beginning of period at Dec. 31, 2023	$ 118,272,565	$ (360,326)	$ 10,874,491	$ 9,772,277	$ (37,946,042)	$ 100,612,965
Balance (in shares) at Dec. 31, 2023	22,222,722
Treasury Shares, Beginning Balance (in shares) at Dec. 31, 2023		(70,874)
Increase (Decrease) in Stockholders' Equity
Net income					1,506,896	1,506,896
Dividends paid					(1,370,409)	(1,370,409)
Stock-based compensation expense			321,569			321,569
Buyback of common shares		$ (1,203,708)				(1,203,708)
Buyback of common shares (in shares)		(248,700)
Retirement of treasury shares	$ (1,564,034)
Retirement of treasury shares (in shares)	(319,574)
Treasury Shares, Retirement of treasury shares		$ 1,564,034
Treasury Shares, Retirement of treasury shares (in shares)		319,574
Vesting of shares of restricted stock (in shares)	10,054
Other comprehensive (loss) income				(4,245)		(4,245)
Balance at end of period at Mar. 31, 2024	$ 116,708,531		11,196,060	9,768,032	(37,809,555)	99,863,068
Balance (in shares) at Mar. 31, 2024	21,913,202
Balance at beginning of period at Dec. 31, 2023	$ 118,272,565	$ (360,326)	10,874,491	9,772,277	(37,946,042)	100,612,965
Balance (in shares) at Dec. 31, 2023	22,222,722
Treasury Shares, Beginning Balance (in shares) at Dec. 31, 2023		(70,874)
Balance at end of period at Jun. 30, 2024	$ 116,708,531		11,509,649	9,793,272	(38,365,835)	99,645,617
Balance (in shares) at Jun. 30, 2024	21,921,850
Balance at beginning of period at Mar. 31, 2024	$ 116,708,531		11,196,060	9,768,032	(37,809,555)	99,863,068
Balance (in shares) at Mar. 31, 2024	21,913,202
Increase (Decrease) in Stockholders' Equity
Net income					815,660	815,660
Dividends paid					(1,371,940)	(1,371,940)
Stock-based compensation expense			313,589			313,589
Vesting of shares of restricted stock (in shares)	8,648
Other comprehensive (loss) income				25,240		25,240
Balance at end of period at Jun. 30, 2024	$ 116,708,531		11,509,649	9,793,272	(38,365,835)	99,645,617
Balance (in shares) at Jun. 30, 2024	21,921,850
Balance at beginning of period at Dec. 31, 2024	$ 116,081,031		12,118,907	10,033,267	(41,505,076)	96,728,129
Balance (in shares) at Dec. 31, 2024	22,008,766
Increase (Decrease) in Stockholders' Equity
Net income					4,016,034	4,016,034
Dividends paid					(1,375,612)	(1,375,612)
Stock-based compensation expense			385,838			385,838
Other comprehensive (loss) income				(50,116)		(50,116)
Balance at end of period at Mar. 31, 2025	$ 116,081,031		12,504,745	9,983,151	(38,864,654)	99,704,273
Balance (in shares) at Mar. 31, 2025	22,008,766
Balance at beginning of period at Dec. 31, 2024	$ 116,081,031		12,118,907	10,033,267	(41,505,076)	$ 96,728,129
Balance (in shares) at Dec. 31, 2024	22,008,766
Increase (Decrease) in Stockholders' Equity
Retirement of treasury shares (in shares)						0
Balance at end of period at Jun. 30, 2025	$ 116,081,031		12,890,583	9,907,655	(38,688,953)	$ 100,190,316
Balance (in shares) at Jun. 30, 2025	22,017,405
Balance at beginning of period at Mar. 31, 2025	$ 116,081,031		12,504,745	9,983,151	(38,864,654)	99,704,273
Balance (in shares) at Mar. 31, 2025	22,008,766
Increase (Decrease) in Stockholders' Equity
Net income					1,551,461	1,551,461
Dividends paid					(1,375,760)	(1,375,760)
Stock-based compensation expense			385,838			385,838
Vesting of shares of restricted stock (in shares)	8,639
Other comprehensive (loss) income				(75,496)		(75,496)
Balance at end of period at Jun. 30, 2025	$ 116,081,031		$ 12,890,583	$ 9,907,655	$ (38,688,953)	$ 100,190,316
Balance (in shares) at Jun. 30, 2025	22,017,405

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Unaudited Condensed Consolidated Statements of Cash Flows - USD ($)	6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024
Cash flows from operating activities:
Net income	$ 5,567,495	$ 2,322,556
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion	6,677,511	4,428,829
Impairment expense	2,676,669	0
Accretion of discount on available for sale securities	0	(297,637)
(Gain) loss on derivative contracts	(1,111,693)	195,617
Settlement (paid) received on derivative contracts	(108,383)	760,542
Settlement of asset retirement obligation	(1,600)	(87,284)
Stock-based compensation expense	771,676	635,158
Deferred income tax benefit	(779,676)	(54,736)
Changes in assets and liabilities:
Accounts receivable	346,839	1,070,784
Prepaid income taxes	0	319,770
Other assets and liabilities	385,445	354,014
Accounts payable, royalties payable, gathering fees payable, and other accrued liabilities	(66,454)	(572,099)
Income taxes payable	2,572,921	0
Net cash provided by operating activities	16,930,750	9,075,514
Cash flows from investing activities:
Additions to unproved oil and gas properties	(5,132,649)	(2,993,155)
Additions to proved oil and gas properties	(5,997,993)	(26,425,017)
Additions to gathering system properties	(228,327)	(70,236)
Additions to land, buildings and property and equipment	(12,102)	(13,912)
Purchases of short term investments - available for sale	0	(4,045,785)
Proceeds from short term investments - held to maturity	0	23,116,930
Prepaid drilling costs	705,165	886,981
Net cash used in investing activities	(10,665,906)	(9,544,194)
Cash flows from financing activities:
Buyback of common shares	0	(1,203,708)
Dividends paid	(2,751,372)	(2,742,349)
Net cash used in financing activities	(2,751,372)	(3,946,057)
Effect of currency rates on cash, cash equivalents, and restricted cash	(125,612)	22,593
Decrease in cash, cash equivalents, and restricted cash	3,387,860	(4,392,144)
Cash, cash equivalents, and restricted cash, beginning of period	6,989,793	13,873,628
Cash, cash equivalents, and restricted cash, end of period	10,377,653	9,481,484
Supplemental cash flow disclosures:
Income tax paid - federal	1,325,000	140,000
Interest paid	9,552	0
Non-cash investing activities:
Change in proved properties accrued in accounts payable	(690,866)	(1,471,985)
Change in gathering system accrued in accounts payable	71,366	45,862
Asset retirement obligation asset additions and adjustments	18,235	21,831
State (PA)
Supplemental cash flow disclosures:
Income tax paid (refund)	355,138	0
State (other)
Supplemental cash flow disclosures:
Income tax paid (refund)	$ 1,710	$ (8,608)

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Description of Business

6 Months Ended

Jun. 30, 2025

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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, pursuant to the Alberta Business Corporations Act. 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, we began trading in the United States on the NASDAQ Global Market under the trading symbol “EPSN.” Epsilon is a North American on-shore focused independent natural gas and oil company engaged in the acquisition, development, gathering and production of natural gas and oil reserves.

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Basis of Preparation

6 Months Ended

Jun. 30, 2025

Accounting Policies [Abstract]

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 statement 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, 2024. 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.

Reclassification

The consolidated financial statements for the prior periods include certain reclassifications that were made to conform to the current period presentation. Such reclassifications have no impact on previously reported consolidated financial position, results of operations or cash flows.

Recently Issued Accounting Standards

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures, which requires public entities, on an annual basis, to disclose disaggregated information about a reporting entity’s effective tax rate reconciliation, using both percentages and reporting currency amounts for specific standardized categories, as well as disclosure of income taxes paid disaggregated by jurisdiction. The amendments will be effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The Company is evaluating the impact of

this new standard and believes that the adoption will result in additional disclosures, but will not have any other impact on its consolidated financial statements.

In March 2024, the FASB issued ASU No. 2024-01, Compensation – Stock Compensation (Topic 718): Scope Applications of Profits Interest and Similar Awards (“ASU 2024-01”). The amendments in ASU 2024-01 improve its overall clarity and operability without changing the guidance and adding illustrative examples to determine whether profits interest award should be accounted for in accordance with Topic 718. The Company has adopted ASU No. 2024-01 as of January 1, 2025. There was no impact as a result of the adoption of this ASU.

In November 2024, the FASB issued ASU 2024-3 "Income Statement – Reporting Comprehensive Income – Expense Disaggregation Disclosures." The ASU will improve the decision usefulness for investors by requiring public business entities to disclose more detailed information about their expenses such as (a) inventory and manufacturing expense, (b) employee compensation, (c) depreciation, (d) intangible asset amortization, etc. The amendments will be effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027, with early adoption permitted. The amendments will be applied prospectively with an option for a retrospective application. The Company is evaluating the impact of this new standard and believes that the adoption will result in additional disclosures, but will not have any other impact on its consolidated financial statements.

In July 2025, the FASB issued ASU 2025-05, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit losses for Accounts Receivable and Contract Assets. The amendments in this update provide (1) all entities with a practical expedient to assume that current conditions as of the balance sheet date do not change for the remaining life of the assets and (2) entities other than public business entities with an accounting policy election to consider collection activity after the balance sheet date when estimating expected credit losses for current accounts receivable and current contract assets arising from transactions accounted for under Topic 606. The amendments will be effective for fiscal years beginning after December 15, 2025, with early adoption permitted. The Company is evaluating the impact of this new standard and believes that the adoption may result in additional disclosures, but will not have any other impact on its consolidated financial statements.

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Cash, Cash Equivalents, and Restricted Cash

6 Months Ended

Jun. 30, 2025

Cash and Cash Equivalents [Abstract]

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, 2025 and December 31, 2024:

	June 30,		December 31,
	2025		2024
Cash and cash equivalents	$	9,907,653	$	6,519,793
Restricted cash included in other assets		470,000		470,000
Cash, cash equivalents, and restricted cash in the statement of cash flows	$	10,377,653	$	6,989,793

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Short Term Investments

6 Months Ended

Jun. 30, 2025

Investments, Debt and Equity Securities [Abstract]

Short Term Investments

4. Short Term Investments

Short term investments are highly liquid investments with original maturities between three and twelve months. The Company’s short term investments consist of US Treasury Bills. These investments are classified as available-for-sale. Available-for-sale short term investments are reported at fair value in the Consolidated Balance Sheets. Unrealized gains and losses are excluded from earnings and are reported in Accumulated other comprehensive income in the Consolidated Statements of Operations and Comprehensive Income.

As of June 30, 2025 and December 31, 2024, the Company had no short term investments.

During the six months ended June 30, 2024, the Company sold securities with a carrying amount of $14,989,595

for total proceeds of $15,336,930. The realized gains on these sales were $347,335. An additional $7,780,000 of securities reached maturity with total realized gains of $234,248. During the three months ended June 30, 2024, the Company sold securities with a carrying amount of $7,986,472 for total proceeds of $8,177,645. The realized gains on these sales were $191,173. An additional $4,145,000 of securities reached maturity with total realized gains of $99,215. The realized gains are included in other income in the consolidated Statements of Operations and Comprehensive Income.

