EPSILON ENERGY LTD._March 31, 2025

Three months ended March 31,

Net income

Table of Contents

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 March 31, 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 May 13, 2025, there were 22,017,405 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	20
	Commodity Price Risks	20
	Commodity Derivative Contracts	20
16.	Asset Retirement Obligations	21
17.	Fair Value Measurements	21

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		23
	Overview	23
	Business Strategy	23
	Operational Highlights	24
	Non-GAAP Financial Measures-Adjusted EBITDA	24
	Net Operating Revenues	26
	Operating Costs	27
	Depletion, Depreciation, Amortization and Accretion	27
	General and Administrative	28
	Interest Income	28
	Interest Expense	28

Table of Contents

	Loss on Derivative Contracts	29
	Capital Resources and Liquidity	29
	Cash Flow	29
	Credit Agreement	30
	Repurchase Transactions	30
	Derivative Transactions	30
	Contractual Obligations	31
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		31
	Gathering System Revenue Risk	31
	Interest Rate Risk	31
	Derivative Contracts	31
ITEM 4. CONTROLS AND PROCEDURES		32
	Disclosure Controls and Procedures	32
	Changes in Internal Control Over Financial Reporting	32
	Inherent Limitations on Effectiveness of Controls	32
PART II OTHER INFORMATION		32
ITEM 1. LEGAL PROCEEDINGS		32
ITEM 1A. RISK FACTORS		32
ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS		32
ITEM 3. DEFAULTS UPON SENIOR SECURITIES		32
ITEM 4. MINE SAFETY DISCLOSURES		33
ITEM 5. OTHER INFORMATION		33
ITEM 6. EXHIBITS		34
SIGNATURES		34

Table of Contents

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.

Table of Contents

PART I-FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Balance Sheets


	March 31,		December 31,
	2025		2024
ASSETS
Current assets
Cash and cash equivalents	$	6,892,735	$	6,519,793
Accounts receivable		8,003,517		5,843,722
Prepaid income taxes		—		975,963
Other current assets		647,295		792,041
Total current assets		15,543,547		14,131,519
Non-current assets
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties		194,811,616		191,879,210
Unproved properties		33,425,087		28,364,186
Accumulated depletion, depreciation, amortization and impairment		(126,370,072)		(123,281,395)
Total oil and gas properties, net		101,866,631		96,962,001
Gathering system		43,176,418		43,116,371
Accumulated depletion, depreciation, amortization and impairment		(36,777,152)		(36,449,511)
Total gathering system, net		6,399,266		6,666,860
Land		637,764		637,764
Buildings and other property and equipment, net		246,894		259,335
Total property and equipment, net		109,150,555		104,525,960
Other assets:
Operating lease right-of-use assets, long term		318,604		344,589
Restricted cash		470,000		470,000
Prepaid drilling costs		22,581		982,717
Total non-current assets		109,961,740		106,323,266
Total assets	$	125,505,287	$	120,454,785

LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Accounts payable trade	$	2,013,172	$	2,334,732
Gathering fees payable		1,651,164		997,016
Royalties payable		2,019,819		1,400,976
Income taxes payable		924,905		—
Accrued capital expenditures		309,630		572,079
Accrued compensation		284,905		695,018
Other accrued liabilities		481,770		371,503
Fair value of derivatives		1,534,675		487,548
Operating lease liabilities		121,293		121,135
Total current liabilities		9,341,333		6,980,007
Non-current liabilities
Asset retirement obligations		3,716,029		3,652,296
Deferred income taxes		12,417,125		12,738,577
Operating lease liabilities, long term		326,527		355,776
Total non-current liabilities		16,459,681		16,746,649
Total liabilities		25,801,014		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 22,008,766 shares issued and outstanding at March 31, 2025 and December 31, 2024		116,081,031		116,081,031
Additional paid-in capital		12,504,745		12,118,907
Accumulated deficit		(38,864,654)		(41,505,076)
Accumulated other comprehensive income		9,983,151		10,033,267
Total shareholders' equity		99,704,273		96,728,129
Total liabilities and shareholders' equity	$	125,505,287	$	120,454,785

