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 ~~September~~March 3031, ~~2024~~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 ~~November~~May 613, ~~2024~~2025, there were 2122,~~857~~017,~~326~~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 (Loss)		6
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		98
Notes to the Unaudited Condensed Consolidated Financial Statements
1.	Description of Business	109
2.	Basis of Preparation	109
	Interim Financial Statements	109
	Principles of Consolidation	109
	Use of Estimates	109
	Recently Issued Accounting Standards	109
3.	Cash, Cash Equivalents, and Restricted Cash	1210
4.	Short Term Investments	1210
5.	Property and Equipment	1311
	Property Impairment	1311
6.	Revolving Line of Credit	1412
7.	Shareholders’ Equity	1412
8.	Revenue Recognition	1713
9.	~~Income~~Accumulated ~~Taxes~~Other Comprehensive Income	1815
10.	~~Commitments~~Income ~~and Contingencies~~Taxes	1815
11.	~~Leases~~Commitments and Contingencies	1916
12.	~~Net Income Per Share~~Leases	1916
13.	~~Operating~~Net ~~Segments~~Income Per Share	2017
14.	~~Commodity~~Operating ~~Risk Management Activities~~Segments	2317
	Commodity Price Risks	23
15.	Commodity Risk Management Activities	20
	Commodity ~~Derivative~~Price ~~Contracts~~Risks	2320
15.	Asset Retirement Obligations	24
	Commodity Derivative Contracts	20
16.	~~Fair~~Asset ~~Value~~Retirement ~~Measurements~~Obligations	2421
17.	~~Current~~Fair ~~Expected~~Value ~~Credit Loss~~Measurements	2521
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		26

	Overview	26
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		23
	~~Business Strategy~~Overview	2623
	~~Operational~~Business ~~Highlights~~Strategy	2723
	~~Non-GAAP~~Operational ~~Financial Measures-Adjusted EBITDA~~Highlights	2824
	~~Net~~Non-GAAP ~~Operating~~Financial ~~Revenues~~Measures-Adjusted EBITDA	2924
	Net Operating ~~Costs~~Revenues	3026
	~~Depletion,~~Operating ~~Depreciation, Amortization and Accretion~~Costs	3027
	~~General~~Depletion, Depreciation, Amortization and ~~Administrative~~Accretion	3127
	~~Interest~~General ~~Income~~and Administrative	3128
	Interest ~~Expense~~Income	3128
	~~Loss~~Interest ~~on Derivative Contracts~~Expense	3228

Table of Contents

	~~Capital~~Loss ~~Resources~~on ~~and~~Derivative ~~Liquidity~~Contracts	3229
	~~Cash~~Capital ~~Flow~~Resources and Liquidity	3229
	~~Credit~~Cash ~~Agreement~~Flow	3329
	~~Repurchase~~Credit ~~Transactions~~Agreement	3330
	~~Derivative~~Repurchase Transactions	3330
	~~Contractual~~Derivative ~~Obligations~~Transactions	3430
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		34
	Contractual Obligations	31
	Gathering System Revenue Risk	34
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		31
	~~Interest~~Gathering ~~Rate~~System Revenue Risk	3431
	~~Derivative~~Interest ~~Contracts~~Rate Risk	3531
ITEM 4. CONTROLS AND PROCEDURES		35
	Derivative Contracts	31
	Disclosure Controls and Procedures	35
ITEM 4. CONTROLS AND PROCEDURES		32
	~~Changes~~Disclosure inControls ~~Internal~~and ~~Control Over Financial Reporting~~Procedures	3532
	~~Inherent~~Changes ~~Limitations~~in onInternal ~~Effectiveness~~Control ofOver ~~Controls~~Financial Reporting	3532
PART II OTHER INFORMATION		35
	Inherent Limitations on Effectiveness of Controls	32
ITEM 1. LEGAL PROCEEDINGS		35
PART II OTHER INFORMATION		32
ITEM 1A. RISK FACTORS		35
ITEM 1. LEGAL PROCEEDINGS		32
ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS		36
ITEM 1A. RISK FACTORS		32
ITEM 3. DEFAULTS UPON SENIOR SECURITIES		36
ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS		32
ITEM 4. MINE SAFETY DISCLOSURES		36
ITEM 3. DEFAULTS UPON SENIOR SECURITIES		32
ITEM 5. OTHER INFORMATION		36
ITEM 4. MINE SAFETY DISCLOSURES		33
ITEM 6. EXHIBITS		37
ITEM 5. OTHER INFORMATION		33
SIGNATURES		37
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, ~~2023~~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, ~~2023~~2024. Our Annual Report on Form 10-K for the year ended December 31, ~~2023~~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


	~~September~~March 3031,		December 31,
	~~2024~~2025		~~2023~~2024
ASSETS
Current assets
Cash and cash equivalents	$	86,~~304~~892,~~971~~735	$	136,~~403~~519,~~628~~793
Accounts receivable		48,~~470~~003,~~017~~517		65,~~015~~843,~~448~~722
Short term investments		—		18,775,106
Prepaid income taxes		—		975,963
Fair value of derivatives		150,121		1,219,025
Other current assets		647,295		792,041
Prepaid income taxes		1,020,179		952,301
Total current assets		15,543,547		14,131,519
Other current assets		865,841		763,288
Total current assets		14,811,129		41,128,796
Non-current assets
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties		~~190~~194,~~162~~811,~~954~~616		~~160~~191,~~263~~879,~~511~~210
Unproved properties		2833,~~292~~425,~~321~~087		2528,~~504~~364,~~873~~186
Accumulated depletion, depreciation, amortization and impairment		(~~119~~126,~~981~~370,~~434~~072)		(~~113~~123,~~708~~281,~~210~~395)
Total oil and gas properties, net		98101,~~473~~866,~~841~~631		7296,~~060~~962,~~174~~001
Gathering system		4243,~~988~~176,~~092~~418		4243,~~738~~116,~~273~~371
Accumulated depletion, depreciation, amortization and impairment		(36,~~221~~777,~~366~~152)		(3536,~~539~~449,~~996~~511)
Total gathering system, net		6,~~766~~399,~~726~~266		76,~~198~~666,~~277~~860
Land		637,764		637,764
Buildings and other property and equipment, net		~~269~~246,~~133~~894		~~291~~259,~~807~~335
Total property and equipment, net		~~106~~109,~~147~~150,~~464~~555		80104,~~188~~525,~~022~~960
Other assets:
Operating lease right-of-use assets, long term		~~368~~318,~~564~~604		~~441~~344,~~987~~589
Restricted cash		470,000		470,000
Prepaid drilling costs		—22,581		1982,~~813,808~~717
Total non-current assets		~~106~~109,~~986~~961,~~028~~740		82106,~~913~~323,~~817~~266
Total assets	$	~~121~~125,~~797~~505,~~157~~287	$	~~124~~120,~~042~~454,~~613~~785

LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities
Accounts payable trade	$	2,~~220~~013,~~394~~172	$	32,~~236~~334,~~871~~732
Gathering fees payable		~~844~~1,~~163~~651,164		1997,~~136,237~~016
Royalties payable		12,~~149~~019,~~330~~819		1,~~422~~400,~~898~~976
Accrued capital expenditures		1,758,133		696,761
Income taxes payable		924,905		—
Accrued compensation		589,620		636,295
Accrued capital expenditures		309,630		572,079
Other accrued liabilities		599,949		561,537
Accrued compensation		284,905		695,018
Fair value of derivatives		50,702		118,770
Other accrued liabilities		481,770		371,503
Operating lease liabilities		112,502		86,473
Fair value of derivatives		1,534,675		487,548
Total current liabilities		7,324,793		7,895,842
Operating lease liabilities		121,293		121,135
Total current liabilities		9,341,333		6,980,007
Non-current liabilities
Asset retirement obligations		3,~~590~~716,~~017~~029		3,~~502~~652,~~952~~296
Deferred income taxes		12,~~138~~417,~~030~~125		1112,~~553~~738,~~943~~577
Operating lease liabilities, long term		~~385~~326,~~653~~527		~~476~~355,~~911~~776
Total non-current liabilities		16,~~113~~459,~~700~~681		1516,~~533~~746,~~806~~649
Total liabilities		2325,~~438~~801,~~493~~014		23,~~429~~726,~~648~~656
Commitments and contingencies (Note 10)
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 21,973,687 shares issued and 21,848,687 shares outstanding at September 30, 2024 and 22,222,722 issued and 22,151,848 shares outstanding at December 31, 2023		116,708,531		118,272,565
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
Treasury shares, at cost, 125,000 at September 30, 2024 and 70,874 at December 31, 2023		(627,500)		(360,326)
Additional paid-in capital		12,504,745		12,118,907
Additional paid-in capital		11,818,758		10,874,491
Accumulated deficit		(38,864,654)		(41,505,076)
Accumulated deficit		(39,374,242)		(37,946,042)
Accumulated other comprehensive income		9,983,151		10,033,267
Accumulated other comprehensive income		9,833,117		9,772,277
Total shareholders' equity		99,704,273		96,728,129
Total shareholders' equity		98,358,664		100,612,965
Total liabilities and shareholders' equity	$	125,505,287	$	120,454,785
Total liabilities and shareholders' equity	$	121,797,157	$	124,042,613