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Property and Equipment

6 Months Ended

Jun. 30, 2025

Oil and Gas Property, Successful Effort Method, Gross [Abstract]

Property and Equipment

5.  Property and Equipment

The following table summarizes the Company’s property and equipment as of June 30, 2025 and December 31, 2024:

	June 30,		December 31,
	2025		2024
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	197,197,902	$	191,879,210
Unproved properties		33,496,835		28,364,186
Accumulated depletion, depreciation, amortization and impairment		(131,899,045)		(123,281,395)
Total oil and gas properties, net		98,795,692		96,962,001
Gathering system		43,416,065		43,116,371
Accumulated depletion, depreciation, amortization and impairment		(37,057,605)		(36,449,511)
Total gathering system, net		6,358,460		6,666,860
Land		637,764		637,764
Buildings and other property and equipment, net		245,555		259,335
Total property and equipment, net	$	106,037,471	$	104,525,960

Asset Acquisitions

During the six months ended June 30, 2025, Epsilon had no asset acquisitions.

During the six months ended June 30, 2024, Epsilon acquired assets that included the following:

● a 25% working interest in three producing wells located in Ector County, Texas.

● a 25% working interest in an additional 3,620 gross undeveloped acres in Ector County, Texas.

● a 50% working interest in 14,243 gross undeveloped acres in Alberta, Canada.

Management determined that substantially all the fair value of the assets acquired was concentrated in a group of similar identifiable assets. Based on this determination, the acquisition was accounted for as an asset acquisition.

Property Impairment

We perform a quantitative impairment test 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, basis differentials, timing, methods and other assumptions consistent with historical periods. When indicators of impairment are present, GAAP requires that the Company first compare 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 properties to their estimated fair value is required. Additionally, if an exploratory well is determined not to have found proved reserves, the costs incurred, net of any salvage value, should be charged to expense.

During the three and six months ended June 30, 2025, Epsilon recorded an impairment of $2.7 million for two wells drilled in Alberta, Canada.  The impairment was a result of a decrease in estimated reserves due to early production coming in below expectations, cost overruns and lower forward commodity prices.

During the three and six months ended June 30, 2024, no impairment was recorded. For the year ended December 31, 2024, the Company had $0.53 million of impairment reflected in proved properties on the Consolidated Balance Sheets. To be consistent with the current presentation, the prior year impairment has been reclassed to accumulated depletion, depreciation, amortization and impairment on the Consolidated Balance Sheets.

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Revolving Line of Credit

6 Months Ended

Jun. 30, 2025

Debt Disclosure [Abstract]

Revolving Line of Credit

6. Revolving Line of Credit

The Company closed a senior secured reserve based revolving credit facility on June 28, 2023, with Frost Bank as issuing bank and sole lender. The current borrowing base is $45 million (redetermined as of February 10, 2025), supported by the Company’s upstream assets in Pennsylvania and subject to semi-annual redeterminations with a maturity date of June 28, 2027. Interest will be charged at the Daily Simple SOFR rate plus a margin of 3.25%. The facility is secured by the assets of the Company’s Epsilon Energy USA subsidiary (Borrower). There are currently no borrowings under the facility.

Under the terms of the facility, the Company must adhere to the following financial covenants:

● Current ratio of 1.0 to 1.0 (current assets / current liabilities)

● Leverage ratio of less than 2.5 to 1.0 (total debt / income adjusted for interest, taxes and non-cash amounts)

Additionally, if the Leverage ratio is greater than 1.0 to 1.0, or the borrowing base utilization is greater than 50%, the Company is required to hedge 50% of the anticipated production from PDP reserves for a rolling 24-month period.

We were in compliance with the financial covenants of the agreement as of June 30, 2025.

	Balance at		Balance at
	June 30,		December 31,		Current
	2025		2024		Borrowing Base		Interest Rate
Revolving line of credit	$	—	$	—	$	45,000,000		SOFR + 3.25%

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Shareholders' Equity

6 Months Ended

Jun. 30, 2025

Equity [Abstract]

Shareholders' Equity

7. 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

On February 12, 2025, Epsilon’s board of directors (the “Board”) authorized a new share repurchase program of up to 2,200,876 common shares, representing 10% of the current outstanding common shares of Epsilon, for an aggregate purchase price of not more than US $13.0 million. The program commenced on February 12, 2025 and ends on February 11, 2026, unless the maximum amount of common shares is purchased before then or the Board approves earlier termination.

The previous share repurchase program commenced on March 19, 2024.  During the year ended December 31, 2024, we repurchased 125,000 common shares and spent $627,500 at an average price of $5.00 per share (excluding commissions) under the plan. On February 12, 2025, the Board terminated and revoked authority under the program.

During the six months ended June 30, 2025, no shares were repurchased under the new or previous program.  

(c)Equity Incentive Plan

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.

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 is authorized to issue up to 2,000,000 Common Shares.

Restricted Stock

For the six months ended June 30, 2025, no restricted common shares were awarded to the Company’s board of directors and employees. For the year ended December 31, 2024, 300,052 restricted common shares with a weighted average grant date fair value of $5.97 were awarded to the Company’s management, employees, and board of directors. These shares vest over a three-year period, with an equal number of 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, 2025, and the year ended December 31, 2024:

	Six months ended				Year ended
	June 30, 2025				December 31, 2024
	Number of	Weighted	Weighted		Number of	Weighted	Weighted
	Restricted	Average	Average		Restricted	Average	Average
	Shares	Remaining Life	Grant Date		Shares	Remaining Life	Grant Date
	Outstanding	(years)	Fair Value		Outstanding	(years)	Fair Value
Balance non-vested Restricted Stock at beginning of period	560,970	1.61	$	5.77	491,536	1.74	$	5.59
Granted	—	—		-	300,052	1.92		5.97
Vested	(8,639)	—		6.15	(230,618)	—		5.65
Balance non-vested Restricted Stock at end of period	552,331	1.11	$	5.77	560,970	1.61	$	5.77

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, 2025 was $385,838 and $771,676, respectively (for the three and six months ended June 30, 2024 was $313,589 and $ 635,158, respectively).

As of June 30, 2025, the Company had unrecognized stock-based compensation related to these shares of $2,426,793 to be recognized over a weighted average period of 1.14 years (at December 31, 2024: $3,198,469 over 1.30 years).

(d)Dividends

On February 26, 2025 and June 3, 2025, the Board declared quarterly a dividend of $0.0625 per common share (annualized $0.25 per common share) totaling in aggregate an amount of approximately $2.8 million that has been paid during the six months ended June 30, 2025.

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Revenue Recognition

6 Months Ended

Jun. 30, 2025

Revenues [Abstract]

Revenue Recognition

8. Revenue Recognition

Revenues are comprised of sales of natural gas, oil and natural gas liquids (“NGLs”), along with the revenue generated from the Company’s ownership interest in the gas gathering system in the Auburn field in Northeastern Pennsylvania.

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 points 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. Gathering System revenues derived from Epsilon’s production, which have been eliminated from total gathering system revenues (“elimination entry”), amounted to $0.5 million and $1.1 million, respectively, for the three and six months ended June 30, 2025 ($0.3 million and $0.6 million, respectively, for the three and six months ended June 30, 2024).

The following table details revenue for the three and six months ended June 30, 2025 and 2024.

	Three months ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Operating revenue
Natural gas	$	6,910,344	$	1,961,230	$	17,523,917	$	4,924,209
Natural gas liquids		145,020		388,423		532,270		761,407
Oil and condensate		2,724,364		3,513,717		5,994,331		6,228,799
Gathering and compression fees (1)		1,845,005		1,444,448		3,737,355		3,380,146
Total operating revenue	$	11,624,733	$	7,307,818	$	27,787,873	$	15,294,561

(1) Net of the elimination entry

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 and Comprehensive Income.

Settlement statements for product sales, and the related cash consideration, are generally 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 in Pennsylvania. 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 GGS 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.

Current Expected Credit Losses

Under ASU 326, Financial Instruments – Credit Losses, estimated losses on financial assets are provided through an allowance for credit losses. The majority of our financial assets are held in cash and cash equivalents and accounts receivable. The accounts receivable are primarily from purchasers of oil and natural gas, counterparties to our financial instruments, and revenues earned for compression and gathering services. Our oil, gas, and natural gas liquids accounts receivable are generally collected within 30 days after the end of the month. Compression and gathering receivables are generally collected within 60 days after the end of the month. We assess collectability through various procedures,

including review of our trade receivable balances by counterparty, assessing economic events and conditions, our historical experience with counterparties, the counterparty’s financial condition and the amount and age of past due accounts. As of June 30, 2025 and December 31, 2024, we determined that our allowance for credit loss was nil.

	June 30,		December 31,		December 31,
	2025		2024		2023
Accounts receivable
Natural gas and oil sales	$	3,946,643	$	4,888,294	$	4,327,886
Joint interest billing		—		—		17,476
Gathering and compression fees		1,434,591		918,471		1,543,239
Commodity contract		115,649		36,957		72,075
Interest		—		—		54,772
Total accounts receivable	$	5,496,883	$	5,843,722	$	6,015,448

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Accumulated Other Comprehensive Income

6 Months Ended

Jun. 30, 2025

Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]

Accumulated Other Comprehensive Income

9. Accumulated Other Comprehensive Income

Accumulated other comprehensive income includes certain transactions that have generally been reported in the Consolidated Statements of Changes in Shareholders’ Equity. The activity in accumulated other comprehensive income during the three and six months ended June 30, 2025 and 2024 consisted of the following:

	Three months ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Balance at beginning of period	$	9,983,151	$	9,768,032	$	10,033,267	$	9,772,277
Translation (loss)/gain		(75,496)		22,229		(125,612)		22,593
Unrealized gain/(loss) on securities		—		3,011		—		(1,598)
Balance at end of period	$	9,907,655	$	9,793,272	$	9,907,655	$	9,793,272

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Income Taxes

6 Months Ended

Jun. 30, 2025

Income Tax Disclosure [Abstract]

Income Taxes

10. Income Taxes

Income tax provisions for the three and six months ended June 30, 2025 and 2024 are as follows:

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Current:
Federal	$	1,794,581	$	401,042	$	3,358,642	$	467,310
State		501,330		89,717		928,915		100,492
Total current income tax expense		2,295,911		490,759		4,287,557		567,802
Deferred:
Federal		(413,762)		(23,214)		(704,026)		354,385
State		(44,462)		(8,529)		(75,650)		(409,121)
Total deferred tax expense		(458,224)		(31,743)		(779,676)		(54,736)
Income tax expense	$	1,837,687	$	459,016	$	3,507,881	$	513,066

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, 2021 through December 31, 2024. To the extent we utilize net operating losses generated in earlier years, such earlier years may also be subject to audit.

Starting in 2023, distributions of Epsilon Energy USA Inc. earnings to Epsilon Energy Ltd. incur a 5% U.S. dividend withholding tax, provided the Company is eligible for benefits under the U.S. / Canada income treaty.

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, 2025 was higher than the statutory federal rate as a result of state income taxes partially offset by the valuation allowance against the Canadian net operating loss.