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

Table of Contents

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Operations and Comprehensive Income


	Three months ended March 31,
	2025		2024
Revenues from contracts with customers:
Gas, oil, NGL, and condensate revenue	$	14,270,790	$	6,051,045
Gas gathering and compression revenue		1,892,350		1,935,698
Total revenue		16,163,140		7,986,743

Operating costs and expenses:
Lease operating expenses		2,755,898		1,768,462
Gathering system operating expenses		552,651		552,570
Depletion, depreciation, amortization, and accretion		3,475,857		2,380,426
Impairment expense		6,669		—
General and administrative expenses:
Stock based compensation expense		385,838		321,569
Other general and administrative expenses		1,818,418		1,559,023
Total operating costs and expenses		8,995,331		6,582,050
Operating income		7,167,809		1,404,693

Other income (expense):
Interest income		15,299		266,272
Interest expense		(12,211)		(8,760)
Loss on derivative contracts		(1,462,170)		(100,726)
Other expense		(22,499)		(533)
Other (expense) income, net		(1,481,581)		156,253

Net income before income tax expense		5,686,228		1,560,946
Income tax expense		1,670,194		54,050
NET INCOME	$	4,016,034	$	1,506,896
Currency translation adjustments		(50,116)		364
Unrealized loss on securities		—		(4,609)
NET COMPREHENSIVE INCOME	$	3,965,918	$	1,502,651

Net income per share, basic	$	0.18	$	0.07
Net income per share, diluted	$	0.18	$	0.07
Weighted average number of shares outstanding, basic		22,008,766		21,994,207
Weighted average number of shares outstanding, diluted		22,109,819		21,994,207

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

Table of Contents

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


									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

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

Table of Contents

EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Cash Flows


	Three months ended March 31,
	2025		2024
Cash flows from operating activities:
Net income	$	4,016,034	$	1,506,896
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion		3,475,857		2,380,426
Impairment expense		6,669		—
Accretion of discount on available for sale securities		—		(216,180)
Loss on derivative contracts		1,462,170		100,726
Settlement (paid) received on derivative contracts		(415,043)		488,285
Settlement of asset retirement obligation		(1,600)		(1,653)
Stock-based compensation expense		385,838		321,569
Deferred income tax expense (benefit)		(321,452)		(22,993)
Changes in assets and liabilities:
Accounts receivable		(2,159,795)		953,714
Prepaid income taxes		978,542		(68,401)
Other assets and liabilities		141,640		146,477
Accounts payable, royalties payable, gathering fees payable, and other accrued liabilities		91,390		(1,897,438)
Income taxes payable		922,326		—
Net cash provided by operating activities		8,582,576		3,691,428
Cash flows from investing activities:
Additions to unproved oil and gas properties		(5,060,901)		(3,088,198)
Additions to proved oil and gas properties		(2,578,866)		(17,226,449)
Additions to gathering system properties		(104,275)		(22,650)
Additions to land, buildings and property and equipment		—		(7,681)
Purchases of short term investments - available for sale		—		(4,045,785)
Proceeds from short term investments - held to maturity		—		10,794,285
Prepaid drilling costs		960,136		1,813,808
Net cash used in investing activities		(6,783,906)		(11,782,670)
Cash flows from financing activities:
Buyback of common shares		—		(1,203,708)
Dividends paid		(1,375,612)		(1,370,409)
Net cash used in financing activities		(1,375,612)		(2,574,117)
Effect of currency rates on cash, cash equivalents, and restricted cash		(50,116)		364
Decrease in cash, cash equivalents, and restricted cash		372,942		(10,664,995)
Cash, cash equivalents, and restricted cash, beginning of period		6,989,793		13,873,628
Cash, cash equivalents, and restricted cash, end of period	$	7,362,735	$	3,208,633

Supplemental cash flow disclosures:
Income tax paid - federal	$	80,000	$	—
Income tax paid - state (PA)	$	5,138	$	—
Income tax paid - state (other)	$	25	$	—
Interest paid	$	657	$	—

Non-cash investing activities:
Change in proved properties accrued in accounts payable	$	341,974	$	2,946,528
Change in gathering system accrued in accounts payable	$	(44,228)	$	(3,624)
Asset retirement obligation asset additions and adjustments	$	18,235	$	16,372

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

Table of Contents

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

Table of Contents

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.