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 ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Revenues from contracts with customers:

Gas, oil, NGL, and condensate revenue

614,~~203~~270,~~953~~790

36,~~241~~051,~~531~~045

~~18,118,368~~

~~14,509,184~~

Gas gathering and compression revenue

1,~~083~~892,~~988~~350

31,~~068~~935,~~996~~698

~~4,464,134~~

~~7,657,755~~

Total revenue

716,~~287~~163,~~941~~140

67,~~310~~986,~~527~~743

~~22,582,502~~

~~22,166,939~~

Operating costs and expenses:

Lease operating expenses

2,~~099~~755,~~501~~898

1,~~559~~768,~~957~~462

~~5,517,830~~

~~4,404,757~~

Gathering system operating expenses

~~490~~552,~~325~~651

~~631~~552,~~725~~570

~~1,692,862~~

~~1,854,000~~

Depletion, depreciation, amortization, and accretion

23,~~698~~475,~~812~~857

12,~~392~~380,~~032~~426

~~7,127,641~~

~~4,780,766~~

Loss on sale of oil and gas properties

—

1,449,871

Impairment expense

6,669

—

General and administrative expenses:

Stock based compensation expense

~~309~~385,~~109~~838

~~439~~321,~~653~~569

~~944,267~~

~~799,149~~

Other general and administrative expenses

1,~~449~~818,~~576~~418

1,~~540~~559,~~358~~023

~~4,486,814~~

~~5,160,757~~

Total operating costs and expenses

78,~~047~~995,~~323~~331

56,~~563~~582,~~725~~050

~~19,769,414~~

~~18,449,300~~

Operating income

~~240~~7,~~618~~167,809

~~746~~1,~~802~~404,693

~~2,813,088~~

~~3,717,639~~

Other income (expense):

Interest income

9615,~~220~~299

~~384~~266,~~732~~272

~~471,435~~

~~1,308,695~~

Interest expense

(5312,~~125~~211)

(8,760)

~~(70,644)~~

~~(71,619)~~

Gain (loss) on derivative contracts

440,712

(24,303)

245,095

1,672,535

Loss on derivative contracts

(1,462,170)

(100,726)

Other income, net

9,994

468

111,067

5,169

Other expense

(22,499)

(533)

Other income, net

493,801

352,137

756,953

2,914,780

Other (expense) income, net

(1,481,581)

156,253

Net income before income tax expense

~~734~~5,~~419~~686,228

1,~~098~~560,~~939~~946

~~3,570,041~~

~~6,632,419~~

Income tax expense

~~368~~1,~~398~~670,194

~~710~~54,~~164~~050

~~881,464~~

~~2,283,228~~

NET INCOME

~~366~~4,~~021~~016,034

~~388~~1,~~775~~506,896

~~2,688,577~~

~~4,349,191~~

Currency translation adjustments

39(50,~~845~~116)

~~(846)~~364

~~62,438~~

~~(2,317)~~

Unrealized gain (loss) on securities

—

24,641

(1,598)

(22,365)

Unrealized loss on securities

—

(4,609)

NET COMPREHENSIVE INCOME

~~405~~3,~~866~~965,918

~~412~~1,~~570~~502,651

~~2,749,417~~

~~4,324,509~~

Net income per share, basic

0.0218

0.0207

~~0.12~~

~~0.19~~

Net income per share, diluted

0.0218

0.0207

~~0.12~~

~~0.19~~

Weighted average number of shares outstanding, basic

2122,~~948~~008,~~519~~766

2221,~~118~~994,~~984~~207

~~21,954,803~~

~~22,616,539~~

Weighted average number of shares outstanding, diluted

22,~~155~~109,~~292~~819

2221,~~178~~994,~~686~~207

~~22,000,881~~

~~22,631,550~~

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, 2024	22,222,722	$	118,272,565	(70,874)	$	(360,326)	$	10,874,491	$	9,772,277	$	(37,946,042)	$	100,612,965
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	—		—	—		—		—		—		14,~~506~~016,~~896~~034		14,~~506~~016,~~896~~034
Dividends paid	—		—	—		—		—		—		(1,~~370~~375,~~409~~612)		(1,~~370~~375,~~409~~612)
Stock-based compensation expense	—		—	—		—		~~321~~385,~~569~~838		—		—		~~321~~385,~~569~~838
Buyback of common shares	—		—	(248,700)		(1,203,708)		—		—		—		(1,203,708)
Other comprehensive loss	—		—	—		—		—		(50,116)		—		(50,116)
Retirement of treasury shares	(319,574)		(1,564,034)	319,574		1,564,034		—		—		—		—
Balance at March 31, 2025	22,008,766	$	116,081,031	—	$	—	$	12,504,745	$	9,983,151	$	(38,864,654)	$	99,704,273
Vesting of shares of restricted stock	10,054		—	—		—		—		—		—		—
Other comprehensive loss	—		—	—		—		—		(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 loss	—		—	—		—		—		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
Net income	—		—	—		—		—		—		366,021		366,021
Dividends paid	—		—	—		—		—		—		(1,374,428)		(1,374,428)
Stock-based compensation expense	—		—	—		—		309,109		—		—		309,109
Buyback of common shares	—		—	(125,000)		(627,500)		—		—		—		(627,500)
Vesting of shares of restricted stock	51,837		—	—		—		—		—		—		—
Other comprehensive income	—		—	—		—		—		39,845		—		39,845
Balance at September 30, 2024	21,973,687	$	116,708,531	(125,000)	$	(627,500)		11,818,758	$	9,833,117	$	(39,374,242)	$	98,358,664

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


									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

Table of Contents


									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, 2023	23,117,144	$	123,904,965	—	$	—	$	9,856,229	$	9,774,551	$	(39,290,540)	$	104,245,205
Net income	—		—	—		—		—		—		3,529,827		3,529,827
Dividends paid	—		—	—		—		—		—		(1,412,455)		(1,412,455)
Stock-based compensation expense	—		—	—		—		179,748		—		—		179,748
Buyback of common shares	—		—	(237,920)		(1,367,425)		—		—		—		(1,367,425)
Retirement of treasury shares	(190,700)		(1,115,306)	190,700		1,115,306		—		—		—		—
Other comprehensive income	—		—	—		—		—		(2,600)		—		(2,600)
Balance at March 31, 2023	22,926,444	$	122,789,659	(47,220)	$	(252,119)	$	10,035,977	$	9,771,951	$	(37,173,168)	$	105,172,300
Net income	—		—	—		—		—		—		430,589		430,589
Dividends paid	—		—	—		—		—		—		(1,416,147)		(1,416,147)
Stock-based compensation expense	—		—	—		—		179,748		—		—		179,748
Buyback of common shares	—		—	(325,055)		(1,687,350)		—		—		—		(1,687,350)
Retirement of treasury shares	(277,154)		(1,441,655)	277,154		1,441,655		—		—		—		—
Other comprehensive loss	—		—	—		—		—		(45,877)		—		(45,877)
Balance at June 30, 2023	22,649,290	$	121,348,004	(95,121)	$	(497,814)	$	10,215,725	$	9,726,074	$	(38,158,726)	$	102,633,263
Net income	—		—	—		—		—		—		388,775		388,775
Dividends paid	—		—	—		—		—		—		(1,388,869)		(1,388,869)
Stock-based compensation expense	—		—	—		—		439,653		—		—		439,653
Buyback of common shares	—		—	(525,000)		(2,640,500)		—		—		—		(2,640,500)
Retirement of treasury shares	(620,121)		(3,138,314)	620,121		3,138,314		—		—		—		—
Vesting of shares of restricted stock	97,631		—	—		—		—		—		—		—
Other comprehensive loss	—		—	—		—		—		23,795		—		23,795
Balance at September 30, 2023	22,126,800	$	118,209,690	—	$	—	$	10,655,378	$	9,749,869	$	(39,158,820)	$	99,456,117

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

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EPSILON ENERGY LTD.