On July 4, 2025, Public Law No. 119-21, commonly referred to as the One Big Beautiful Bill Act (the “Act”), was enacted by the U.S. government. While the enactment of the Act does not have an impact on the historical financial data, the Company’s future tax liabilities may be impacted. Among other changes, the Act: (i) allows for 100% expensing of the costs of certain qualified property acquired after January 19, 2025; (ii) allows election to immediately deduct R&D costs incurred; and (iii) modifies the provision related to the limitations on deduction of interest expense.

The Company expects to realize net benefits from U.S. tax reform, primarily driven by the accelerated depreciation of qualified assets for tax purposes. However, the Company continues to evaluate the impacts of the Act and further understand its implications, as well as the related, and yet to be issued, regulations and interpretations which could impact this outlook.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2025

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

11. Commitments and Contingencies

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of June 30, 2025, the Company had commitments of $1.9 million for capital expenditures.

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Leases

6 Months Ended

Jun. 30, 2025

Leases [Abstract]

Leases

12. Leases

Under ASC 842, Leases, the Company recognized an operating lease related to its corporate office as of June 30, 2025 and December 31, 2024 as summarized in the following table:

	June 30,		December 31,
	2025		2024
Asset
Operating lease right-of-use assets, long term	$	295,317	$	344,589
Total operating lease right-of-use assets	$	295,317	$	344,589
Liabilities
Operating lease liabilities	$	121,057	$	121,135
Operating lease liabilities, long term		296,250		355,776
Total operating lease liabilities	$	417,307	$	476,911
Operating lease costs	$	120,926	$	236,044
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	152,709	$	214,230
Weighted average remaining lease term (years) - operating lease		2.29		2.50
Weighted average discount rate (annualized) - operating lease		8.25%		8.25%

On March 1, 2023, the Company commenced a new office lease with a 70 month lease term and future lease payments estimated to be approximately $0.85 million. There are no other pending leases, and no lease arrangements in which the Company is the lessor.

Lease expense for operating leases was $0.12 million and $0.24 million for the six months ended June 30, 2025 and

the year ended December 31, 2024, respectively. This lease expense is presented in other general and administrative expenses in the Consolidated Statements of Operations and Comprehensive Income.

Future minimum lease payments as of June 30, 2025 are as follows:

	Operating Leases
2025	$	86,775
2026		177,021
2027		180,492
2028		183,963
Total minimum lease payments		628,251
Less: imputed interest		(210,944)
Present value of future minimum lease payments		417,307
Less: current obligations under leases		(121,057)
Long-term lease obligations	$	296,250

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Net Income Per Share

6 Months Ended

Jun. 30, 2025

Earnings Per Share [Abstract]

Net Income Per Share

13.    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,
	2025		2024		2025		2024
Net income	$	1,551,461	$	815,660	$	5,567,495	$	2,322,556

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,
	2025	2024	2025	2024
Basic weighted-average number of shares outstanding	22,017,310	21,921,752	22,013,062	21,957,980
Unvested time-based restricted shares	185,005	107,723	142,567	29,162
Diluted weighted-average shares outstanding	22,202,315	22,029,475	22,155,629	21,987,142

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,
	2025	2024	2025	2024
Anti-dilutive unvested time-based restricted shares	367,421	492,463	411,203	512,389

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Operating Segments

6 Months Ended

Jun. 30, 2025

Segment Reporting [Abstract]

Operating Segments

14. Operating Segments

Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision-maker (CODM). The CODM, who is responsible for allocating resources and assessing performance of the operating segments, has been identified as executive management consisting of the Chief Executive Officer, Chief Financial Officer, and Chief Operating Officer. The CODM uses the Company’s consolidated financial results, including operating income or loss by segment, to make key operating decisions, assess performance, and to allocate resources.

Segment performance is evaluated based on operating income or loss as shown in the table below. Interest income 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 natural gas and oil reserves on properties within the United States and Canada; and

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

Segment activity for the six months ended June 30, 2025 and 2024 is as follows:

	Upstream		Gas Gathering		Consolidated
As of and for the six months ended June 30, 2025
Operating revenue
Natural gas	$	17,523,917	$	—	$	17,523,917
Natural gas liquids		532,270		—		532,270
Oil and condensate		5,994,331		—		5,994,331
Gathering and compression fees		—		3,737,355		3,737,355
Intersegment gathering and compression fees		—		1,064,223		1,064,223
		24,050,518		4,801,578		28,852,096
Reconciliation of operating revenue
Elimination of intersegment revenues						(1,064,223)
Total consolidated operating revenue(1)						27,787,873
Operating costs
Gathering, transportation, and compression		3,978,175		—		3,978,175
Other lease operating expense		1,240,508		—		1,240,508
Gathering system operating expenses		—		1,166,446		1,166,446
Intersegment other lease operating expense		1,064,223		—		1,064,223
Impairment		2,676,669		—		2,676,669
Depletion, depreciation, amortization and accretion		6,065,544		611,967		6,677,511
Segment operating income	$	9,025,399	$	3,023,165	$	10,984,341
Reconciliation of segment operating income
Salary expense						1,789,792
Stock based compensation						771,676
Other general and administrative						1,490,504
Elimination of intersegment other lease operating expenses						(1,064,223)
Total consolidated operating income						7,996,592
Other income (expense)
Interest income						32,546
Interest expense						(32,117)
Loss on derivative contracts						1,111,693
Other expense						(33,338)
Other expense, net						1,078,784
Net income before income tax expense					$	9,075,376
Capital expenditures (2)	$	11,142,744	$	228,327	$	11,371,071
Segment assets	$	99,073,244	$	6,358,460	$	105,431,704
Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	105,431,704
Current assets, net						16,533,328
Other property and equipment						883,319
Operating lease right-of-use asset						295,317
Restricted cash						470,000
					$	123,613,668

	Upstream		Gas Gathering		Consolidated
As of and for the six months ended June 30, 2024
Operating revenue
Natural gas	$	4,924,209	$	—	$	4,924,209
Natural gas liquids		761,407		—		761,407
Oil and condensate		6,228,799		—		6,228,799
Gathering and compression fees		—		3,380,146		3,380,146
Intersegment gathering and compression fees		—		591,907		591,907
		11,914,415		3,972,053		15,886,468
Reconciliation of operating revenue
Elimination of intersegment revenues						(591,907)
Total consolidated operating revenue(1)						15,294,561
Operating costs
Gathering, transportation, and compression		2,602,378		—		2,602,378
Other lease operating expense		815,951		—		815,951
Gathering system operating expenses		—		1,202,537		1,202,537
Intersegment other lease operating expense		591,907		—		591,907
Depletion, depreciation, amortization and accretion		4,007,320		421,509		4,428,829
Segment operating income	$	3,896,859	$	2,348,007	$	5,652,959
Reconciliation of segment operating income
Salary expense						1,461,549
Stock based compensation						635,158
Other general and administrative						1,575,689
Elimination of intersegment other lease operating expenses						(591,907)
Total consolidated operating income						2,572,470
Other income (expense)
Interest income						375,215
Interest expense						(17,519)
Gain on derivative contracts						(195,617)
Other expense						101,073
Other income, net						263,152
Net income before income tax expense					$	2,835,622
Capital expenditures (2)	$	29,432,084	$	70,236	$	29,502,320
Segment assets	$	97,059,040	$	6,896,509	$	103,955,549
Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	103,955,549
Current assets, net						14,977,407
Other property and equipment						919,208
Operating lease right-of-use asset						392,792
Restricted cash						900,000
					$	121,144,956

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the six months ended June 30, 2025 and 2024 have been eliminated upon consolidation. For the six months ended June 30, 2025, Epsilon sold natural gas to 34 unique customers. The one customer over 10% comprised 34% of total revenue. For the six months ended June 30, 2024, Epsilon sold natural gas to 29 unique customers. The three customers over 10% comprised 14%, 11%, 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, completion, and maintenance of the gathering and compression facility.

Segment activity for the three months ended June 30, 2025 and 2024 is as follows:

	Upstream		Gas Gathering		Consolidated
As of and for the three months ended June 30, 2025
Operating revenue
Natural gas	$	6,910,344	$	—	$	6,910,344
Natural gas liquids		145,020		—		145,020
Oil and condensate		2,724,364		—		2,724,364
Gathering and compression fees		—		1,845,005		1,845,005
Intersegment gathering and compression fees		—		507,365		507,365
		9,779,728		2,352,370		12,132,098
Reconciliation of operating revenue
Elimination of intersegment revenues						(507,365)
Total consolidated operating revenue(1)						11,624,733
Operating costs
Gathering, transportation, and compression		1,924,460		—		1,924,460
Other lease operating expense		538,325		—		538,325
Gathering system operating expenses		—		613,795		613,795
Intersegment other lease operating expense		507,365		—		507,365
Impairment		2,670,000		—		2,670,000
Depletion, depreciation, amortization and accretion		2,919,238		282,416		3,201,654
Segment operating income	$	1,220,340	$	1,456,159	$	2,169,134
Reconciliation of segment operating income
Salary expense						710,122
Stock based compensation						385,838
Other general and administrative						751,756
Elimination of intersegment other lease operating expenses						(507,365)
Total consolidated operating income						828,783
Other income (expense)
Interest income						17,247
Interest expense						(19,906)
Gain on derivative contracts						2,573,863
Other expense						(10,839)
Other expense, net						2,560,365
Net income before income tax expense					$	3,389,148
Capital expenditures (2)	$	3,502,977	$	124,052	$	3,627,029

	Upstream		Gas Gathering		Consolidated
As of and for the three months ended June 30, 2024
Operating revenue
Natural gas	$	1,961,230	$	—	$	1,961,230
Natural gas liquids		388,423		—		388,423
Oil and condensate		3,513,717		—		3,513,717
Gathering and compression fees		—		1,444,448		1,444,448
Intersegment gathering and compression fees		—		277,509		277,509
		5,863,370		1,721,957		7,585,327
Reconciliation of operating revenue
Elimination of intersegment revenues						(277,509)
Total consolidated operating revenue(1)						7,307,818
Operating costs
Gathering, transportation, and compression		1,231,981		—		1,231,981
Other lease operating expense		417,886		—		417,886
Gathering system operating expenses		—		649,967		649,967
Intersegment other lease operating expense		277,509		—		277,509
Depletion, depreciation, amortization and accretion		1,877,611		170,792		2,048,403
Segment operating income	$	2,058,383	$	901,198	$	2,682,072
Reconciliation of segment operating income
Salary expense						15,838
Stock based compensation						313,589
Other general and administrative						1,462,377
Elimination of intersegment other lease operating expenses						(277,509)
Total consolidated operating income						1,167,777
Other income (expense)
Interest income						108,943
Interest expense						(8,759)
Gain on derivative contracts						(94,891)
Other expense						101,606
Other income, net						106,899
Net income before income tax expense					$	1,274,676
Capital expenditures (2)	$	9,109,756	$	47,586	$	9,157,342

(3) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended June 30, 2025 and 2024 have been eliminated upon consolidation. For the three months ended June 30, 2025, Epsilon sold natural gas to 31 unique customers. The two customers over 10% comprised 44% and 14% of total revenue. For the three months ended June 30, 2024, Epsilon sold natural gas to 26 unique customers. The three customers over 10% comprised 20%, 15% and 14% of total revenue.

(4) 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, completion, and maintenance of the gathering and compression facility.