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 March 31, 2025 and December 31, 2024:


	March 31,		December 31,
	2025		2024
Cash and cash equivalents	$	6,892,735	$	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	$	7,362,735	$	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.

As of March 31, 2025 and December 31, 2024, the Company had no short term investments. During the three months ended March 31, 2024, the Company sold securities with a carrying amount of $7,003,123 for total proceeds of $7,159,285. The realized gains on these sales were $156,162. An additional $3,635,000 of securities reached maturity with total realized gains of $135,034. The realized gains are included in Other (expense) income, net in the Consolidated Statements of Operations and Comprehensive Income.

Table of Contents

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

5. Property and Equipment

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


	March 31,		December 31,
	2025		2024
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	194,811,616	$	191,879,210
Unproved properties		33,425,087		28,364,186
Accumulated depletion, depreciation, amortization and impairment		(126,370,072)		(123,281,395)
Total oil and gas properties, net		101,866,631		96,962,001
Gathering system		43,176,418		43,116,371
Accumulated depletion, depreciation, amortization and impairment		(36,777,152)		(36,449,511)
Total gathering system, net		6,399,266		6,666,860
Land		637,764		637,764
Buildings and other property and equipment, net		246,894		259,335
Total property and equipment, net	$	109,150,555	$	104,525,960

Asset Acquisitions

During the three months ended March 31, 2025, Epsilon had no asset acquisitions.

During the three months ended March 31, 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 3,246 gross undeveloped acres in Ector County, Texas.

●

total consideration paid of $14.8 million consisting of

(i)

$12.1 million for the producing wells and

(ii)

$2.7 million for the undeveloped acreage.

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 months ended March 31, 2025, Epsilon recorded an impairment of $0.01 million for one well drilled during 2024 that was deemed non-commercial. During the three months ended March 31, 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

Table of Contents

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

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 March 31, 2025.

Balance at

March 31,

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.

During the three months ended March 31, 2025, no shares were repurchased under the new or previous program.

Table of Contents

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

(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 three months ended March 31, 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 three months ended March 31, 2025, and the year ended December 31, 2024:


	Three months ended				Year ended
	March 31, 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	—	—		-	(230,618)	—		5.65
Balance non-vested Restricted Stock at end of period	560,970	1.35	$	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 months ended March 31, 2025 and 2024 was $385,838 and $321,569, respectively.

As of March 31, 2025, the Company had unrecognized stock-based compensation related these shares of $2,817,243 to be recognized over a weighted average period of 1.19 years (at December 31, 2024: $3,198,469 over 1.30 years).

(d)Dividends

On February 26, 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 $1.38 million that was paid on March 31, 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.

Table of Contents

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 $0.6 million and $0.3 million, respectively, for the three months ended March 31, 2025 and 2024.

The following table details revenue for the three months ended March 31, 2025 and 2024.


	Three Months Ended March 31,
	2025		2024
Operating revenue
Natural gas	$	10,613,573	$	2,962,979
Natural gas liquids		387,250		372,984
Oil and condensate		3,269,967		2,715,082
Gathering and compression fees⁽¹⁾		1,892,350		1,935,698
Total operating revenue	$	16,163,140	$	7,986,743

(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 receivables 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,

Table of Contents

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 March 31, 2025 and December 31, 2024, we determined that our allowance for credit loss was nil.