Unaudited Condensed Consolidated Statements of Cash Flows


	~~Nine~~Three months ended ~~September~~March 3031,
	~~2024~~2025		~~2023~~2024
Cash flows from operating activities:
Net income	$	24,~~688~~016,~~577~~034	$	41,~~349~~506,~~191~~896
Adjustments to reconcile net income to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion		73,~~127~~475,~~641~~857		42,~~780~~380,~~766~~426
Accretion of discount on available for sale securities		(297,637)		(574,341)
Impairment expense		6,669		—
Gain on available for sale securities		—		(60,494)
Accretion of discount on available for sale securities		—		(216,180)
Loss on sale of oil and gas properties		—		1,449,871
Loss on derivative contracts		1,462,170		100,726
Gain on derivative contracts		(245,095)		(1,672,535)
Settlement (paid) received on derivative contracts		(415,043)		488,285
Settlement received on derivative contracts		1,245,931		2,979,128
Settlement of asset retirement obligation		(1,600)		(1,653)
Settlement of asset retirement obligation		(88,992)		(3,482)
Stock-based compensation expense		385,838		321,569
Stock-based compensation expense		944,267		799,149
Deferred income tax expense (benefit)		(321,452)		(22,993)
Deferred income tax (benefit) expense		584,088		1,188,059
Changes in assets and liabilities:
Accounts receivable		1(2,~~545~~159,~~431~~795)		3953,~~195,108~~714
Prepaid income taxes		~~(67~~978,~~878)~~542		(~~814~~68,~~694~~401)
Other assets and liabilities		~~(94~~141,~~360)~~640		~~(67~~146,~~008)~~477
Accounts payable, royalties payable and other accrued liabilities		(1,520,707)		(1,191,558)
Accounts payable, royalties payable, gathering fees payable, and other accrued liabilities		91,390		(1,897,438)
Net cash provided by operating activities		11,821,266		14,357,160
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		(25,~~787~~060,~~448~~901)		(83,~~017~~088,~~412~~198)
Additions to proved oil and gas properties		(292,~~041~~578,~~344~~866)		(717,~~860~~226,~~073~~449)
Additions to gathering system properties		(76104,~~625~~275)		(5222,~~069~~650)
Additions to land, buildings and property and equipment		~~(13,912)~~—		(497,~~689~~681)
Purchases of short term investments - held to maturity		—		(32,812,974)
Purchases of short term investments - available for sale		—		(4,045,785)
Purchases of short term investments - available for sale		(4,045,785)		—
Proceeds from short term investments - held to maturity		—		10,794,285
Proceeds from sales and maturities of short term investments		23,116,930		14,554,976
Prepaid drilling costs		960,136		1,813,808
Proceeds from sale of oil and gas properties		—		12,498
Net cash used in investing activities		(6,783,906)		(11,782,670)
Prepaid drilling costs		1,813,808		(2,891,250)
Net cash used in investing activities		(11,034,376)		(37,115,993)
Cash flows from financing activities:
Buyback of common shares		~~(1,831,208)~~—		(51,~~695~~203,~~275~~708)
Dividends paid		(41,~~116~~375,~~777~~612)		(41,~~217~~370,~~471~~409)
Debt issuance costs		—		(140,000)
Net cash used in financing activities		(1,375,612)		(2,574,117)
Net cash used in financing activities		(5,947,985)		(10,052,746)
Effect of currency rates on cash, cash equivalents, and restricted cash		(50,116)		364
Effect of currency rates on cash, cash equivalents, and restricted cash		62,438		(2,317)
Decrease in cash, cash equivalents, and restricted cash		372,942		(10,664,995)
Decrease in cash, cash equivalents, and restricted cash		(5,098,657)		(32,813,896)
Cash, cash equivalents, and restricted cash, beginning of period		6,989,793		13,873,628
Cash, cash equivalents, and restricted cash, beginning of period		13,873,628		45,806,947
Cash, cash equivalents, and restricted cash, end of period	$	7,362,735	$	3,208,633
Cash, cash equivalents, and restricted cash, end of period	$	8,774,971	$	12,993,051

Supplemental cash flow disclosures:
Income taxes paid	$	4,000	$	1,442,304
Income tax paid - federal	$	80,000	$	—
Interest paid	$	16,832	$	88,835
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 and accrued liabilities	$	818,504	$	41,947
Change in proved properties accrued in accounts payable	$	341,974	$	2,946,528
Change in gathering system accrued in accounts payable and accrued liabilities	$	173,193	$	3,441
Change in gathering system accrued in accounts payable	$	(44,228)	$	(3,624)
Asset retirement obligation asset additions and adjustments	$	3918,~~597~~235	$	416,~~640~~372

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

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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 ~~ABCA.~~Alberta ~~Epsilon~~Business isCorporations ~~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~~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, ~~2023~~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

~~The~~In ~~Company~~December 2023, anthe ~~emerging~~FASB ~~growth~~issued ~~company~~ASU ~~(“EGC”)~~No. 2023-09, ~~has~~Income ~~elected~~Taxes (Topic 740): Improvements to ~~take~~Income ~~advantage~~Tax ofDisclosures, ~~the~~which ~~benefits~~requires ofpublic ~~the~~entities, ~~extended~~on ~~transition~~an ~~period~~annual ~~provided~~basis, ~~for~~to indisclose ~~Section~~disaggregated 7(information about a~~)(2)(B)~~ ofreporting ~~the~~entity’s ~~Securities~~effective ~~Act~~tax rate reconciliation, ~~for~~using ~~complying~~both ~~with~~percentages ~~new~~and orreporting ~~revised~~currency ~~accounting~~amounts ~~standards~~for ~~which~~specific ~~allows~~standardized ~~the~~categories, ~~Company~~as towell ~~defer~~as ~~adoption~~disclosure of ~~certain~~income ~~accounting~~taxes ~~standards~~paid ~~until~~disaggregated ~~those~~by ~~standards~~jurisdiction. ~~would~~The ~~otherwise~~amendments ~~apply~~will tobe ~~private~~effective ~~companies~~for fiscal years beginning after December 15, 2024, with early adoption permitted. The Company is evaluating the impact of

In June 2016 the FASB issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments, which removes the thresholds that companies apply to measure credit losses on financial instruments measured at amortized cost, such as loans, receivables, and held-to-maturity debt securities. Under current U.S. GAAP, companies generally recognize credit losses when it is probable that the loss has been incurred. The revised guidance removes all recognition thresholds and requires companies to recognize an allowance for credit losses for the difference between the amortized cost basis of a financial instrument and the amount of amortized cost that the 9

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

~~Company~~this ~~expects~~new tostandard ~~collect~~and ~~over~~believes that the ~~instrument’s~~adoption ~~contractual~~will ~~life.~~result ~~Epsilon~~in ~~adopted~~additional ~~ASU~~disclosures, ~~2016-13~~but aswill ofnot ~~January~~have 1,any ~~2023.~~other ~~There was no~~ impact ~~from~~on ~~the~~its ~~adoption~~consolidated offinancial ~~this ASU~~statements.

In ~~2020~~March 2024, the FASB issued ASU ~~2020~~No. 2024-0401, ~~Facilitation~~Compensation of– ~~the~~Stock ~~Effects~~Compensation of(Topic ~~Reference~~718): ~~Rate~~Scope ~~Reform~~Applications ~~on Financial Reporting, which, for a limited period~~ of ~~time,~~Profits ~~adds~~Interest ~~ASC 848 to the Codification providing entities with certain practical expedients~~ and ~~exceptions~~Similar ~~from~~Awards ~~applying~~(“ASU ~~modification accounting if certain criteria are met~~2024-01”). The amendments ~~are designed to reduce operational challenges that entities will face~~ in ~~applying~~ASU ~~modification~~2024-01 ~~accounting~~improve toits ~~all~~overall ~~contracts~~clarity ~~that~~and ~~will~~operability bewithout ~~revised~~changing ~~due~~the ~~to reference rate reform. The~~ guidance ~~in ASC 848 was triggered by the pending discontinuation of certain benchmark reference rates~~ and, inadding ~~some~~illustrative ~~cases,~~examples ~~their replacement by new rates that are more observable or transaction-based and, therefore, less susceptible~~ to ~~manipulation,~~determine ~~than~~whether ~~certain~~profits interest~~-rate~~ ~~benchmark~~award ~~reference~~should ~~rates~~be ~~commonly~~accounted ~~used~~for ~~today,~~in ~~including~~accordance ~~the~~with ~~London~~Topic ~~Interbank Offered Rate (LIBOR)~~718. ~~This~~The ~~process~~Company ofhas ~~reference rate reform will require entities to modify certain contracts by removing the discontinued rates and including new rates. Epsilon~~ adopted ASU ~~2020~~No. 2024-0401 as of January 1, ~~2023~~2025. There was no impact ~~from~~as a result of the adoption of this ASU.