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Commodity Risk Management Activities

6 Months Ended

Jun. 30, 2025

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Commodity Risk Management Activities

15. 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 and oil by securing derivative contracts for a portion of expected sales volumes.

Inherent in the Company’s fixed price contracts, are certain business risks, including market risk and credit risk. Market risk is the risk that the price of oil and natural gas 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. The Company does not currently require collateral from any of its counterparties nor do its counterparties currently require collateral from the Company.

The Company enters into certain commodity derivative instruments to mitigate commodity price risk associated with a portion of its future natural gas and oil production and related cash flows. The natural gas and oil 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 and oil 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 on derivative contracts on the condensed Consolidated Statements of Operations and Comprehensive Income. The related cash flow impact is reflected in cash flows from operating activities. During the three and six months ended June 30, 2025, Epsilon recognized gains on commodity derivative contracts of $2,573,863 and $1,111,693, respectively. These amounts included cash received of $306,660 and cash paid of $108,383 on settlements on these contracts, respectively. For the three and six months ended June 30, 2024, Epsilon recognized losses on commodity derivative contracts of $94,891 and $195,617, respectively. These amounts included cash received on settlements on these contracts of $272,257 and $760,542, respectively.

Commodity Derivative Contracts

At June 30, 2025, the Company had outstanding natural gas NYMEX Henry Hub (“HH”) swaps totaling 2.67 Bcf, natural gas Tennessee Z4 basis swaps totaling 0.78 Bcf, natural gas NYMEX HH options totaling 0.93 Bcf, and crude oil NYMEX WTI CMA swaps totaling 40 MBbls.

	Fair Value of Derivative  Assets
	June 30,		December 31,
	2025		2024
Current
Henry Hub Nymex Swap	$	322,385	$	151,274
Tennessee Z4 Basis swap		351,769		195,211
Henry Hub Nymex Option - Put		181,254		—
Crude Oil NYMEX WTI CMA		263,462		56,547
Long-term
Henry Hub Nymex Swap		7,225		—
Henry Hub Nymex Option - Put		222,199		—
	$	1,348,294	$	403,032

	Fair Value of Derivative  Liabilities
	June 30,		December 31,
	2025		2024
Current
Henry Hub Nymex Swap	$	(264,965)	$	(448,852)
Tennessee Z4 Basis swap		—		(441,728)
Henry Hub Nymex Option - Call		(105,437)		—
Long-term
Henry Hub Nymex Swap		(51,406)		—
Henry Hub Nymex Option - Call		(193,958)		—
	$	(615,766)	$	(890,580)
Net Fair Value of Derivatives	$	732,528	$	(487,548)

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,
	2025		2024		2025		2024
Fair value of (liability) asset, beginning of the period	$	(1,534,675)	$	511,244	$	(487,548)	$	1,100,255
Gain/(loss) on derivative contracts included in earnings		2,573,863		(94,891)		1,111,693		(195,617)
Settlement of commodity derivative contracts		(306,660)		(272,257)		108,383		(760,542)
Fair value of asset, end of the period	$	732,528	$	144,096	$	732,528	$	144,096

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Asset Retirement Obligations

6 Months Ended

Jun. 30, 2025

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

16. Asset Retirement Obligations

Asset retirement obligations are 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, and the forecast risk free cost of capital. Each year we review, and to the extent necessary, revise our asset retirement obligations estimates in accordance with recent activity and current service costs.

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

	Six Months Ended		Year ended
		June 30,		December 31,
	2025		2024
Balance beginning of period	$	3,652,296	$	3,502,952
Liabilities acquired		18,235		48,207
Wells plugged and abandoned		(1,600)		(88,992)
Change in estimates		—		6,695
Accretion		95,885		183,434
Balance end of period	$	3,764,816	$	3,652,296

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Fair Value Measurements

6 Months Ended

Jun. 30, 2025

Fair Value Disclosures [Abstract]

Fair Value Measurements

17. Fair Value Measurements

The methodologies used to determine the fair value of our financial assets and liabilities at June 30, 2025 were the same as those used at December 31, 2024.

Cash and cash equivalents, restricted cash, accounts receivable, and accounts payable 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. The revolving line of credit is classified within Level 2 of the fair value hierarchy.

Commodity derivative instruments consist of NYMEX HH swap, NYMEX HH option, and Tennessee Z4 basis swap contracts for natural gas, and NYMEX WTI CMA swap contracts for crude oil. 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.

	June 30, 2025
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	1,348,294	$	—	$	(615,766)	$	732,528
Cash equivalents	$	261,512	$	—	$	—	$	—	$	261,512
Liabilities
Derivative contracts	$	—	$	615,766	$	—	$	(615,766)	$	—

	December 31, 2024
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	403,032	$	—	$	(403,032)	$	—
Cash equivalents	$	298,767	$	—	$	—	$	—	$	298,767
Liabilities
Derivative contracts	$	—	$	890,580	$	—	$	(403,032)	$	487,548

Non-Recurring Fair Value Measurements

The Company performed an impairment test on our oil and gas properties and it was determined that the carrying amount of the Canada asset exceeded the estimated undiscounted future cash flows resulting in a reduction of the carrying amount of the properties to their estimated fair values by $2.7 million. This nonrecurring fair value measurement is classified within Level 3 of the fair value hierarchy. For the year ended December 31, 2024, there was an impairment of $1.45 million.

The table below summarizes the fair value of the impaired assets at June 30, 2025.

			Quoted Prices		Significant
			in Active		Other		Significant
			Markets for		Observable		Unobservable
	June 30,		Identical Assets		Inputs		Inputs
	2025		(Level 1)		(Level 2)		(Level 3)
Nonrecurring fair value measurement
Long-lived assets held and used	$	1,342,942	$	—	$	—	$	1,342,942
Total Nonrecurring fair value measurement	$	1,342,942	$	—	$	—	$	1,342,942

The table below summarizes the fair value of the impaired assets at December 31, 2024.

			Quoted Prices		Significant
			in Active		Other		Significant
			Markets for		Observable		Unobservable
	December 31,		Identical Assets		Inputs		Inputs
	2024		(Level 1)		(Level 2)		(Level 3)
Nonrecurring fair value measurement
Long-lived assets held and used	$	492,253	$	—	$	—	$	492,253
Total Nonrecurring fair value measurement	$	492,253	$	—	$	—	$	492,253

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Subsequent Events

6 Months Ended

Jun. 30, 2025

Subsequent Events [Abstract]

Subsequent Events

18. Subsequent Events

On August 11, 2025, Epsilon signed definitive agreements to acquire two entities, Peak Exploration and Production LLC and Peak BLM Lease LLC (together, “Peak”). Consideration at closing is proposed as the issuance of 6 million Epsilon common shares and the assumption of approximately $49 million in debt. Additional consideration is proposed as the issuance of 1.5 - 2.5 million Epsilon common shares are contingent on the receipt of drilling permits on, and the ability to access, leasehold currently affected by a drilling moratorium in Converse County, Wyoming.  If the conditions are not met by year-end 2027, Epsilon has a $6.5 million cash option to retain the affected undeveloped leasehold.

The acquired assets include an operated position of 40,500 net acres producing 2.2 MBoepd in the Powder River Basin in Campbell and Converse County, Wyoming.

The transaction is subject to a shareholder vote; the associated proxy process will run in the interim period between signing and closing. If approved, the transaction is expected to close in the fourth quarter of 2025.

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Pay vs Performance Disclosure - USD ($)	3 Months Ended
	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2024	Mar. 31, 2024
Pay vs Performance Disclosure
Net Income (Loss)	$ 1,551,461	$ 4,016,034	$ 815,660	$ 1,506,896

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Insider Trading Arrangements	3 Months Ended
	Jun. 30, 2025
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Basis of Preparation (Policies)

6 Months Ended

Jun. 30, 2025

Accounting Policies [Abstract]

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 statement 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, 2024. 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.

Reclassification

Reclassification

The consolidated financial statements for the prior periods include certain reclassifications that were made to conform to the current period presentation. Such reclassifications have no impact on previously reported consolidated financial position, results of operations or cash flows.

Recently Issued Accounting Standards

Recently Issued Accounting Standards

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures, which requires public entities, on an annual basis, to disclose disaggregated information about a reporting entity’s effective tax rate reconciliation, using both percentages and reporting currency amounts for specific standardized categories, as well as disclosure of income taxes paid disaggregated by jurisdiction. The amendments will be effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The Company is evaluating the impact of

this new standard and believes that the adoption will result in additional disclosures, but will not have any other impact on its consolidated financial statements.

In March 2024, the FASB issued ASU No. 2024-01, Compensation – Stock Compensation (Topic 718): Scope Applications of Profits Interest and Similar Awards (“ASU 2024-01”). The amendments in ASU 2024-01 improve its overall clarity and operability without changing the guidance and adding illustrative examples to determine whether profits interest award should be accounted for in accordance with Topic 718. The Company has adopted ASU No. 2024-01 as of January 1, 2025. There was no impact as a result of the adoption of this ASU.

In November 2024, the FASB issued ASU 2024-3 "Income Statement – Reporting Comprehensive Income – Expense Disaggregation Disclosures." The ASU will improve the decision usefulness for investors by requiring public business entities to disclose more detailed information about their expenses such as (a) inventory and manufacturing expense, (b) employee compensation, (c) depreciation, (d) intangible asset amortization, etc. The amendments will be effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027, with early adoption permitted. The amendments will be applied prospectively with an option for a retrospective application. The Company is evaluating the impact of this new standard and believes that the adoption will result in additional disclosures, but will not have any other impact on its consolidated financial statements.

In July 2025, the FASB issued ASU 2025-05, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit losses for Accounts Receivable and Contract Assets. The amendments in this update provide (1) all entities with a practical expedient to assume that current conditions as of the balance sheet date do not change for the remaining life of the assets and (2) entities other than public business entities with an accounting policy election to consider collection activity after the balance sheet date when estimating expected credit losses for current accounts receivable and current contract assets arising from transactions accounted for under Topic 606. The amendments will be effective for fiscal years beginning after December 15, 2025, with early adoption permitted. The Company is evaluating the impact of this new standard and believes that the adoption may result in additional disclosures, but will not have any other impact on its consolidated financial statements.