	March 31,		December 31,		December 31,
	2025		2024		2023
Accounts receivable
Natural gas and oil sales	$	6,357,749	$	4,888,294	$	4,327,886
Joint interest billing		—		—		17,476
Gathering and compression fees		1,615,086		918,471		1,543,239
Commodity contract		30,682		36,957		72,075
Interest		—		—		54,772
Total accounts receivable	$	8,003,517	$	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 months ended March 31, 2025 and 2024 consisted of the following:


	Three Months Ended March 31,
	2025		2024
Balance at beginning of period	$	10,033,267	$	9,772,277
Translation gain/(loss)		(50,116)		364
Unrealized (loss)/gain on securities		—		(4,609)
Balance at end of period	$	9,983,151	$	9,768,032

10. Income Taxes

Income tax provisions for the three months ended March 31, 2025 and 2024 are as follows:


	Three months ended March 31,
	2025		2024
Current:
Federal	$	1,564,061	$	66,268
State		427,585		10,775
Total current income tax expense		1,991,646		77,043
Deferred:
Federal		(290,264)		377,599
State		(31,188)		(400,592)
Total deferred tax expense		(321,452)		(22,993)
Income tax expense	$	1,670,194	$	54,050

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

Table of Contents

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 three months ended March 31, 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.

11. Commitments and Contingencies

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of March 31, 2025, the Company had no commitments for capital expenditures.

12. Leases

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


	March 31,		December 31,
	2025		2024
Asset
Operating lease right-of-use assets, long term	$	318,604	$	344,589
Total operating lease right-of-use assets	$	318,604	$	441,987

Liabilities
Operating lease liabilities	$	121,293	$	121,135
Operating lease liabilities, long term		326,527		355,776
Total operating lease liabilities	$	447,820	$	476,911

Operating lease costs	$	60,349	$	236,044

Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	84,906	$	214,230
Weighted average remaining lease term (years) - operating lease		2.40		2.50
Weighted average discount rate (annualized) - operating lease		8.25%		8.25%

Table of Contents

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

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 $0.06 million and $0.24 million for the three months ended March 31, 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 March 31, 2025 are as follows:


	Operating Leases
2025	$	130,162
2026		177,021
2027		180,492
2028		183,963
Total minimum lease payments		671,638
Less: imputed interest		(223,818)
Present value of future minimum lease payments		447,820
Less: current obligations under leases		(121,293)
Long-term lease obligations	$	326,527

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:

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


	Three months ended March 31,
	2025	2024
Basic weighted-average number of shares outstanding	22,008,766	21,994,207
Unvested time-based restricted shares	101,053	—
Diluted weighted-average shares outstanding	22,109,819	21,994,207

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


	Three months ended March 31,
	2025	2024
Anti-dilutive unvested time-based restricted shares	459,917	546,245

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.

Table of Contents

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:

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

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

Segment activity for the three months ended March 31, 2025 is as follows:


	Upstream		Gas Gathering		Consolidated
As of and for the three months ended March 31, 2025
Operating revenue
Natural gas	$	10,613,573	$	—	$	10,613,573
Natural gas liquids		387,250		—		387,250
Oil and condensate		3,269,967		—		3,269,967
Gathering and compression fees		—		1,892,350		1,892,350
Intersegment gathering and compression fees		—		556,858		556,858
		14,270,790		2,449,208		16,719,998

Reconciliation of operating revenue
Elimination of intersegment revenues						(556,858)
Total consolidated operating revenue⁽¹⁾						16,163,140

Operating costs
Gathering, transportation, and compression		2,053,715		—		2,053,715
Other lease operating expense		702,183		—		702,183
Gathering system operating expenses		—		552,651		552,651
Intersegment other lease operating expense		556,858		—		556,858
Impairment		6,669		—		6,669
Depletion, depreciation, amortization and accretion		3,146,306		329,551		3,475,857
Segment operating income	$	7,805,059	$	1,567,006	$	8,815,207

Reconciliation of segment operating income
Salary expense						1,079,670
Stock based compensation						385,838
Other general and administrative						738,748
Elimination of intersegment other lease operating expenses						(556,858)
Total consolidated operating income						7,167,809

Other income (expense)
Interest income						15,299
Interest expense						(12,211)
Gain on derivative contracts						(1,462,170)
Other expense						(22,499)
Other expense, net						(1,481,581)
Net income before income tax expense					$	5,686,228

Capital expenditures⁽²⁾	$	7,639,767	$	104,275	$	7,744,042
Segment assets	$	101,889,212	$	6,399,266	$	108,288,478

Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	108,288,478
Current assets, net						15,543,547
Other property and equipment						884,658
Operating lease right-of-use asset						318,604
Restricted Cash						470,000
					$	125,505,287

Table of Contents

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Segment activity for the three months ended March 31, 2024 is as follows:


	Upstream		Gas Gathering		Consolidated
As of and for the three months ended March 31, 2024
Operating revenue
Natural gas	$	2,962,979	$	—	$	2,962,979
Natural gas liquids		372,984		—		372,984
Oil and condensate		2,715,082		—		2,715,082
Gathering and compression fees		—		1,935,698		1,935,698
Intersegment gathering and compression fees		—		314,398		314,398
		6,051,045		2,250,096		8,301,141

Reconciliation of operating revenue
Elimination of intersegment revenues						(314,398)
Total consolidated operating revenue⁽¹⁾						7,986,743

Operating costs
Gathering, transportation, and compression		1,370,398		—		1,370,398
Other lease operating expense		398,064		—		398,064
Gathering system operating expenses		—		552,570		552,570
Intersegment other lease operating expense		314,398		—		314,398
Depletion, depreciation, amortization and accretion		2,129,709		250,717		2,380,426
Segment operating income	$	1,838,476	$	1,446,809	$	2,970,887

Reconciliation of segment operating income
Salary expense						800,395
Stock based compensation						321,569
Other general and administrative						758,628
Elimination of intersegment other lease operating expenses						(314,398)
Total consolidated operating income						1,404,693

Other income (expense)
Interest income						266,272
Interest expense						(8,760)
Gain on derivative contracts						(100,726)
Other expense						(533)
Other income, net						156,253
Net income before income tax expense					$	1,560,946

Capital expenditures⁽²⁾	$	20,322,328	$	22,650	$	20,344,978
Segment assets	$	93,262,985	$	6,968,392	$	100,231,377

Total segment assets reconciled to consolidated amounts are as follows:
Total segment assets					$	100,231,377
Current assets, net						22,596,300
Other property and equipment						925,288
Operating lease right-of-use asset						417,268
Restricted Cash						900,000
					$	125,070,233

(1)

Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended March 31, 2025 and 2024 have been eliminated upon consolidation. For the three months ended March 31, 2025, Epsilon sold natural gas to 38 unique customers. The one customer over 10% comprised 25% of total revenue. For the three months ended March 31, 2024, Epsilon sold natural gas to 23 unique customers. The two customers over 10% comprised 25% and 12% 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.

Table of Contents

Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

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 months ended March 31, 2025, Epsilon recognized losses on commodity derivative contracts of $1,462,170. This amount included cash paid on settlements on these contracts of $415,043. For the three months ended March 31, 2024, Epsilon recognized losses on commodity derivative contracts of $100,726, respectively. This amount included cash received on settlements on these contracts of $488,285.

Commodity Derivative Contracts

At March 31, 2025, the Company had outstanding natural gas NYMEX Henry Hub (“HH”) swaps totaling 1.56 Bcf, natural gas Tennessee Z4 basis swaps totaling 1.56 Bcf, and crude oil NYMEX WTI CMA swaps totaling 47 MBbls.


	Fair Value of Derivative Assets
	March 31,		December 31,
	2025		2024
Current
NYMEX Henry Hub swap	$	—	$	151,274
Tennessee Z4 basis swap		285,583		195,211
Crude Oil NYMEX WTI CMA		89,782		56,547
	$	375,365	$	403,032


	Fair Value of Derivative Liabilities
	March 31,		December 31,
	2025		2024
Current
NYMEX Henry Hub swap	$	(1,872,793)	$	(448,852)
Tennessee Z4 Basis swap		(34,798)		(441,728)
Crude Oil NYMEX WTI CMA		(2,449)		—
	$	(1,910,040)	$	(890,580)

Net Fair Value of Derivatives	$	(1,534,675)	$	(487,548)

Table of Contents

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 March 31,
	2025		2024
Fair value of (liability) asset, beginning of the period	$	(487,548)	$	1,100,255
Loss on derivative contracts included in earnings		(1,462,170)		(100,726)
Settlement of commodity derivative contracts		415,043		(488,285)
Fair value of (liability) asset, end of the period	$	(1,534,675)	$	511,244

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:


	Three Months Ended		Year ended
		March 31,		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		47,098		183,434
Balance end of period	$	3,716,029	$	3,652,296

17. Fair Value Measurements

The methodologies used to determine the fair value of our financial assets and liabilities at March 31, 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 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.