In ~~July~~November ~~2023~~2024, the ~~Financial Accounting Standards Board (“~~FASB”) issued ~~Accounting Standards Update (“~~ASU”) ~~No. 2023~~2024-033 to"Income ~~amend~~Statement ~~various~~– ~~SEC~~Reporting ~~paragraphs~~Comprehensive inIncome ~~the~~– ~~Accounting~~Expense ~~Standards~~Disaggregation ~~Codification~~Disclosures." ~~(“ASC”)~~The toASU ~~primarily~~will ~~reflect~~improve the ~~issuance~~decision ofusefulness ~~SEC~~for ~~Staff~~investors ~~Accounting~~by ~~Bulletin~~requiring ~~No.~~public ~~120.~~business ~~ASU~~entities ~~No.~~to ~~2023-03,~~disclose ~~“Presentation~~more ofdetailed ~~Financial~~information ~~Statements~~about ~~(Topic~~their ~~205),~~expenses ~~Income~~such ~~Statement - Reporting~~as ~~Comprehensive Income~~ (~~Topic 220~~a), ~~Distinguishing~~inventory ~~Liabilities~~and ~~from~~manufacturing ~~Equity~~expense, (~~Topic 480~~b), ~~Equity~~employee ~~(Topic 505)~~compensation, ~~and Compensation - Stock Compensation~~ (~~Topic 718~~c): ~~Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 120 (“SAB 120”)~~depreciation, ~~SEC Staff Announcement at the March 24, 2022 Emerging Issues Task Force~~ (~~“EITF”~~d) ~~Meeting,~~intangible ~~and~~asset ~~Staff Accounting Bulletin Topic 6.B~~amortization, ~~Accounting Series Release 280 - General Revision of Regulation S-X: Income or Loss Applicable to Common Stock~~etc.” ~~ASU~~The ~~2023-03~~amendments ~~amends~~will ~~the~~be ~~ASC~~effective for ~~SEC~~fiscal ~~updates~~years ~~pursuant~~beginning toafter ~~SEC~~December ~~Staff~~15, ~~Accounting~~2026, ~~Bulletin~~and ~~No.~~interim ~~120;~~periods ~~SEC~~within ~~Staff~~fiscal ~~Announcement~~years atbeginning ~~the~~after ~~March~~December 2415, ~~2022~~2027, ~~EITF~~with ~~Meeting;~~early ~~and~~adoption ~~Staff Accounting Bulletin Topic 6~~permitted.B, ~~Accounting~~The ~~Series~~amendments ~~Release~~will ~~280~~be –applied ~~General~~prospectively ~~Revision~~with ofan ~~Regulation~~option ~~S-X;~~for ~~Income~~a orretrospective ~~Loss Applicable to Common Stock~~application. ~~SAB~~The ~~120~~Company ~~provides~~is ~~guidance~~evaluating on the ~~measurement~~impact ~~and disclosure~~ of ~~share-based~~this ~~awards~~new ~~shortly~~standard ~~before~~and ~~announcing~~believes ~~material~~that ~~nonpublic~~the ~~information.~~adoption ~~These~~will ~~updates~~result ~~were~~in ~~immediately~~additional ~~effective~~disclosures, ~~and~~but ~~did~~will not have any other impact on ~~our~~its ~~condensed~~ consolidated financial statements.

In October 2023, the FASB issued ASU 2023-06, Disclosure Improvements: Codification Amendments in Response to the SEC’s Disclosure Update and Simplification Initiative, to amend certain disclosure and presentation requirements.

In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. This ASU required disclosure of incremental segment information, primarily through enhanced disclosures about significant segment expenses and amounts for each reportable segment on an annual and interim basis. This guidance is effective for fiscal years beginning after December 15, 2023 and interim periods with fiscal years beginning after December 15, 2024. The Company is currently assessing the potential effects of this standard.

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. ASU 2023-09 is effective for fiscal years beginning after December 15, 2024, with early adoption permitted. The Company is currently assessing the potential effects of this standard.

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 improves 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 does not anticipate that these updates, once adopted, will have a material effect.

In March 2024, the FASB issued ASU No. 2024-02, Codification Improvements – Amendments to Remove References to the Concept Statements (“ASU 2024-02”). The amendments in ASU 2024-02 removes references to various FASB Concept Statements in the Accounting Standard Codifications to draw a distinction between authoritative and non-authoritative literature. The Company does not anticipate that these updates, once adopted, will have a material effect.

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed 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 ~~September~~March 3031, ~~2024~~2025 and December 31, ~~2023~~2024:


	~~September~~March 3031,		December 31,
	~~2024~~2025		~~2023~~2024
Cash and cash equivalents	$	86,~~304~~892,~~971~~735	$	136,~~403~~519,~~628~~793
Restricted cash included in other assets		470,000		470,000
Cash, cash equivalents, and restricted cash in the statement of cash flows	$	87,~~774~~362,~~971~~735	$	136,~~873~~989,~~628~~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~~Accumulated other comprehensive income in the Consolidated Statements of Operations and Comprehensive Income.

~~The~~As ~~following~~of ~~table~~March ~~summarizes~~31, 2025 and December 31, 2024, the ~~available-for-sale~~Company had no short term investments. asDuring ofthe ~~September~~three 30months ended March 31, 2024, ~~and~~the ~~December~~Company 31sold securities with a carrying amount of $7,003,123 ~~2023~~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.


	September 30, 2024						December 31, 2023
	Amortized		Unrealized		Fair		Amortized		Unrealized		Fair
	Cost		Losses		Value		Cost		Gains		Value
U.S. Treasury Bills	$	—	$	—	$	—	$	18,773,508	$	1,598	$	18,775,106

During the nine months ended September 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. The realized gains are included in other income in the consolidated Statements of Operations and Comprehensive Income. During the three months ended September 30, 2024, the Company did not acquire or sell any securities.

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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 ~~September~~March 3031, ~~2024~~2025 and December 31, ~~2023~~2024:


	~~September~~March 3031,		December 31,
	~~2024~~2025		~~2023~~2024
Property and equipment:
Oil and gas properties, successful efforts method
Proved properties	$	~~190~~194,~~162~~811,~~954~~616	$	~~160~~191,~~263~~879,~~511~~210
Unproved properties		2833,~~292~~425,~~321~~087		2528,~~504~~364,~~873~~186
Accumulated depletion, depreciation, amortization and impairment		(~~119~~126,~~981~~370,~~434~~072)		(~~113~~123,~~708~~281,~~210~~395)
Total oil and gas properties, net		98101,~~473~~866,~~841~~631		7296,~~060~~962,~~174~~001
Gathering system		4243,~~988~~176,~~092~~418		4243,~~738~~116,~~273~~371
Accumulated depletion, depreciation, amortization and impairment		(36,~~221~~777,~~366~~152)		(3536,~~539~~449,~~996~~511)
Total gathering system, net		6,~~766~~399,~~726~~266		76,~~198~~666,~~277~~860
Land		637,764		637,764
Buildings and other property and equipment, net		~~269~~246,~~133~~894		~~291~~259,~~807~~335
Total property and equipment, net	$	~~106~~109,~~147~~150,~~464~~555	$	80104,~~188~~525,~~022~~960

Asset Acquisitions

During the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025, Epsilon ~~acquired~~had ~~assets~~no ~~that~~asset ~~included the following:~~acquisitions.

●During athe ~~25%~~three ~~working~~months ~~interest~~ended inMarch ~~three~~31, ~~producing~~2024, ~~wells~~Epsilon inacquired ~~Ector~~assets ~~County,~~that ~~Texas~~included ~~for~~the ~~$12.1 million.~~following:

● a 25% working interest in ~~3,620~~three ~~gross~~producing ~~undeveloped~~wells ~~acres~~located in Ector County, Texas ~~for $2~~.~~6 million.~~

● a 5025% working interest in 143,~~243~~246 gross undeveloped acres in ~~Alberta~~Ector County, ~~Canada for $1~~Texas.~~0 million.~~

~~Management~~● ~~determined~~total ~~that~~consideration ~~substantially~~paid ~~all the fair value~~ of ~~the assets acquired was concentrated in a group of similar identifiable assets~~$14.8 ~~Based~~million onconsisting ~~this determination, the acquisitions were accounted for as asset acquisitions.~~ of

~~During~~(i) ~~the~~$12.1 ~~nine~~million ~~months~~for ~~ended~~the ~~September~~producing ~~30,~~wells ~~2023, Epsilon acquired assets that included the following:~~and

●(ii) a$2.7 ~~10%~~million ~~interest~~for inthe ~~two~~undeveloped ~~wellbores located in Eddy County, New Mexico for $2~~acreage.~~1 million.~~

●Management adetermined ~~25%~~that ~~working~~substantially ~~interest~~all inthe ~~1,297~~fair ~~gross~~value ~~acres~~of inthe ~~Ector~~assets ~~County,~~acquired ~~Texas~~was ~~including~~concentrated ~~the~~in ~~drilling~~a group of ~~one~~similar ~~well~~identifiable ~~for $3~~assets.7 ~~million~~Based ~~and~~on athis ~~commitment~~determination, ~~for~~ the ~~completion~~acquisition ofwas ~~that~~accounted ~~well~~ for ~~$1.6~~as ~~million~~an asset acquisition.

● a 25% working interest in 11,067 gross acres in Ector County, Texas for $6.3 million.

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 ~~values~~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 nine~~ months ended ~~September~~March 3031, 2025, Epsilon recorded an impairment of $0.01 million for one well drilled during 2024 ~~and~~that ~~2023~~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

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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 ~~commitment and~~ borrowing base is $45 million (redetermined onas ~~June~~of 25February 10, ~~2024~~2025), supported by the Company’s upstream assets in Pennsylvania and subject to semi-annual redeterminations with a maturity date of ~~the earlier of~~ June 28, 2027 ~~or the date that the commitments are terminated~~. 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) ~~and guaranteed by the Company and the other wholly owned subsidiaries~~. 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 ~~September~~March 3031, ~~2024~~2025.