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Cash, Cash Equivalents, and Restricted Cash (Tables)

6 Months Ended

Jun. 30, 2025

Accounting Policies [Abstract]

Schedule of cash, cash equivalents and restricted cash

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, 2025 and December 31, 2024:

	June 30,		December 31,
	2025		2024
Cash and cash equivalents	$	9,907,653	$	6,519,793
Restricted cash included in other assets		470,000		470,000
Cash, cash equivalents, and restricted cash in the statement of cash flows	$	10,377,653	$	6,989,793

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Property and Equipment (Tables)

6 Months Ended

Jun. 30, 2025

Oil and Gas Property, Successful Effort Method, Gross [Abstract]

Schedule of property and equipment

The following table summarizes the Company’s property and equipment as of June 30, 2025 and December 31, 2024:

	June 30,		December 31,
	2025		2024
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	197,197,902	$	191,879,210
Unproved properties		33,496,835		28,364,186
Accumulated depletion, depreciation, amortization and impairment		(131,899,045)		(123,281,395)
Total oil and gas properties, net		98,795,692		96,962,001
Gathering system		43,416,065		43,116,371
Accumulated depletion, depreciation, amortization and impairment		(37,057,605)		(36,449,511)
Total gathering system, net		6,358,460		6,666,860
Land		637,764		637,764
Buildings and other property and equipment, net		245,555		259,335
Total property and equipment, net	$	106,037,471	$	104,525,960

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Revolving Line of Credit (Tables)

6 Months Ended

Jun. 30, 2025

Debt Disclosure [Abstract]

Schedule of revolving line of credit

	Balance at		Balance at
	June 30,		December 31,		Current
	2025		2024		Borrowing Base		Interest Rate
Revolving line of credit	$	—	$	—	$	45,000,000		SOFR + 3.25%

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Shareholders' Equity (Tables)

6 Months Ended

Jun. 30, 2025

Equity [Abstract]

Schedule of restricted stock activity

The following table summarizes restricted stock activity for the six months ended June 30, 2025, and the year ended December 31, 2024:

	Six months ended				Year ended
	June 30, 2025				December 31, 2024
	Number of	Weighted	Weighted		Number of	Weighted	Weighted
	Restricted	Average	Average		Restricted	Average	Average
	Shares	Remaining Life	Grant Date		Shares	Remaining Life	Grant Date
	Outstanding	(years)	Fair Value		Outstanding	(years)	Fair Value
Balance non-vested Restricted Stock at beginning of period	560,970	1.61	$	5.77	491,536	1.74	$	5.59
Granted	—	—		-	300,052	1.92		5.97
Vested	(8,639)	—		6.15	(230,618)	—		5.65
Balance non-vested Restricted Stock at end of period	552,331	1.11	$	5.77	560,970	1.61	$	5.77

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Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2025

Revenues [Abstract]

Summary of revenue

The following table details revenue for the three and six months ended June 30, 2025 and 2024.

	Three months ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Operating revenue
Natural gas	$	6,910,344	$	1,961,230	$	17,523,917	$	4,924,209
Natural gas liquids		145,020		388,423		532,270		761,407
Oil and condensate		2,724,364		3,513,717		5,994,331		6,228,799
Gathering and compression fees (1)		1,845,005		1,444,448		3,737,355		3,380,146
Total operating revenue	$	11,624,733	$	7,307,818	$	27,787,873	$	15,294,561

(1) Net of the elimination entry

Schedule of accounts receivable net of allowance for doubtful accounts

	June 30,		December 31,		December 31,
	2025		2024		2023
Accounts receivable
Natural gas and oil sales	$	3,946,643	$	4,888,294	$	4,327,886
Joint interest billing		—		—		17,476
Gathering and compression fees		1,434,591		918,471		1,543,239
Commodity contract		115,649		36,957		72,075
Interest		—		—		54,772
Total accounts receivable	$	5,496,883	$	5,843,722	$	6,015,448

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Accumulated Other Comprehensive Income (Tables)

6 Months Ended

Jun. 30, 2025

Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]

Schedule of Accumulated Other Comprehensive Income

	Three months ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
Balance at beginning of period	$	9,983,151	$	9,768,032	$	10,033,267	$	9,772,277
Translation (loss)/gain		(75,496)		22,229		(125,612)		22,593
Unrealized gain/(loss) on securities		—		3,011		—		(1,598)
Balance at end of period	$	9,907,655	$	9,793,272	$	9,907,655	$	9,793,272

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2025

Income Tax Disclosure [Abstract]

Schedule of current and deferred tax expense (benefit)

Income tax provisions for the three and six months ended June 30, 2025 and 2024 are as follows:

	Three months ended June 30,				Six months ended June 30,
	2025		2024		2025		2024
Current:
Federal	$	1,794,581	$	401,042	$	3,358,642	$	467,310
State		501,330		89,717		928,915		100,492
Total current income tax expense		2,295,911		490,759		4,287,557		567,802
Deferred:
Federal		(413,762)		(23,214)		(704,026)		354,385
State		(44,462)		(8,529)		(75,650)		(409,121)
Total deferred tax expense		(458,224)		(31,743)		(779,676)		(54,736)
Income tax expense	$	1,837,687	$	459,016	$	3,507,881	$	513,066

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Leases (Tables)

6 Months Ended

Jun. 30, 2025

Leases [Abstract]

Schedule of operating lease

Under ASC 842, Leases, the Company recognized an operating lease related to its corporate office as of June 30, 2025 and December 31, 2024 as summarized in the following table:

	June 30,		December 31,
	2025		2024
Asset
Operating lease right-of-use assets, long term	$	295,317	$	344,589
Total operating lease right-of-use assets	$	295,317	$	344,589
Liabilities
Operating lease liabilities	$	121,057	$	121,135
Operating lease liabilities, long term		296,250		355,776
Total operating lease liabilities	$	417,307	$	476,911
Operating lease costs	$	120,926	$	236,044
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	152,709	$	214,230
Weighted average remaining lease term (years) - operating lease		2.29		2.50
Weighted average discount rate (annualized) - operating lease		8.25%		8.25%

Schedule of maturity analysis of operating lease liability

Future minimum lease payments as of June 30, 2025 are as follows:

	Operating Leases
2025	$	86,775
2026		177,021
2027		180,492
2028		183,963
Total minimum lease payments		628,251
Less: imputed interest		(210,944)
Present value of future minimum lease payments		417,307
Less: current obligations under leases		(121,057)
Long-term lease obligations	$	296,250

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Net Income Per Share (Tables)

6 Months Ended

Jun. 30, 2025

Earnings Per Share [Abstract]

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

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,
	2025		2024		2025		2024
Net income	$	1,551,461	$	815,660	$	5,567,495	$	2,322,556

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

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,
	2025	2024	2025	2024
Basic weighted-average number of shares outstanding	22,017,310	21,921,752	22,013,062	21,957,980
Unvested time-based restricted shares	185,005	107,723	142,567	29,162
Diluted weighted-average shares outstanding	22,202,315	22,029,475	22,155,629	21,987,142

Schedule of anti-dilutive shares

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,
	2025	2024	2025	2024
Anti-dilutive unvested time-based restricted shares	367,421	492,463	411,203	512,389

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Operating Segments (Tables)

6 Months Ended

Jun. 30, 2025

Segment Reporting [Abstract]

Schedule of segment financial information

Segment activity for the six months ended June 30, 2025 and 2024 is as follows:

	Upstream		Gas Gathering		Consolidated
As of and for the six months ended June 30, 2025
Operating revenue
Natural gas	$	17,523,917	$	—	$	17,523,917
Natural gas liquids		532,270		—		532,270
Oil and condensate		5,994,331		—		5,994,331
Gathering and compression fees		—		3,737,355		3,737,355
Intersegment gathering and compression fees		—		1,064,223		1,064,223
		24,050,518		4,801,578		28,852,096
Reconciliation of operating revenue
Elimination of intersegment revenues						(1,064,223)
Total consolidated operating revenue(1)						27,787,873
Operating costs
Gathering, transportation, and compression		3,978,175		—		3,978,175
Other lease operating expense		1,240,508		—		1,240,508
Gathering system operating expenses		—		1,166,446		1,166,446
Intersegment other lease operating expense		1,064,223		—		1,064,223
Impairment		2,676,669		—		2,676,669
Depletion, depreciation, amortization and accretion		6,065,544		611,967		6,677,511
Segment operating income	$	9,025,399	$	3,023,165	$	10,984,341
Reconciliation of segment operating income
Salary expense						1,789,792
Stock based compensation						771,676
Other general and administrative						1,490,504
Elimination of intersegment other lease operating expenses						(1,064,223)
Total consolidated operating income						7,996,592
Other income (expense)
Interest income						32,546
Interest expense						(32,117)
Loss on derivative contracts						1,111,693
Other expense						(33,338)
Other expense, net						1,078,784
Net income before income tax expense					$	9,075,376
Capital expenditures (2)	$	11,142,744	$	228,327	$	11,371,071
Segment assets	$	99,073,244	$	6,358,460	$	105,431,704
Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	105,431,704
Current assets, net						16,533,328
Other property and equipment						883,319
Operating lease right-of-use asset						295,317
Restricted cash						470,000
					$	123,613,668

	Upstream		Gas Gathering		Consolidated
As of and for the six months ended June 30, 2024
Operating revenue
Natural gas	$	4,924,209	$	—	$	4,924,209
Natural gas liquids		761,407		—		761,407
Oil and condensate		6,228,799		—		6,228,799
Gathering and compression fees		—		3,380,146		3,380,146
Intersegment gathering and compression fees		—		591,907		591,907
		11,914,415		3,972,053		15,886,468
Reconciliation of operating revenue
Elimination of intersegment revenues						(591,907)
Total consolidated operating revenue(1)						15,294,561
Operating costs
Gathering, transportation, and compression		2,602,378		—		2,602,378
Other lease operating expense		815,951		—		815,951
Gathering system operating expenses		—		1,202,537		1,202,537
Intersegment other lease operating expense		591,907		—		591,907
Depletion, depreciation, amortization and accretion		4,007,320		421,509		4,428,829
Segment operating income	$	3,896,859	$	2,348,007	$	5,652,959
Reconciliation of segment operating income
Salary expense						1,461,549
Stock based compensation						635,158
Other general and administrative						1,575,689
Elimination of intersegment other lease operating expenses						(591,907)
Total consolidated operating income						2,572,470
Other income (expense)
Interest income						375,215
Interest expense						(17,519)
Gain on derivative contracts						(195,617)
Other expense						101,073
Other income, net						263,152
Net income before income tax expense					$	2,835,622
Capital expenditures (2)	$	29,432,084	$	70,236	$	29,502,320
Segment assets	$	97,059,040	$	6,896,509	$	103,955,549
Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	103,955,549
Current assets, net						14,977,407
Other property and equipment						919,208
Operating lease right-of-use asset						392,792
Restricted cash						900,000
					$	121,144,956

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the six months ended June 30, 2025 and 2024 have been eliminated upon consolidation. For the six months ended June 30, 2025, Epsilon sold natural gas to 34 unique customers. The one customer over 10% comprised 34% of total revenue. For the six months ended June 30, 2024, Epsilon sold natural gas to 29 unique customers. The three customers over 10% comprised 14%, 11%, 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, completion, and maintenance of the gathering and compression facility.