	March 31, 2025
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	375,365	$	—	$	(375,365)	$	—
Cash equivalents	$	260,135	$	—	$	—	$	—	$	260,135
Liabilities
Derivative contracts	$	—	$	1,910,040	$	—	$	(375,365)	$	1,534,675

Table of Contents

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

Table of Contents

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 March 31, 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 March 31, 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 March 31, 2025 in the project (including undeveloped leasehold) are $38.6 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 March 31, 2025 in the project (including undeveloped leasehold) are $2.9 million.

Table of Contents

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 March 31, 2025 are $8.3 million.

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

Three months ended March 31, 2025 Highlights

Operational Highlights

Marcellus Shale – Pennsylvania

●

During the three months ended March 31, 2025, Epsilon's realized natural gas price was $3.92 per Mcf, a 69% increase over the three months ended March 31, 2024.

●

During the three months ended March 31, 2025, Epsilon’s net revenue interest natural gas production was 2.6 Bcf, a 63% increase over the three months ended March 31, 2024.

●

Gathered and delivered 11.6 Bcf gross (4.1 net to Epsilon's interest) during the three months ended March 31, 2025, or 129 MMcf/d through the Auburn Gas Gathering System.

Permian Basin – Texas and New Mexico

●

During the three months ended March 31, 2025, Epsilon's realized price for all Permian Basin production was $54.60 per Boe (87% liquids), a 2% increase over the three months ended March 31, 2024.

●

Total net revenue interest production for the three months ended March 31, 2025, which included oil, natural gas liquids, and natural gas, was 61.9 Mboe compared to 52.3 Mboe during the same period in 2024, an 18% increase.

Anadarko, NW Stack Trend – Oklahoma

●

During the three months ended March 31, 2025, Epsilon's realized price for all Oklahoma production was $5.29 per Mcfe (60% natural gas), a 17% increase from the three months ended March 31, 2024.

●

Total net revenue interest production for the three months ended March 31, 2025 included natural gas, oil and other liquids and was 0.09 Bcfe, a 18% decrease from the same period in 2024.

Western Canadian Sedimentary Basin—Alberta, Canada

●

During the three months ended March 31, 2025, Epsilon’s realized price for Canada oil production was $51.27 per Bbl.

●

Total oil sales for the three months ended March 31, 2025 were 1.8 MBbl.

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.

Table of Contents

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 months ended March 31, 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 March 31,
	2025		2024
Net income	$	4,016,034	$	1,506,896
Add Back:
Interest income, net		(3,088)		(257,512)
Income tax expense		1,670,194		54,050
Depreciation, depletion, amortization, and accretion		3,475,857		2,380,426
Impairment expense		6,669		—
Stock based compensation expense		385,838		321,569
Loss on derivative contracts net of cash received or paid on settlement		1,047,127		589,011
Foreign currency translation loss		10,289		570
Adjusted EBITDA	$	10,608,920	$	4,595,010

Table of Contents

Results of Operations

Net Operating Revenues

For the three months ended March 31, 2025 revenues increased $8.2 million, or 102%, to $16.2 million from $8.0 million during the same period of 2024.