Balance at

~~September~~March 3031,

December 31,

Current

~~2024~~2025

~~2023~~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 ~~March~~February 2012, ~~2024~~2025, ~~the~~Epsilon’s ~~Board~~board of ~~Directors~~directors (the “Board”) authorized a new share repurchase program of up to 2,~~191~~200,~~320~~876 common shares, representing 10% of the current outstanding common shares of ~~the Company at such time~~Epsilon, for an aggregate purchase price of not more than US $1213.0 million. The program ~~is pursuant to a normal course issuer bid and will be conducted in accordance with Rule 10b-18 under the Exchange Act. The program~~ commenced on ~~March~~February 2712, ~~2024~~2025 and ~~will~~ends ~~end~~ on ~~March~~February 2611, ~~2025~~2026, unless the maximum amount of common shares is purchased before then or ~~Epsilon~~the ~~provides~~Board approves earlier ~~notice of~~ termination.

The previous share repurchase program commenced on March 19, 2024. During the ~~nine~~year ~~months~~ ended ~~September~~December 3031, 2024, we repurchased 125,000 common shares ~~have~~and ~~been~~spent ~~repurchased~~$627,500 at aan average price of $5.00 per share (excluding commissions) under the ~~new program~~plan. ~~These~~On ~~shares~~February ~~are~~12, ~~currently~~2025, ~~held~~the inBoard ~~treasury~~terminated and ~~will~~revoked beauthority ~~retired~~under ~~during~~ the ~~fourth quarter of 2024~~program.

~~The~~During ~~previous~~the ~~share~~three ~~repurchase~~months ~~program commenced on March 27, 2023 and~~ ended on March ~~26, 2024. During the year ended December~~ 31, ~~2023~~2025, weno ~~repurchased 968,149 common~~ shares atwere anrepurchased ~~average price of $5.08 per share (excluding commissions)~~ under the new or previous ~~plan~~program.

~~During the nine months ended September 30, 2024, we repurchased and retired 248,700 shares at a price of $4.82 per share (excluding commissions) under the previous plan.~~ 12

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

The following table contains activity relating to our acquisition of equity securities during the nine months ended September 30, 2024:


				Maximum number
				of shares
	Total number	Average price		remaining to be
	of shares	paid per		purchased under
	purchased	share		the program
Beginning of normal-course issuer bid, March 27, 2023 (1)					1,324,495
January 2024	248,700	$	4.82
Total as of March 26, 2024	248,700	$	4.82		1,075,795

Beginning of normal-course issuer bid, March 27, 2024 (2)					2,191,320
September 2024	125,000	$	5.00
Total as of September 30, 2024	125,000	$	5.00		2,066,320

(1) Epsilon repurchased these shares under its 2023-2024 share repurchase program that commenced on March 27, 2023 and terminated on March 26, 2024, as described above.

(2) Epsilon repurchased these shares under its 2024-2025 share repurchase program that commenced on March 27, 2024 and terminates on March 26, 2025 as described above.

(c)Equity Incentive Plan

~~Epsilon’s~~The ~~board of directors (the “~~Board”) adopted the 2020 Equity Incentive Plan (the “2020 Plan”) on July 22, 2020, ~~and~~subject to approval by Epsilon’s shareholders ~~approved the 2020 Plan~~ at Epsilon’s 2020 Annual General and Special Meeting of ~~Shareholders~~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 ~~will~~is be authorized to issue up to 2,000,000 Common Shares.

Restricted Stock ~~Awards~~

For the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025, ~~63,980~~no restricted ~~stock~~common ~~units~~shares ~~with a weighted average price at the grant date of $5.08~~ were awarded to the Company’s board of directors and employees. For the year ended December 31, ~~2023~~2024, ~~358~~300,~~546~~052 restricted ~~stock~~common ~~units~~shares with a weighted average ~~price at the~~ grant date fair value of $5.4297 were awarded to the Company’s management, employees, and board of directors. These ~~units~~shares vest over a three-year period, with an equal number of ~~common~~ shares being issued per period on the anniversary of the award resolution. The vesting of the ~~units (and corresponding issuance of~~ shares) is contingent on the individuals’ continued employment or service. The Company determined the fair value of the granted ~~restricted~~Restricted ~~stock~~Stock ~~units~~ based on the market price of the common shares of the Company on the date of grant.

The following table summarizes restricted stock ~~unit~~ activity for the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025, and the year ended December 31, ~~2023~~2024:

~~Nine~~Three months ended

~~Year ended~~

Year ended

~~September~~March 3031, ~~2024~~2025

~~December 31, 2023~~

December 31, 2024

Number of

Weighted

~~Number of~~Weighted

~~Weighted~~

Number of

Weighted

Restricted

Average

~~Restricted~~Average

~~Average~~

Restricted

Average

Remaining Life

~~Shares~~Grant Date

~~Remaining Life~~

Remaining Life

Grant Date

Outstanding

(years)

~~Outstanding~~Fair Value

~~(years)~~

Outstanding

(years)

Fair Value

Balance non-vested Restricted Stock at beginning of period

~~491~~560,~~536~~970

1.7461

~~298,210~~$

5.77

~~1.74~~

491,536

1.74

5.59

Granted

~~63,980~~—

~~1.25~~—

~~358,546~~

~~1.90~~

300,052

1.92

5.97

Vested

~~(70,539)~~—

—

~~(165,220)~~

—

(230,618)

—

5.65

Balance non-vested Restricted Stock at end of period

~~484~~560,~~977~~970

1.1735

~~491,536~~$

5.77

~~1.74~~

560,970

1.61

5.77

15Stock 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.

~~Table~~As of ~~Contents~~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).

~~Epsilon Energy Ltd.~~(d)Dividends

Notes to the Unaudited Condensed Consolidated Financial Statements

Stock compensation expense for the granted restricted stock units is recognized over the vesting period. Stock compensation expense recognized during the three and nine months ended September 30, 2024 was $309,109 and $944,267, respectively (for the three and nine months ended September 30, 2023 was $424,969 and $755,097, respectively).

At September 30, 2024, the Company had unrecognized stock-based compensation related to the restricted stock units of $2,032,610 to be recognized over a weighted average period of 1.13 years (at December 31, 2023: $2,651,858 over 1.42 years).

Performance Share Unit Awards (“PSU”)

For the three and nine months ended September 30, 2024, there were no outstanding PSUs. For the year ended December 31, 2023, a total of 15,833 common shares vested and were issued.

The following table summarizes PSUs for the nine months ended September 30, 2024 and the year ended December 31, 2023:


	Nine months ended		Year ended
	September 30, 2024		December 31, 2023
	Number of	Weighted	Number of	Weighted
	Performance	Average	Performance	Average
	Shares	Remaining Life	Shares	Remaining Life
	Outstanding	(years)	Outstanding	(years)
Balance non-vested PSUs at beginning of period	—	—	15,833	1.00
Vested	—	—	(15,833)	—
Balance non-vested PSUs at end of period	—	—	—	—

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.

Stock compensation expense for the granted PSUs is recognized over the vesting period. Stock compensation expense recognized during the nine months ended September 30, 2024 related to PSUs was $0 (for the three and nine months ended September 30, 2023 related to PSUs was $14,684 and $44,052, respectively).

At September 30, 2024 and December 31, 2023, the Company had no unrecognized stock-based compensation related to PSUs.

~~Stock~~8. Revenue ~~Options~~Recognition

AsRevenues are comprised of ~~September~~sales ~~30,~~of ~~2024~~natural gas, ~~the~~oil ~~Company~~and ~~had~~natural nogas ~~outstanding~~liquids ~~stock~~(“NGLs”), ~~options.~~along ~~During~~with the ~~nine~~revenue ~~months~~generated ~~ended~~from ~~September~~the ~~30,~~Company’s ~~2024~~ownership ~~and~~interest in the ~~year~~gas ~~ended~~gathering ~~December~~system ~~31,~~in ~~2023,~~ the ~~Company~~Auburn ~~awarded~~field noin ~~stock~~Northeastern ~~options~~Pennsylvania.

The following table summarizes stock option activity for the nine months ended September 30, 2024 and the year ended December 31, 2023:


	Nine months ended			Year ended
	September 30, 2024			December 31, 2023
		Weighted				Weighted
	Number of	Average		Number of		Average
	Options	Exercise		Options		Exercise
Exercise price in US$	Outstanding	Price		Outstanding		Price (1)
Balance at beginning of period	57,500	$	5.03		70,000	$	5.03
Exercised	—	$	—		(12,500)	$	5.03
Expired	(57,500)	$	—		—	$	—
Balance at period-end	—	$	—		57,500	$	5.03

Exercisable at period-end	—	$	—		57,500	$	5.03

At September 30, 2024, the Company had unrecognized stock-based compensation, related to these options, of nil (at December 31, 2023: nil). The aggregate intrinsic value at September 30, 2024 was nil (at December 31, 2023: $5,500).