Segment activity for the three months ended June 30, 2025 and 2024 is as follows:

	Upstream		Gas Gathering		Consolidated
As of and for the three months ended June 30, 2025
Operating revenue
Natural gas	$	6,910,344	$	—	$	6,910,344
Natural gas liquids		145,020		—		145,020
Oil and condensate		2,724,364		—		2,724,364
Gathering and compression fees		—		1,845,005		1,845,005
Intersegment gathering and compression fees		—		507,365		507,365
		9,779,728		2,352,370		12,132,098
Reconciliation of operating revenue
Elimination of intersegment revenues						(507,365)
Total consolidated operating revenue(1)						11,624,733
Operating costs
Gathering, transportation, and compression		1,924,460		—		1,924,460
Other lease operating expense		538,325		—		538,325
Gathering system operating expenses		—		613,795		613,795
Intersegment other lease operating expense		507,365		—		507,365
Impairment		2,670,000		—		2,670,000
Depletion, depreciation, amortization and accretion		2,919,238		282,416		3,201,654
Segment operating income	$	1,220,340	$	1,456,159	$	2,169,134
Reconciliation of segment operating income
Salary expense						710,122
Stock based compensation						385,838
Other general and administrative						751,756
Elimination of intersegment other lease operating expenses						(507,365)
Total consolidated operating income						828,783
Other income (expense)
Interest income						17,247
Interest expense						(19,906)
Gain on derivative contracts						2,573,863
Other expense						(10,839)
Other expense, net						2,560,365
Net income before income tax expense					$	3,389,148
Capital expenditures (2)	$	3,502,977	$	124,052	$	3,627,029

	Upstream		Gas Gathering		Consolidated
As of and for the three months ended June 30, 2024
Operating revenue
Natural gas	$	1,961,230	$	—	$	1,961,230
Natural gas liquids		388,423		—		388,423
Oil and condensate		3,513,717		—		3,513,717
Gathering and compression fees		—		1,444,448		1,444,448
Intersegment gathering and compression fees		—		277,509		277,509
		5,863,370		1,721,957		7,585,327
Reconciliation of operating revenue
Elimination of intersegment revenues						(277,509)
Total consolidated operating revenue(1)						7,307,818
Operating costs
Gathering, transportation, and compression		1,231,981		—		1,231,981
Other lease operating expense		417,886		—		417,886
Gathering system operating expenses		—		649,967		649,967
Intersegment other lease operating expense		277,509		—		277,509
Depletion, depreciation, amortization and accretion		1,877,611		170,792		2,048,403
Segment operating income	$	2,058,383	$	901,198	$	2,682,072
Reconciliation of segment operating income
Salary expense						15,838
Stock based compensation						313,589
Other general and administrative						1,462,377
Elimination of intersegment other lease operating expenses						(277,509)
Total consolidated operating income						1,167,777
Other income (expense)
Interest income						108,943
Interest expense						(8,759)
Gain on derivative contracts						(94,891)
Other expense						101,606
Other income, net						106,899
Net income before income tax expense					$	1,274,676
Capital expenditures (2)	$	9,109,756	$	47,586	$	9,157,342

(3) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended June 30, 2025 and 2024 have been eliminated upon consolidation. For the three months ended June 30, 2025, Epsilon sold natural gas to 31 unique customers. The two customers over 10% comprised 44% and 14% of total revenue. For the three months ended June 30, 2024, Epsilon sold natural gas to 26 unique customers. The three customers over 10% comprised 20%, 15% and 14% of total revenue.

(4) 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, completion, and maintenance of the gathering and compression facility.

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Commodity Risk Management Activities (Tables)

6 Months Ended

Jun. 30, 2025

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of fair value of derivatives

	Fair Value of Derivative  Assets
	June 30,		December 31,
	2025		2024
Current
Henry Hub Nymex Swap	$	322,385	$	151,274
Tennessee Z4 Basis swap		351,769		195,211
Henry Hub Nymex Option - Put		181,254		—
Crude Oil NYMEX WTI CMA		263,462		56,547
Long-term
Henry Hub Nymex Swap		7,225		—
Henry Hub Nymex Option - Put		222,199		—
	$	1,348,294	$	403,032

	Fair Value of Derivative  Liabilities
	June 30,		December 31,
	2025		2024
Current
Henry Hub Nymex Swap	$	(264,965)	$	(448,852)
Tennessee Z4 Basis swap		—		(441,728)
Henry Hub Nymex Option - Call		(105,437)		—
Long-term
Henry Hub Nymex Swap		(51,406)		—
Henry Hub Nymex Option - Call		(193,958)		—
	$	(615,766)	$	(890,580)
Net Fair Value of Derivatives	$	732,528	$	(487,548)

Schedule of fair value of derivatives rollforward

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,
	2025		2024		2025		2024
Fair value of (liability) asset, beginning of the period	$	(1,534,675)	$	511,244	$	(487,548)	$	1,100,255
Gain/(loss) on derivative contracts included in earnings		2,573,863		(94,891)		1,111,693		(195,617)
Settlement of commodity derivative contracts		(306,660)		(272,257)		108,383		(760,542)
Fair value of asset, end of the period	$	732,528	$	144,096	$	732,528	$	144,096

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Asset Retirement Obligations (Tables)

6 Months Ended

Jun. 30, 2025

Asset Retirement Obligation Disclosure [Abstract]

Schedule of activity in asset retirement obligations

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

	Six Months Ended		Year ended
		June 30,		December 31,
	2025		2024
Balance beginning of period	$	3,652,296	$	3,502,952
Liabilities acquired		18,235		48,207
Wells plugged and abandoned		(1,600)		(88,992)
Change in estimates		—		6,695
Accretion		95,885		183,434
Balance end of period	$	3,764,816	$	3,652,296

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Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2025

Fair Value Disclosures [Abstract]

Schedule of derivative instruments

	June 30, 2025
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	1,348,294	$	—	$	(615,766)	$	732,528
Cash equivalents	$	261,512	$	—	$	—	$	—	$	261,512
Liabilities
Derivative contracts	$	—	$	615,766	$	—	$	(615,766)	$	—

	December 31, 2024
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	403,032	$	—	$	(403,032)	$	—
Cash equivalents	$	298,767	$	—	$	—	$	—	$	298,767
Liabilities
Derivative contracts	$	—	$	890,580	$	—	$	(403,032)	$	487,548

Schedule of non-recurring fair value measurements

The table below summarizes the fair value of the impaired assets at June 30, 2025.

			Quoted Prices		Significant
			in Active		Other		Significant
			Markets for		Observable		Unobservable
	June 30,		Identical Assets		Inputs		Inputs
	2025		(Level 1)		(Level 2)		(Level 3)
Nonrecurring fair value measurement
Long-lived assets held and used	$	1,342,942	$	—	$	—	$	1,342,942
Total Nonrecurring fair value measurement	$	1,342,942	$	—	$	—	$	1,342,942

The table below summarizes the fair value of the impaired assets at December 31, 2024.

			Quoted Prices		Significant
			in Active		Other		Significant
			Markets for		Observable		Unobservable
	December 31,		Identical Assets		Inputs		Inputs
	2024		(Level 1)		(Level 2)		(Level 3)
Nonrecurring fair value measurement
Long-lived assets held and used	$	492,253	$	—	$	—	$	492,253
Total Nonrecurring fair value measurement	$	492,253	$	—	$	—	$	492,253

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Description of Business (Details)	6 Months Ended
	Jun. 30, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Date of Incorporation	Mar. 14, 2005

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Cash, Cash Equivalents, and Restricted Cash - Reconciliation of Cash (Details) - USD ($)	Jun. 30, 2025	Dec. 31, 2024	Jun. 30, 2024	Dec. 31, 2023
Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	$ 9,907,653	$ 6,519,793
Restricted cash included in other assets	470,000	470,000	$ 900,000
Cash, cash equivalents and restricted cash in the statement of cash flows	$ 10,377,653	$ 6,989,793	$ 9,481,484	$ 13,873,628

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Short Term Investments (Details) - USD ($)	3 Months Ended	6 Months Ended
	Jun. 30, 2024	Jun. 30, 2024	Jun. 30, 2025	Dec. 31, 2024
Schedule of Held-to-Maturity Securities [Line Items]
Short term investments			$ 0	$ 0
Securities Sold Prior To Maturity Date
Schedule of Held-to-Maturity Securities [Line Items]
Carrying amount of available for sale debt securities sold	$ 7,986,472	$ 14,989,595
Total Proceeds for available for sale securities	8,177,645	15,336,930
Realized gains on available for sale securities	191,173	347,335
Securities Sold After Maturity Date
Schedule of Held-to-Maturity Securities [Line Items]
Realized gains on available for sale securities	99,215	234,248
Carrying amount of available for sale debt securities matured	$ 4,145,000	$ 7,780,000

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Property and Equipment (Details) - USD ($)	Jun. 30, 2025	Dec. 31, 2024
Oil and gas properties, successful efforts method
Proved properties	$ 197,197,902	$ 191,879,210
Unproved properties	33,496,835	28,364,186
Accumulated depletion, depreciation, amortization and impairment	(131,899,045)	(123,281,395)
Total oil and gas properties, net	98,795,692	96,962,001
Gathering system	43,416,065	43,116,371
Accumulated depletion, depreciation, amortization and impairment	(37,057,605)	(36,449,511)
Total gathering system, net	6,358,460	6,666,860
Land	637,764	637,764
Buildings and other property and equipment, net	245,555	259,335
Total property and equipment, net	$ 106,037,471	$ 104,525,960

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Property and Equipment - Property Acquisition and Sale (Details)	Jun. 30, 2025 item	Jun. 30, 2024 a item
Property and equipment Acquisition and Sale
Number of asset acquisitions | item	0
Canada | Alberta
Property and equipment Acquisition and Sale
Asset acquisition, percentage of interests acquired		50.00%
Acres of land acquired | a		14,243
Asset Acquisition One | Texas | Ector County
Property and equipment Acquisition and Sale
Asset acquisition, percentage of interests acquired		25.00%
Asset acquisition, number of wellbores acquired | item		3
Asset Acquisition Two | Texas | Ector County
Property and equipment Acquisition and Sale
Asset acquisition, percentage of interests acquired		25.00%
Acres of land acquired | a		3,620

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Property and Equipment - Property Impairment (Details)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2025 USD ($) item	Jun. 30, 2024 USD ($)	Jun. 30, 2025 USD ($) item	Jun. 30, 2024 USD ($)	Dec. 31, 2024 USD ($)
Oil and Gas Property, Successful Effort Method, Gross [Abstract]
Impairment expense	$ 2,670,000	$ 0	$ 2,676,669	$ 0	$ 530,000
Number of wells drilled | item	2		2
Impairment of oil and gas properties		$ 0	$ 2,700,000	$ 0	$ 1,450,000

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Revolving Line of Credit (Details) - Revolving Credit Facility	6 Months Ended
	Jun. 30, 2025 USD ($)
Revolving Credit Facility
Current borrowing base	$ 45,000,000
Margin added to variable interest rate	3.25%
Investment, Variable Interest Rate, Type [Extensible Enumeration]	us-gaap:SecuredOvernightFinancingRateSofrOvernightIndexSwapRateMember

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Revolving Line of Credit - Ratios (Details) - Revolving Credit Facility - USD ($)	6 Months Ended
	Jun. 30, 2025	Dec. 31, 2024
Revolving Credit Facility
Current borrowing base	$ 45,000,000
Current ratio	1
Line of credit	$ 0	$ 0
Margin added to variable interest rate	3.25%
Investment, Variable Interest Rate, Type [Extensible Enumeration]	us-gaap:SecuredOvernightFinancingRateSofrOvernightIndexSwapRateMember
Percentage of Utilization of Borrowing Base	50.00%
Percentage of Hedging Anticipated Production from PDP Reserves	50.00%
Rolling Term for Calculation of Anticipated Production from PDP Reserves	24 months
Minimum
Revolving Credit Facility
Leverage ratio	1
Maximum
Revolving Credit Facility
Leverage ratio	2.5

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Shareholders' Equity - Share Capital (Details) - $ / shares	6 Months Ended	12 Months Ended
	Jun. 30, 2025	Dec. 31, 2024
Components of share capital:
Common shares, no par value	$ 0	$ 0
Common shares, unlimited authorized	Unlimited	Unlimited
Preferred shares, no par value	$ 0	$ 0
Preferred shares, unlimited authorized	Unlimited	Unlimited