Revenue and volume statistics for the three months ended March 31, 2025 and 2024 were as follows:


	Three months ended
	March 31,
	2025		2024
Revenues
Pennsylvania
Natural gas revenue	$	10,327,894	$	2,758,108
Volume (MMcf)		2,637		1,557
Avg. Price ($/Mcf)	$	3.92	$	1.77
Gathering system revenue (net of elimination)	$	1,892,350	$	1,935,698
Total PA Revenues	$	12,220,244	$	4,693,806
Permian Basin
Natural gas revenue	$	78,339	$	41,578
Volume (MMcf)		50		43
Avg. Price ($/Mcf)	$	1.57	$	0.96
Natural gas liquids revenue	$	284,961	$	259,914
Volume (MBOE)		12.1		11.4
Avg. Price ($/Bbl)	$	23.56	$	22.71
Oil and condensate revenue	$	3,019,495	$	2,486,513
Volume (MBbl)		41.5		33.7
Avg. Price ($/Bbl)	$	72.72	$	73.87
Total Permian Basin Revenues	$	3,382,795	$	2,788,005
Oklahoma
Natural gas revenue	$	207,340	$	163,293
Volume (MMcf)		53		66
Avg. Price ($/Mcf)	$	3.94	$	2.47
Natural gas liquids revenue	$	102,289	$	113,070
Volume (MBOE)		3.7		4.7
Avg. Price ($/Bbl)	$	27.68	$	24.26
Oil and condensate revenue	$	157,937	$	228,569
Volume (MBbl)		2.2		3.0
Avg. Price ($/Bbl)	$	70.35	$	77.04
Total OK Revenues	$	467,566	$	504,932
Canada
Oil and condensate revenue	$	92,535	$	—
Volume (MBbl)		1.8		—
Avg. Price ($/Bbl)	$	51.27	$	—
Total Canada Revenues	$	92,535	$	—
Total Revenues	$	16,163,140	$	7,986,743

Upstream natural gas revenue for the three months ended March 31, 2025 increased by $7.6 million, or 258%, over the same period in 2024. An increase of $1.9 million was due to higher natural gas prices and an increase of $5.7 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 three months ended March 31, 2025 was constant with the same period in 2024, increasing by $0.01 million, or 4%.

Table of Contents

Upstream oil and condensate revenue for the three months ended March 31, 2025 increased by $0.6 million, or 20% over the same period in 2024. An increase of $0.7 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 $0.1 million was due to slightly lower prices.

Gathering system revenue for the three months ended March 31, 2025 was relatively flat compared with the same period in 2024, decreasing $0.04 million, or 2%. Revenues derived from transporting and compressing our production, which have been eliminated from gathering system revenues amounted to $0.6 million for the three months ended March 31, 2025.

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 months ended March 31, 2025 and 2024:


	Three months ended March 31,
	2025		2024
Lease operating costs (net of elimination)	$	2,755,898	$	1,768,462
Gathering system operating costs		552,651		552,570
	$	3,308,549	$	2,321,032

Upstream operating costs—Total $/Mcfe	$	0.89	$	0.89
Gathering system operating costs $/Mcf	$	0.13	$	0.11

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 three months ended March 31, 2025 these costs increased by $1.0 million, or 56%, 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 months ended March 31, 2025, gathering system operating costs were constant compared to the same period in 2024.

The higher gathering system unit operating costs in the three months ending March 31, 2025 were primarily due to a 17% decrease in throughput volumes.

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

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

Table of Contents

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 months ended March 31, 2025 increased by $1.1 million, or 46% from the same period in 2024. This increase was a result of higher produced volumes in Pennsylvania and the Permian Basin.

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 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 months ended March 31, 2025, the Company recorded an impairment of $0.01 million for costs on the Killam project well drilled during 2024 that was deemed non-commercial. For the three months ended March 31, 2024, there was no impairment.

General and Administrative (“G&A”)

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.

G&A expenses for the three months ended March 31, 2025 and 2024 increased by $0.3 million, or 17% from the same period in 2024. This was primarily due to higher compensation expenses.

Interest Income

Interest income for the three months ended March 31, 2025 and 2024 decreased by $0.3 million, or 94% from the same period in 2024. This was primarily due to a reduction in the balance of cash and short term investments.

Interest Expense

Table of Contents

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

Interest expense during the three months ended March 31, 2025 and 2024 was relatively flat.