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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 (d“elimination entry”), ~~Dividends~~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.

On March 1, 2024, May 30, 2024 and August 27, 2024, 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 $4.1 million that has been paid for the nine months ended September 30, 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

8. Revenue Recognition

Revenues are comprised of sales of natural gas, oil and 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 $0.3 million and $0.8 million, respectively, for the three and nine months ended September 30, 2024 ($0.3 million and $1.0 million, respectively, for the three and nine months ended September 30, 2023).

The following table details revenue for the three and nine months ended September 30, 2024 and 2023.


	Three months ended September 30,				Nine Months Ended September 30,
	2024		2023		2024		2023
Operating revenue
Natural gas	$	1,903,946	$	2,088,745	$	6,828,155	$	11,351,618
Natural gas liquids		335,271		228,012		1,096,678		669,295
Oil and condensate		3,964,736		924,774		10,193,535		2,488,271
Gathering and compression fees (1)		1,083,988		3,068,996		4,464,134		7,657,755
Total operating revenue	$	7,287,941	$	6,310,527	$	22,582,502	$	22,166,939

(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~~Consolidated ~~statements~~Statements of ~~operations~~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~~Consolidated ~~balance~~Balance ~~sheets~~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 ~~the Auburn field~~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.

17The 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

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

~~The~~including ~~settlement~~review ~~statement from the operator~~ of ~~the~~our ~~Auburn~~trade ~~GGS~~receivable isbalances ~~received~~by ~~two~~counterparty, ~~months~~assessing ~~after~~economic ~~gathering~~events and ~~compression~~conditions, ~~has~~our ~~occurred.~~historical Asexperience awith ~~result~~counterparties, the ~~Company~~counterparty’s ~~must~~financial ~~estimate~~condition and the amount ~~of production that was gathered~~ and ~~compressed~~age ~~within~~of ~~the~~past ~~system. Estimated revenue~~ due toaccounts. ~~the~~As ~~Company~~of isMarch ~~recorded~~31, ~~within~~2025 ~~the~~and ~~receivables~~December ~~line~~31, ~~item~~2024, onwe ~~the~~determined ~~accompanying~~that ~~consolidated~~our ~~balance~~allowance ~~sheets~~for ~~until~~credit ~~payment~~loss iswas ~~received~~nil.


	~~September~~March 3031,		December 31,		December 31,
	~~2024~~2025		~~2023~~2024		~~2022~~2023
Accounts receivable
Natural gas and oil sales	$	36,~~563~~357,~~893~~749	$	4,~~327~~888,~~886~~294	$	54,~~696~~327,~~419~~886
Joint interest billing		—		~~17,476~~—		2017,~~454~~476
Gathering and compression fees		~~750~~1,~~776~~615,086		1918,~~543,239~~471		1,~~483~~543,~~956~~239
Commodity contract		~~155~~30,~~348~~682		7236,~~075~~957		—72,075
Interest		—		~~54,772~~—		~~557~~54,772
Total accounts receivable	$	48,~~470~~003,~~017~~517	$	65,~~015~~843,~~448~~722	$	76,~~201~~015,~~386~~448

9. ~~Income~~Accumulated ~~Taxes~~Other Comprehensive Income

~~Income~~Accumulated ~~tax~~other ~~provisions~~comprehensive ~~for~~income includes certain transactions that have generally been reported in the ~~three~~Consolidated ~~and~~Statements ~~nine~~of Changes in Shareholders’ Equity. The activity in accumulated other comprehensive income during the three months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024 ~~are~~consisted asof ~~follows~~the following:


	Three months ended September 30,				Nine months ended September 30,
	2024		2023		2024		2023
Current:
Federal	$	(198,619)	$	(105,913)	$	268,691	$	940,873
State		(71,807)		(141,655)		28,685		154,296
Total current income tax expense		(270,426)		(247,568)		297,376		1,095,169
Deferred:
Federal		565,137		762,495		919,522		1,140,543
State		73,687		195,237		(335,434)		47,516
Total deferred tax expense		638,824		957,732		584,088		1,188,059
Income tax expense	$	368,398	$	710,164	$	881,464	$	2,283,228

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


	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

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, 2020 through December 31, 2023. 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 nine months ended September 30, 2024 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.

10. Commitments and Contingencies

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of September 30, 2024, the Company had no unpaid capital expenditures.

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.

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

11open to audit under the statute of limitations for the years ending December 31, 2021 through December 31, 2024. ~~Leases~~To the extent we utilize net operating losses generated in earlier years, such earlier years may also be subject to audit.

Our effective tax rate will typically differ from the statutory federal rate primarily as a result of state income taxes and the valuation allowance against the Canadian net operating loss. The effective tax rate for the 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.

~~Under~~11. Commitments ~~ASC 842, Leases, the Company recognized an operating lease related to its corporate office as of September 30, 2024~~ and ~~December 31, 2023 as summarized in the following table:~~Contingencies


	September 30,		December 31,
	2024		2023
Asset
Operating lease right-of-use assets, long term	$	368,564	$	441,987
Total operating lease right-of-use assets	$	368,564	$	441,987

Liabilities
Operating lease liabilities	$	112,502	$	86,473
Operating lease liabilities, long term		385,653		476,911
Total operating lease liabilities	$	498,155	$	563,384

Operating lease costs	$	177,212	$	144,490

Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	176,347	$	27,010
Right-of-use assets obtained in exchange for new operating lease liabilities	$	—	$	535,149
Weighted average remaining lease term (years) - operating lease		2.65		3.00
Weighted average discount rate (annualized) - operating lease		8.25%		8.25%

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.

~~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~~12.85 million. There are no other pending leases, and no lease arrangements in which the Company is the lessor. Lease expense for operating leases was $0.18 million and $0.14 million for the nine months ended September 30, 2024 and for the year ended December 31, 2023, respectively. This lease expense is presented in other general and administrative expenses in the consolidated statements of operations and comprehensive income.Leases

~~Future~~Under ~~minimum~~ASC 842, Leases, the Company recognized an operating lease ~~payments~~related to its corporate office as of ~~September~~March 3031, ~~2024~~2025 ~~are~~and December 31, 2024 as ~~follows~~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%


	Operating Leases
2024	$	33,687
2025		173,550
2026		177,021
2027		180,492
2028		183,963
Total minimum lease payments		748,713
Less: imputed interest		(250,558)
Present value of future minimum lease payments		498,155
Less: current obligations under leases		(112,502)
Long-term lease obligations	$	385,653

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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

~~12. 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.

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

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

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Net income

~~366~~4,~~021~~016,034

~~388~~1,~~775~~506,896

~~2,688,577~~

~~4,349,191~~

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


	Three months ended ~~September~~March 3031,		~~Nine months ended September 30,~~
	~~2024~~2025	~~2023~~2024	~~2024~~	~~2023~~
Basic weighted-average number of shares outstanding	2122,~~948~~008,~~519~~766	2221,~~118~~994,~~984~~207	~~21,954,803~~	~~22,616,539~~
Dilutive stock options	—	6,786	—	5,865
Unvested time-based restricted shares	101,053	—
Unvested time-based restricted shares	206,773	41,037	46,078	—
Diluted weighted-average shares outstanding	22,109,819	21,994,207
Unvested performance-based restricted shares	—	11,879	—	9,146
Diluted weighted-average shares outstanding	22,155,292	22,178,686	22,000,881	22,631,550

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


	Three months ended ~~September~~March 3031,		~~Nine months ended September 30,~~
	~~2024~~2025	~~2023~~2024	~~2024~~	~~2023~~
Anti-dilutive options	—	63,214	—	64,135
Anti-dilutive unvested time-based restricted shares	459,917	546,245
Anti-dilutive unvested time-based restricted shares	408,816	355,788	478,005	327,300
Anti-dilutive unvested performance-based restricted shares	—	3,954	—	6,687
Total Anti-dilutive shares	408,816	422,956	478,005	398,122

1314. Operating Segments

Operating segments are reported in a manner consistent with the internal reporting provided to the chief operating decision-maker (CODM). The ~~chief operating decision-maker~~CODM, who is responsible for allocating resources and assessing performance of the operating segments, has been identified as executive management. ~~Segment~~consisting ~~performance~~of isthe ~~evaluated~~Chief ~~based~~Executive onOfficer, ~~operating~~Chief ~~income~~Financial ~~(loss)~~Officer, asand ~~shown~~Chief inOperating Officer. The CODM uses the ~~table~~Company’s ~~below.~~consolidated ~~Interest~~financial results, including operating income ~~and~~or ~~expense~~loss by segment, ~~and~~to ~~income~~make ~~taxes~~key ~~are~~operating ~~managed~~decisions, ~~separately~~assess onperformance, aand ~~group~~to ~~basis~~allocate resources.