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Shareholders' Equity - Purchases of Equity Shares (Details) - USD ($)		6 Months Ended	12 Months Ended
	Feb. 12, 2025	Jun. 30, 2025	Dec. 31, 2024
Share Repurchase Program [Line Items]
Purchased shares		0
NCIB Program 3/27/2024-3/26/2025
Share Repurchase Program [Line Items]
Shares repurchased			125,000
Consideration for shares repurchased			$ 627,500
Average price paid per share			$ 5
NCIB Program 2/12/2025-2/11/2026
Share Repurchase Program [Line Items]
Authorized shares to be repurchased	2,200,876
Shares repurchased as a percentage of outstanding common shares	10.00%
NCIB Program 2/12/2025-2/11/2026 | Maximum
Share Repurchase Program [Line Items]
Authorized amount repurchase	$ 13,000,000

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Shareholders' Equity - Equity Incentive Plan (Details)	Jun. 30, 2025 shares
Equity [Abstract]
Number of shares authorized to be issued	2,000,000

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Shareholders' Equity - Restricted Stock (Details) - Restricted Stock Unit - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024	Dec. 31, 2024	Dec. 31, 2023
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Vesting period			3 years
Stock based compensation expense	$ 385,838	$ 313,589	$ 771,676	$ 635,158
Compensation cost not yet recognized	$ 2,426,793		$ 2,426,793		$ 3,198,469
Weighted average period for recognition			1 year 1 month 20 days		1 year 3 months 18 days
Number outstanding
Balance non-vested Stock at beginning of period (in shares)			560,970	491,536	491,536
Granted (in shares)			0		300,052
Vested (in shares)			(8,639)		(230,618)
Balance non-vested Stock at end of period (in shares)	552,331		552,331		560,970	491,536
Weighted Average Remaining Life
Balance non-vested Stock at end of period (in years)			1 year 1 month 9 days		1 year 7 months 9 days	1 year 8 months 26 days
Granted (in years)					1 year 11 months 1 day
Weighted Average Grant Date Fair Value
Weighted Average Grant Date Fair Value , beginning of period			$ 5.77	$ 5.59	$ 5.59
Weighted Average Grant Date Fair Value, Granted			0		5.97
Weighted Average Grant Date Fair Value, Vested			6.15		5.65
Weighted Average Grant Date Fair Value, end of period	$ 5.77		$ 5.77		$ 5.77	$ 5.59
Board of Directors
Number outstanding
Granted (in shares)			0
Management, Employees, and Board Of Directors
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Weighted average market price at grant date (in dollars per share)					$ 5.97
Number outstanding
Granted (in shares)					300,052

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Shareholders' Equity - Dividends (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2025	Jun. 30, 2024
Class of Stock [Line Items]
Annual dividend (in dollars per share)	$ 0.25		$ 0.25
Payment of aggregate amount of dividend			$ 2,751,372	$ 2,742,349
2025 Q1 Dividends
Class of Stock [Line Items]
Dividend declared date		Feb. 26, 2025
Cash dividend of common stock (in dollars per share)		$ 0.0625
Dividend payable date		Jun. 30, 2025
2025 Q2 Dividends
Class of Stock [Line Items]
Dividend declared date	Jun. 03, 2025
Cash dividend of common stock (in dollars per share)	$ 0.0625
Dividend payable date	Jun. 30, 2025

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Revenue Recognition - Summary of revenue (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Revenue recognition
Total operating revenue	$ 11,624,733	$ 7,307,818	$ 27,787,873	$ 15,294,561
Natural Gas
Revenue recognition
Total operating revenue	6,910,344	1,961,230	17,523,917	4,924,209
Natural Gas Liquids
Revenue recognition
Total operating revenue	145,020	388,423	532,270	761,407
Oil and Condensate
Revenue recognition
Total operating revenue	2,724,364	3,513,717	5,994,331	6,228,799
Gathering and Compression fees
Revenue recognition
Total operating revenue	1,845,005	1,444,448	3,737,355	3,380,146
Gathering and Compression fees | Intersubsegment Eliminations
Revenue recognition
Total operating revenue	$ 500,000	$ 300,000	$ 1,100,000	$ 600,000

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Revenue Recognition - Additional Information (Details)	6 Months Ended
	Jun. 30, 2025
Gas, oil, NGL and condensate revenue
Revenue recognition
Period settlement statement received	30 days
Gathering and Compression fees | Auburn Gas Gathering System
Revenue recognition
Period settlement statement received	2 months

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Revenue Recognition - Accounts receivable (Details) - USD ($)	Jun. 30, 2025	Dec. 31, 2024	Dec. 31, 2023
Disaggregation of Revenue [Line Items]
Allowance for credit loss	$ 0	$ 0
Accounts receivable	5,496,883	5,843,722	$ 6,015,448
Natural gas and oil sales
Disaggregation of Revenue [Line Items]
Accounts receivable	3,946,643	4,888,294	4,327,886
Joint Interest Billing
Disaggregation of Revenue [Line Items]
Accounts receivable	0	0	17,476
Gathering and Compression fees
Disaggregation of Revenue [Line Items]
Accounts receivable	1,434,591	918,471	1,543,239
Commodity Contract
Disaggregation of Revenue [Line Items]
Accounts receivable	115,649	36,957	72,075
Interest
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 0	$ 0	$ 54,772

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Accumulated Other Comprehensive Income (Details) - USD ($)	3 Months Ended				6 Months Ended
	Jun. 30, 2025	Mar. 31, 2025	Jun. 30, 2024	Mar. 31, 2024	Jun. 30, 2025	Jun. 30, 2024
Accumulated Other Comprehensive Income (Loss)
Balance at beginning of period	$ 99,704,273	$ 96,728,129	$ 99,863,068	$ 100,612,965	$ 96,728,129	$ 100,612,965
Translation (loss)/gain	(75,496)	(50,116)	25,240	(4,245)
Unrealized gain/(loss) on securities	0		3,011		0	(1,598)
Balance at end of period	100,190,316	99,704,273	99,645,617	99,863,068	100,190,316	99,645,617
Foreign Currency Translation Adjustment
Accumulated Other Comprehensive Income (Loss)
Balance at beginning of period	9,983,151	10,033,267	9,768,032	9,772,277	10,033,267	9,772,277
Translation (loss)/gain	(75,496)		22,229		(125,612)	22,593
Unrealized gain/(loss) on securities	0		3,011		0	(1,598)
Balance at end of period	$ 9,907,655	$ 9,983,151	$ 9,793,272	$ 9,768,032	$ 9,907,655	$ 9,793,272

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Income Taxes - Current and Deferred Tax Expense (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Current:
Federal	$ 1,794,581	$ 401,042	$ 3,358,642	$ 467,310
State	501,330	89,717	928,915	100,492
Total current income tax expense	2,295,911	490,759	4,287,557	567,802
Deferred:
Federal	(413,762)	(23,214)	(704,026)	354,385
State	(44,462)	(8,529)	(75,650)	(409,121)
Total deferred tax expense	(458,224)	(31,743)	(779,676)	(54,736)
Income tax expense	$ 1,837,687	$ 459,016	$ 3,507,881	$ 513,066

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Commitments and Contingencies (Details) $ in Millions	Jun. 30, 2025 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Commitments for capital expenditures	$ 1.9

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Leases - Lease Commitment (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2025	Dec. 31, 2024	Jun. 30, 2024
Assets
Operating lease right-of-use assets, long term	$ 295,317	$ 344,589	$ 392,792
Total operating lease right-of-use assets	295,317	344,589
Operating lease liabilities	121,057	121,135
Operating lease liabilities, long term	296,250	355,776
Total operating lease liabilities	417,307	476,911
Operating lease costs	120,926	236,044
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$ 152,709	$ 214,230
Weighted average remaining lease term	2 years 3 months 14 days	2 years 6 months
Weighted average discount rate	8.25%	8.25%

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Leases - Future Minimum Lease Commitments (Details) - USD ($)	Jun. 30, 2025	Dec. 31, 2024
Future Minimum Lease Commitments
2025	$ 86,775
2026	177,021
2027	180,492
2028	183,963
Total minimum lease payments	628,251
Less: imputed interest	(210,944)
Total operating lease liabilities	417,307	$ 476,911
Less: current obligations under leases	(121,057)	(121,135)
Long-term lease obligations	$ 296,250	$ 355,776

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Leases - Narrative (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2025	Dec. 31, 2024	Mar. 01, 2023
Leases
Future lease payments estimated	$ 628,251
Rent expense for operating leases	$ 120,000	$ 240,000
New office lease
Leases
Lease term			70 months
Future lease payments estimated			$ 850,000

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Net Income Per Share (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net income	$ 1,551,461	$ 815,660	$ 5,567,495	$ 2,322,556
Weighted average number of shares - basic and diluted
Basic weighted-average number of shares outstanding	22,017,310	21,921,752	22,013,062	21,957,980
Diluted weighted-average shares outstanding	22,202,315	22,029,475	22,155,629	21,987,142
Time-Based Restricted Shares
Weighted average number of shares - basic and diluted
Incremental common shares	185,005	107,723	142,567	29,162
Total Anti-dilutive shares	367,421	492,463	411,203	512,389