Loss on Derivative Contracts

For the three months ended March 31, 2025 and 2024, Epsilon had NYMEX HH Natural Gas futures swaps, Tennessee Gas Pipeline Zone 4 basis swaps, 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 March 31, 2025, we paid net cash settlements of $415,043. During the three months ended March 31, 2024, we received net cash settlements of $488,285.

For the three months ended March 31, 2025, realized losses on derivative contracts increased by $1.4 million. This increase was primarily the result of a significant increase in Henry Hub prices during the quarter.

Capital Resources and Liquidity

Cash Flow

The primary source of cash for Epsilon during the three months ended March 31, 2025 was funds generated from operations. The primary source of cash for Epsilon during the three months ended March 31, 2024 was funds generated from operations and proceeds from short term investments. The primary uses of cash for the three months ended March 31, 2025 were the development of upstream properties and the distribution of dividends. The primary uses of cash for the three months ended March 31, 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 March 31, 2025, we had a working capital surplus of $6.2 million, a decrease of $0.9 million from the $7.1 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.

Three months ended March 31, 2025 compared to 2024

During the three months ended March 31, 2025, $8.6 million was provided by the Company’s operating activities, compared to $3.7 million during the same period in 2024, representing a 133% increase. The increase was primarily due to higher produced volumes and realized prices in Pennsylvania.

The Company used $6.8 million and $11.8 million of cash for investing activities during the three months ended March 31, 2025 and 2024, respectively. During the three months ended March 31, 2025, the Company had net investments of $6.8 million primarily in well costs and leasehold (drilling carry) in Pennsylvania, Texas, and Canada. During the three months ended March 31, 2024, the Company had net investments of $18.5 million in leasehold and well costs in Pennsylvania and Texas offset by net proceeds of $6.7 million in U.S. Treasury Bills.

The Company used $1.4 million and $2.6 million of cash for financing activities during the three months ended March 31, 2025 and 2024, respectively. This was spent on dividend payments and the repurchase of shares of common stock.

Table of Contents

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)

Repurchase Transactions

During the three months ended March 31, 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.

Table of Contents

At March 31, 2025, Epsilon’s outstanding natural gas and crude oil commodity contracts consisted of the following:


		Weighted Average
	Volume	Price ($/MMbtu)		Fair Value of Asset
Derivative Type	(MMbtu)	Swaps		March 31, 2025
2025
NYMEX Henry Hub swap	1,564,000	$	3.21	$	(1,872,793)
Tennessee Z4 basis swap	1,564,000		(0.95)		250,785
	3,128,000			$	(1,622,008)


				Fair Value
	Volume	Weighted Average		March 31,
Derivative Type	(Bbl)	Price ($/Bbl)		2025
2025
Crude Oil NYMEX WTI CMA	47,000	$	71.17	$	87,333
	47,000			$	87,333

Contractual Obligations

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of March 31, 2025, the Company has no commitments for capital expenditures and has 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.

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 March 31, 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

Table of Contents

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 March 31, 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 March 31, 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.

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

For the three months ended March 31, 2025, no shares had been repurchased.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not applicable.

Table of Contents

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

Not applicable.

Table of Contents

ITEM 6. —EXHIBITS


Exhibit No.		Description of Exhibit

31.1		Sarbanes-Oxley Section 302 certification of Principal Executive Officer.

31.2		Sarbanes-Oxley Section 302 certification of Principal Financial Officer.

32.1		Sarbanes-Oxley Section 906 certification of Principal Executive Officer.

32.2		Sarbanes-Oxley Section 906 certification of Principal Financial Officer.

101.INS		Inline XBRL Instance Document.

101.SCH		Inline XBRL Schema Document.

101.CAL		Inline XBRL Calculation Linkbase Document.

101.DEF		Inline XBRL Definition Linkbase Document.

101.LAB		Inline XBRL Labels Linkbase Document.

101.PRE		Inline XBRL Presentation Linkbase Document.

104		Cover Page Interactive Data File (embedded within the Inline XBRL document)

SIGNATURES

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


Epsilon Energy Ltd.
(Registrant)

Date: May 14, 2025	By:	/s/ J. Andrew Williamson
		J. Andrew Williamson
		Chief Financial Officer