~~The Company’s reportable segments are as follows:~~17

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

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

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

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

Segment ~~activity~~performance ~~for~~is ~~the~~evaluated ~~nine~~based ~~months~~on ~~ended~~operating ~~September~~income ~~30,~~or ~~2024~~loss as shown in the table below. Interest income and ~~2023~~income istaxes asare ~~follows:~~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.


	Upstream		Gas Gathering		Corporate		Elimination		Consolidated
As of and for the nine months ended September 30, 2024
Operating revenue
Natural gas	$	6,828,155	$	—	$	—	$	—	$	6,828,155
Natural gas liquids		1,096,678		—		—		—		1,096,678
Oil and condensate		10,193,535		—		—		—		10,193,535
Gathering and compression fees		—		5,306,759		—		(842,625)		4,464,134
Total operating revenue (1)		18,118,368		5,306,759		—		(842,625)		22,582,502

Operating costs
Operating costs		6,360,455		1,692,862		5,431,081		(842,625)		12,641,773
Depletion, depreciation, amortization and accretion		6,440,741		686,900		—		—		7,127,641
Operating income (loss)		5,317,172		2,926,997		(5,431,081)		—		2,813,088

Other income (expense)
Interest income		—		—		471,435		—		471,435
Interest expense		(35,117)		—		(35,527)		—		(70,644)
Gain on derivative contracts		245,095		—		—		—		245,095
Other income (expense)		111,637		—		(570)		—		111,067
Other income, net		321,615		—		435,338		—		756,953
Net income (loss) before income tax expense	$	5,638,787	$	2,926,997	$	(4,995,743)	$	—	$	3,570,041

Segment assets
Current assets, net	$	—	$	—	$	15,281,129	$	—	$	15,281,129
Proved properties		70,181,520		—		—		—		70,181,520
Unproved properties		28,292,321		—		—		—		28,292,321
Gathering system		—		6,766,726		—		—		6,766,726
Other property and equipment		906,897		—		—		—		906,897
Operating lease right-of-use asset		—		—		368,564		—		368,564
Total segment assets	$	99,380,738	$	6,766,726	$	15,649,693	$	—	$	121,797,157

Capital expenditures (2)	$	32,661,208	$	249,818	$	—	$	—	$	32,911,026

As of and for the nine months ended September 30, 2023
Operating revenue
Natural gas	$	11,351,618	$	—	$	—	$	—	$	11,351,618
Natural gas liquids		669,295		—		—		—		669,295
Oil and condensate		2,488,271		—		—		—		2,488,271
Gathering and compression fees		—		8,694,987		—		(1,037,232)		7,657,755
Total operating revenue (1)		14,509,184		8,694,987		—		(1,037,232)		22,166,939

Operating costs
Operating costs		6,891,860		1,854,030		5,959,876		(1,037,232)		13,668,534
Depletion, depreciation, amortization and accretion		4,034,760		746,006		—		—		4,780,766
Operating income (loss)		3,582,564		6,094,951		(5,959,876)		—		3,717,639

Other income (expense)
Interest income		—		—		1,308,695		—		1,308,695
Interest expense		(71,619)		—		—		—		(71,619)
Loss on derivative contracts		1,672,535		—		—		—		1,672,535
Other income		4,083		—		1,086		—		5,169
Other income, net		1,604,999		—		1,309,781		—		2,914,780
Net income (loss) before income tax expense	$	5,187,563	$	6,094,951	$	(4,650,095)	$	—	$	6,632,419

Segment assets
Current assets, net	$	—	$	—	$	38,786,814	$	—	$	38,786,814
Proved properties		43,047,938		—		—		—		43,047,938
Unproved properties		26,185,843		—		—		—		26,185,843
Gathering system		—		7,452,917		—		—		7,452,917
Other property and equipment		3,832,225		—		—		—		3,832,225
Operating lease right-of-use asset		—		—		468,833		—		468,833
Total segment assets	$	73,066,006		7,452,917		39,255,647		—		119,774,570

Capital expenditures (2)	$	15,969,121		55,510		—		—		16,024,631

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

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the nine months ended September 30, 2024 and 2023 have been eliminated upon consolidation. For the nine months ended September 30, 2024, Epsilon sold natural gas to 30 unique customers. The two customers over 10% comprised 18% and 11% of total revenue. For the nine months ended September 30, 2023, Epsilon sold natural gas to 34 unique customers. The one customer over 10% comprised 20% 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.


	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

Segment activity for the three months ended September 30, 2024 and 2023 is as follows:


	Upstream		Gas Gathering		Corporate		Elimination		Consolidated
For the three months ended September 30, 2024
Operating revenue
Natural gas	$	1,903,946	$	—	$	—	$	—	$	1,903,946
Natural gas liquids		335,271		—		—		—		335,271
Oil and condensate		3,964,736		—		—		—		3,964,736
Gathering and compression fees		—		1,334,706		—		(250,718)		1,083,988
Total operating revenue (1)		6,203,953		1,334,706		—		(250,718)		7,287,941

Operating costs
Operating costs		2,350,220		490,324		1,758,685		(250,718)		4,348,511
Depletion, depreciation, amortization and accretion		2,433,421		265,391		—		—		2,698,812
Operating income (loss)		1,420,312		578,991		(1,758,685)		—		240,618

Other income (expense)
Interest income		—		—		96,220		—		96,220
Interest expense		(17,598)		—		(35,527)		—		(53,125)
Loss on derivative contracts		440,712		—		—		—		440,712
Other income		9,994		—		—		—		9,994
Other income, net		433,108		—		60,693		—		493,801
Net income (loss) before income tax expense	$	1,853,420	$	578,991	$	(1,697,992)	$	—	$	734,419

Capital expenditures (2)	$	4,701,109	$	133,720	$	—	$	—	$	4,834,829

For the three months ended September 30, 2023
Operating revenue
Natural gas	$	2,088,745	$	—	$	—	$	—	$	2,088,745
Natural gas liquids		228,012		—		—		—		228,012
Oil and condensate		924,774		—		—		—		924,774
Gathering and compression fees		—		3,366,370		—		(297,374)		3,068,996
Total operating revenue (1)		3,241,531		3,366,370		—		(297,374)		6,310,527

Operating costs
Operating costs		1,857,331		631,725		1,980,011		(297,374)		4,171,693
Depletion, depreciation, amortization and accretion		1,175,402		216,630		—		—		1,392,032
Operating (loss) income		208,798		2,518,015		(1,980,011)		—		746,802

Other income (expense)
Interest income		—		—		384,732		—		384,732
Interest expense		(8,760)		—		—		—		(8,760)
Loss on derivative contracts		(24,303)		—		—		—		(24,303)
Other income		369		—		99		—		468
Other (expense) income, net		(32,694)		—		384,831		—		352,137
Net income (loss) before income tax expense	$	176,104	$	2,518,015	$	(1,595,180)	$	—	$	1,098,939

Capital expenditures (2)	$	2,373,657	$	21,006	$	—	$	—	$	2,394,663

(1) Segment operating revenue represents revenues generated from the operations of the segment. Inter-segment sales during the three months ended September 30, 2024 and 2023 have been eliminated upon consolidation. For the three months ended September 30, 2024, Epsilon sold natural gas to 22 unique customers. The three customers over 10% comprised 34%, 14%,

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements

~~and~~Segment ~~11%~~activity offor ~~total revenue. For~~ the three months ended ~~September~~March 3031, ~~2023,~~2024 ~~Epsilon~~is ~~sold~~as ~~natural gas to 28 unique customers. The two customers over 10% comprised 36% and 24% of total revenue.~~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.

~~14. Commodity Risk Management Activities~~19

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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 ~~gain~~Loss ~~(loss)~~ on derivative contracts on the condensed ~~consolidated~~Consolidated ~~statements~~Statements of ~~operations~~Operations and ~~comprehensive~~Comprehensive ~~income (loss)~~Income. The related cash flow impact is reflected in cash flows from operating activities. During the three ~~and nine~~ months ended ~~September~~March 3031, ~~2024~~2025, Epsilon recognized ~~gains~~losses on commodity derivative contracts of $~~440~~1,~~712 and $245~~462,~~095, respectively~~170. This amount included cash ~~received~~paid on settlements on these contracts of $~~485~~415,~~389 and $1,245,931, respectively~~043. For the three ~~and nine~~ months ended ~~September~~March 3031, ~~2023~~2024, Epsilon recognized (losses) ~~gains~~ on commodity derivative contracts of ($24100,~~303) and $1~~726,~~672,535,~~ respectively. This amount included cash received on settlements on these contracts of $1488,~~346,270 and $2,979,128, respectively~~285.

Commodity Derivative Contracts

At ~~September~~March 3031, ~~2024~~2025, the Company had outstanding natural gas NYMEX Henry Hub (“HH”) swaps totaling 1.1356 Bcf, natural gas Tennessee Z4 basis swaps totaling 01.9856 Bcf, and crude oil NYMEX WTI CMA swaps totaling 2847 MBbls.