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Operating Segments - Segments (Details)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2025 USD ($)	Jun. 30, 2024 USD ($)	Jun. 30, 2025 USD ($) segment	Jun. 30, 2024 USD ($)	Dec. 31, 2024 USD ($)
Segment information
Total operating revenue	$ 11,624,733	$ 7,307,818	$ 27,787,873	$ 15,294,561
Operating costs
Impairment expense	2,670,000	0	2,676,669	0	$ 530,000
Depletion, depreciation, amortization and accretion	3,201,654	2,048,403	6,677,511	4,428,829
Salary expense	710,122	15,838	1,789,792	1,461,549
Stock based compensation expense	385,838	313,589	771,676	635,158
Other general and administrative	751,756	1,462,377	1,490,504	1,575,689
Operating income	828,783	1,167,777	7,996,592	2,572,470
Other income (expense):
Interest income	17,247	108,943	32,546	375,215
Interest expense	(19,906)	(8,759)	(32,117)	(17,519)
(Loss) gain on derivative contracts	2,573,863	(94,891)	1,111,693	(195,617)
Other income	(10,839)	101,606	(33,338)	101,073
Other income, net	2,560,365	106,899	1,078,784	263,152
Net income before income tax expense	3,389,148	1,274,676	9,075,376	2,835,622
Capital expenditures	3,627,029	9,157,342	11,371,071	29,502,320
Assets	123,613,668	121,144,956	123,613,668	121,144,956	120,454,785
Current assets, net	16,533,328	14,977,407	16,533,328	14,977,407	14,131,519
Other property and equipment	883,319	919,208	883,319	919,208
Operating lease right-of-use asset	295,317	392,792	295,317	392,792	344,589
Restricted cash	470,000	900,000	470,000	900,000	$ 470,000
Operating Segments
Segment information
Total operating revenue	12,132,098	7,585,327	28,852,096	15,886,468
Operating costs
Gathering, transportation, and compression	1,924,460	1,231,981	3,978,175	2,602,378
Other lease operating expense	538,325	417,886	1,240,508	815,951
Gathering system operating expenses	613,795	649,967	1,166,446	1,202,537
Intersegment other lease operating expense	507,365	277,509	1,064,223	591,907
Impairment expense	2,670,000		2,676,669
Depletion, depreciation, amortization and accretion	3,201,654	2,048,403	6,677,511	4,428,829
Operating income	2,169,134	2,682,072	10,984,341	5,652,959
Other income (expense):
Assets	105,431,704	103,955,549	105,431,704	103,955,549
Elimination
Segment information
Total operating revenue	(507,365)	(277,509)	(1,064,223)	(591,907)
Operating costs
Intersegment other lease operating expense	(507,365)	(277,509)	(1,064,223)	(591,907)
Natural Gas
Segment information
Total operating revenue	6,910,344	1,961,230	17,523,917	4,924,209
Natural Gas | Operating Segments
Segment information
Total operating revenue	6,910,344	1,961,230	17,523,917	4,924,209
Natural Gas Liquids
Segment information
Total operating revenue	145,020	388,423	532,270	761,407
Natural Gas Liquids | Operating Segments
Segment information
Total operating revenue	145,020	388,423	532,270
Oil and Condensate
Segment information
Total operating revenue	2,724,364	3,513,717	5,994,331	6,228,799
Oil and Condensate | Operating Segments
Segment information
Total operating revenue	2,724,364	3,513,717	5,994,331	6,228,799
Gathering and Compression fees
Segment information
Total operating revenue	1,845,005	1,444,448	3,737,355	3,380,146
Gathering and Compression fees | Operating Segments
Segment information
Total operating revenue	1,845,005	1,444,448	3,737,355	3,380,146
Intersegment revenue	507,365	277,509	1,064,223	591,907
Upstream
Other income (expense):
Capital expenditures	3,502,977	9,109,756	11,142,744	29,432,084
Upstream | Operating Segments
Segment information
Total operating revenue	9,779,728	5,863,370	24,050,518	11,914,415
Operating costs
Gathering, transportation, and compression	1,924,460	1,231,981	3,978,175	2,602,378
Other lease operating expense	538,325	417,886	1,240,508	815,951
Gathering system operating expenses		0
Intersegment other lease operating expense	507,365	277,509	1,064,223	591,907
Impairment expense	2,670,000		2,676,669
Depletion, depreciation, amortization and accretion	2,919,238	1,877,611	6,065,544	4,007,320
Operating income	1,220,340	2,058,383	9,025,399	3,896,859
Other income (expense):
Assets	99,073,244	97,059,040	99,073,244	97,059,040
Upstream | Natural Gas | Operating Segments
Segment information
Total operating revenue	6,910,344	1,961,230	17,523,917	4,924,209
Upstream | Natural Gas Liquids
Segment information
Total operating revenue				761,407
Upstream | Natural Gas Liquids | Operating Segments
Segment information
Total operating revenue	145,020	388,423	532,270
Upstream | Oil and Condensate | Operating Segments
Segment information
Total operating revenue	2,724,364	3,513,717	5,994,331	6,228,799
Upstream | Gathering and Compression fees | Operating Segments
Segment information
Total operating revenue		0
Intersegment revenue		0
Gas Gathering
Other income (expense):
Capital expenditures	124,052	47,586	$ 228,327	70,236
Gas Gathering | Operating Segments
Operating Segments
Number of companies partnered to operate natural gas gathering system | segment			2
Segment information
Total operating revenue	2,352,370	1,721,957	$ 4,801,578	3,972,053
Operating costs
Gathering, transportation, and compression		0
Other lease operating expense		0
Gathering system operating expenses	613,795	649,967	1,166,446	1,202,537
Intersegment other lease operating expense		0
Depletion, depreciation, amortization and accretion	282,416	170,792	611,967	421,509
Operating income	1,456,159	901,198	3,023,165	2,348,007
Other income (expense):
Assets	6,358,460	6,896,509	6,358,460	6,896,509
Gas Gathering | Natural Gas | Operating Segments
Segment information
Total operating revenue		0
Gas Gathering | Natural Gas Liquids | Operating Segments
Segment information
Total operating revenue		0
Gas Gathering | Oil and Condensate | Operating Segments
Segment information
Total operating revenue		0
Gas Gathering | Gathering and Compression fees | Operating Segments
Segment information
Total operating revenue	1,845,005	1,444,448	3,737,355	3,380,146
Intersegment revenue	$ 507,365	$ 277,509	$ 1,064,223	$ 591,907

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Operating Segments - Customers (Details) - customer	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Natural Gas
Concentration risk
Number of customers	31	26	34	29
Customer Concentration Risk
Concentration risk
Number of customers	2	3	1	3
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)	44.00%	20.00%	34.00%	14.00%
Total Revenue | Customer Concentration Risk | Customer Two
Concentration risk
Concentration risk (as a percent)	14.00%	15.00%		11.00%
Total Revenue | Customer Concentration Risk | Customer Three
Concentration risk
Concentration risk (as a percent)		14.00%		10.00%

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Commodity Risk Management Activities - Commodity Price Risks (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Recognized gains (losses) on financial commodity derivative contracts	$ 2,573,863	$ (94,891)	$ 1,111,693	$ (195,617)
Cash received (paid) from settlements of derivative contracts	$ 306,660	$ 272,257	$ (108,383)	$ 760,542

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Commodity Risk Management Activities - Fair Value of Derivative Instruments (Details)	6 Months Ended
	Jun. 30, 2025 USD ($) Bcf MBbls	Dec. 31, 2024 USD ($)
Risk Management Activities
Fair Value of Derivative Assets, current	$ 732,528	$ 0
Fair value of derivative liabilities, current	0	(487,548)
Commodity Derivative Contracts
Risk Management Activities
Net Fair Value of Derivatives	732,528	(487,548)
Commodity Derivative Contracts | Natural Gas
Risk Management Activities
Fair Value of Derivative Assets	1,348,294	403,032
Fair Value of Derivative Liabilities	$ (615,766)	(890,580)
Commodity Derivative Contracts | NYMEX Henry Hub Swap | Natural Gas
Risk Management Activities
Nonmonetary notional amount | Bcf	2.67
Fair Value of Derivative Assets, current	$ 322,385	151,274
Fair Value of Derivative Assets, Noncurrent	7,225	0
Fair value of derivative liabilities, current	(264,965)	(448,852)
Fair Value of Derivative Liabilities, non-current	$ (51,406)	0
Commodity Derivative Contracts | Henry Hub Nymex Options | Natural Gas
Risk Management Activities
Nonmonetary notional amount | Bcf	0.93
Commodity Derivative Contracts | Henry Hub Nymex Option - Put | Natural Gas
Risk Management Activities
Fair Value of Derivative Assets, current	$ 181,254	0
Fair Value of Derivative Assets, Noncurrent	222,199	0
Commodity Derivative Contracts | Henry Hub Nymex Option - Call | Natural Gas
Risk Management Activities
Fair value of derivative liabilities, current	(105,437)	0
Fair Value of Derivative Liabilities, non-current	$ (193,958)	0
Commodity Derivative Contracts | Tennessee Z4 basis swap | Natural Gas
Risk Management Activities
Nonmonetary notional amount | Bcf	0.78
Fair Value of Derivative Assets, current	$ 351,769	195,211
Fair value of derivative liabilities, current	$ 0	(441,728)
Commodity Derivative Contracts | Crude Oil NYMEX WTI CMA | Crude Oil
Risk Management Activities
Nonmonetary notional amount | MBbls	40
Fair Value of Derivative Assets, current	$ 263,462	$ 56,547

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Commodity Risk Management Activities - Fair Value of Asset (Liability) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2025	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair value of asset, beginning of the period	$ (1,534,675)	$ 511,244	$ (487,548)	$ 1,100,255
Gain/(loss) on derivative contracts included in earnings	$ 2,573,863	$ (94,891)	$ 1,111,693	$ (195,617)
Gain (loss) on derivative contracts included in earnings, Statement of Income or Comprehensive Income	Gain (loss) on derivative contracts	Gain (loss) on derivative contracts	Gain (loss) on derivative contracts	Gain (loss) on derivative contracts
Settlement of commodity derivative contracts	$ (306,660)	$ (272,257)	$ 108,383	$ (760,542)
Fair value of asset, end of the period	$ 732,528	$ 144,096	$ 732,528	$ 144,096

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Asset Retirement Obligations (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2025	Dec. 31, 2024
Reconciliation of provision for asset retirement obligations
Balance beginning of period	$ 3,652,296	$ 3,502,952
Liabilities acquired	18,235	48,207
Wells plugged and abandoned	(1,600)	(88,992)
Change in estimates	0	6,695
Accretion	95,885	183,434
Balance end of period	$ 3,764,816	$ 3,652,296

XML

Fair Value Measurements (Details) - USD ($)	3 Months Ended	6 Months Ended		12 Months Ended
	Jun. 30, 2024	Jun. 30, 2025	Jun. 30, 2024	Dec. 31, 2024
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of oil and gas properties	$ 0	$ 2,700,000	$ 0	$ 1,450,000
Derivative contracts, Liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of Netting, Asset		(615,766)
Effect of Netting, Liability				(403,032)
Net Fair Value, Liability		0		487,548
Derivative contracts, Assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of Netting, Asset		(615,766)		(403,032)
Net Fair Value, Liability		732,528		0
Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Effect of Netting, Asset		0		0
Net Fair Value, Asset		261,512
Net Fair Value, Liability				298,767
Level 1 | Derivative contracts, Liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		0
Fair value, Liability gross				0
Level 1 | Derivative contracts, Assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		0		0
Level 1 | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		261,512		298,767
Level 2 | Derivative contracts, Liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		615,766
Fair value, Liability gross				890,580
Level 2 | Derivative contracts, Assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		1,348,294		403,032
Level 2 | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		0		0
Level 3 | Derivative contracts, Liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		0
Fair value, Liability gross				0
Level 3 | Derivative contracts, Assets
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		0		0
Level 3 | Cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets, Gross, Current		$ 0		$ 0

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Fair Value Measurements - Fair value of the impaired assets (Details) - Non-recurring - USD ($)	Jun. 30, 2025	Dec. 31, 2024
Property and Equipment
Total Nonrecurring fair value measurement	$ 1,342,942	$ 492,253
Oil and gas properties
Property and Equipment
Total Nonrecurring fair value measurement	1,342,942	492,253
Level 3
Property and Equipment
Total Nonrecurring fair value measurement	1,342,942	492,253
Level 3 | Oil and gas properties
Property and Equipment
Total Nonrecurring fair value measurement	$ 1,342,942	$ 492,253

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Subsequent Events (Details) - Subsequent Event - Peak Exploration and Production LLC shares in Millions, $ in Millions	Aug. 11, 2025 USD ($) a entity shares
Subsequent events
Acres of land acquired | a	40,500
Number of entities acquired | entity	2
Proposed issuance of shares as consideration	6.0
Price consideration | $	$ 49.0
Additional consideration proposed as issuance shares, minimum	1.5
Additional consideration proposed as issuance shares, maximum	2.5
Business combination, termination, cash option, retain undeveloped leasehold | $	$ 6.5
Acquired assets, power produced volume (in MBoepd)	2.2