	Fair Value of Derivative Assets
	~~September~~March 3031,		December 31,
	~~2024~~2025		~~2023~~2024
Current
NYMEX Henry Hub swap	$	~~164,940~~—	$	1151,~~353,667~~274
Tennessee Z4 basis swap		—285,583		~~112~~195,~~719~~211
Crude Oil NYMEX WTI CMA		~~193~~89,~~249~~782		—56,547
	$	~~358~~375,~~189~~365	$	1403,~~466,386~~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)

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Epsilon Energy Ltd.

Notes to the Unaudited Condensed Consolidated Financial Statements


	Fair Value of Derivative Liabilities
	September 30,		December 31,
	2024		2023
Current
NYMEX Henry Hub swap	$	(85,258)	$	—
Tennessee Z4 Basis swap		(173,512)		(366,131)
	$	(258,770)	$	(366,131)

Net Fair Value of Derivatives	$	99,419	$	1,100,255

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


	Three months ended ~~September~~March 3031,				~~Nine months ended September 30,~~
	~~2024~~2025		~~2023~~2024		~~2024~~		~~2023~~
Fair value of asset, beginning of the period	$	144,096	$	1,286,070	$	1,100,255	$	1,222,090
Fair value of (liability) asset, beginning of the period	$	(487,548)	$	1,100,255
Gain (loss) on derivative contracts included in earnings		440,712		(24,303)		245,095		1,672,535
Loss on derivative contracts included in earnings		(1,462,170)		(100,726)
Settlement of commodity derivative contracts		~~(485~~415,~~389)~~043		(1488,~~346,270~~285)		~~(1,245,931)~~		~~(2,979,128)~~
Fair value of asset (liability), end of the period	$	99,419	$	(84,503)	$	99,419	$	(84,503)
Fair value of (liability) asset, end of the period	$	(1,534,675)	$	511,244

1516. 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. ~~Epsilon has estimated the value of its total asset retirement obligations to be $3.6 million as of September 30, 2024 ($3.5 million at December 31, 2023).~~ 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:


	~~Nine~~Three Months Ended		Year ended
		~~September~~March 3031,		December 31,
	~~2024~~2025		~~2023~~2024
Balance beginning of period	$	3,~~502~~652,~~952~~296	$	23,~~780~~502,~~237~~952
Liabilities acquired		3218,~~902~~235		1248,~~437~~207
Liabilities disposed of		—		(46,961)
Wells plugged and abandoned		(1,600)		(88,992)
Wells plugged and abandoned		(88,992)		(509,802)
Change in estimates		—		6,695
Change in estimates		6,695		1,178,142
Accretion		47,098		183,434
Accretion		136,460		88,899
Balance end of period	$	3,716,029	$	3,652,296
Balance end of period	$	3,590,017	$	3,502,952

1617. Fair Value Measurements

The methodologies used to determine the fair value of our financial assets and liabilities at ~~September~~March 3031, ~~2024~~2025 were the same as those used at December 31, ~~2023~~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

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Notes to the Unaudited Condensed Consolidated Financial Statements

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.


	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


	September 30, 2024
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	358,189	$	—	$	(208,068)	$	150,121
Cash equivalents	$	297,205	$	—	$	—	$	—	$	297,205
Liabilities
Derivative contracts	$	—	$	258,770	$	—	$	(208,068)	$	50,702


	December 31, 2023
	Level 1		Level 2		Level 3		Effect of Netting		Net Fair Value
Assets
Derivative contracts	$	—	$	1,219,025	$	—	$	—	$	1,219,025
Cash equivalents	$	195,669	$	—	$	—	$	—	$	195,669
Short term investments	$	18,775,106	$	—	$	—	$	—	$	18,775,106
Liabilities
Derivative contracts	$	—	$	247,361	$	—	$	(366,131)	$	(118,770)

17. Current Expected Credit Loss

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. We also have accounts receivable which 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, 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 September 30, 2024 and December 31, 2023, we determined that our allowance for credit loss was nil.

18. Subsequent Events

In October 2024, Epsilon formed a joint venture with a private operator covering lands in the Western Canadian Sedimentary Basin in Alberta, Canada. Epsilon will earn a 25% working interest across approximately 160,000 gross acres after fulfilling a carried interest commitment of $7.3 million before December 1, 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 ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024 ~~and for the nine months then ended~~ together with accompanying notes, as well as our audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, ~~2023~~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, ~~and~~ the NW Anadarko ~~basin~~Basin in Oklahoma, and the Western Canadian Sedimentary Basin in Alberta, Canada.

At ~~September~~March 3031, ~~2024~~2025 we held leasehold rights to 2324,~~630~~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, ~~2023~~2024 our total estimated net proved reserves were 6569,~~916~~401 MMcf of natural gas, ~~383~~876,~~174~~808 Bbls of NGLs, and ~~341~~1,~~286~~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 2726, 2024, Epsilon acquired a 25% ~~working~~ interest in three producing wells and 3,~~246~~620 gross undeveloped acres ~~on the Central Basin Platform~~ in Ector County, Texas from a private operator. The ~~assets~~Company ~~are~~participated ~~immediately~~in ~~offset~~the todrilling ~~the~~and ~~assets~~completion ~~acquired~~of 2 gross (0.5 net) wells during 2024 which were put on production in ~~June~~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. ~~The~~Total ~~total~~capital ~~purchase~~expenditures ~~price~~(net ~~was~~to Epsilon) through March 31, 2025 in the project (including undeveloped leasehold) are $1438.86 million.

InOn ~~the~~April ~~second~~11, ~~and~~2024, ~~third~~Epsilon ~~quarter~~acquired ofa ~~2024~~50% working interest in 14,243 ~~Epsilon~~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 ~~Ector~~September ~~County,~~2024. ~~Texas~~One well was deemed non-commercial. ~~The~~Total ~~wells~~capital ~~were~~expenditures ~~put~~(net onto ~~production~~Epsilon) through March 31, 2025 in ~~June~~the ~~and~~project ~~August~~(including ~~2024~~undeveloped leasehold) are $2.9 million.

~~In April 2024, Epsilon acquired a 50% working interest in 14,243 gross acres for $1.0 million. Epsilon participated in the drilling of 2 gross wells in the third and fourth quarter of 2024.~~ 23

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In October 2024, Epsilon formed a joint venture with a private operator covering ~~lands~~approximately 130,000 gross acres in ~~the~~Garrington ~~Western~~and ~~Sedimentary~~Harmattan ~~Basin~~areas in Alberta, Canada. ~~Epsilon~~The ~~will~~Company ~~earn~~provided a $7 million drilling carry in favor of the operator in exchange for a 25% working interest ~~across~~in ~~approximately~~the ~~160~~leasehold. To date,~~000~~ ~~gross~~the ~~acres~~Company ~~after~~participated ~~fulfilling~~in athe ~~carried~~drilling ~~interest~~and ~~commitment~~completion of $72 gross (0.35 ~~million~~net) ~~before~~wells. ~~December~~Total 1capital expenditures (net to Epsilon) through March 31, 2025 are $8.3 million.

We continue to evaluate new opportunities in numerous onshore North American ~~natural gas and oil~~ basins.

Three ~~and nine~~ months ended ~~September~~March 3031, ~~2024~~2025 Highlights

Operational Highlights

Marcellus Shale – Pennsylvania

● During the three months ended ~~September~~March 3031, ~~2024~~2025, Epsilon's realized natural gas price was $13.5492 per Mcf, a 4469% increase over the three months ended ~~September~~March 3031, ~~2023. During the nine months ended September 30,~~ 2024~~, Epsilon's realized natural gas price was $1~~.~~60 per Mcf, an 8% decrease over the nine months ended September 30, 2023.~~

● During the three months ended ~~September~~March 3031, ~~2024~~2025, Epsilon’s net revenue interest natural gas production was 1.2 ~~Bcf compared to 1~~.76 Bcf ~~during the same period in 2023~~, a 3263% ~~decrease.~~increase ~~During~~over the ~~nine~~three months ended ~~September~~March 3031, 2024~~, Epsilon’s net revenue interest natural gas production was 4~~.~~0 Bcf compared to 6.0 Bcf during the same period in 2023, a 33% decrease.~~

● Gathered and delivered 711.06 Bcf gross (24.51 net to Epsilon's interest) during the three months ended ~~September~~March 3031, ~~2024~~2025, or 76129 MMcf/d through the Auburn Gas Gathering System. ~~Gathered and delivered 30.2 Bcf gross (10.6 net to Epsilon's interest) during the nine months ended September 30, 2024, or 111 MMcf/d through the Auburn Gas Gathering System.~~

● On May 17, 2024, Epsilon Energy USA, Inc. ("Epsilon”) executed a new Anchor Shipper Gas Gathering Agreement for Northern Pennsylvania (the "ASGGA”) with operator Appalachia Midstream Services, LLC for a primary term of ten years and an effective date of January 1, 2024. Epsilon simultaneously terminated the prior agreement. The new ASGGA establishes fixed gathering, compression and cross-flow rates for all shippers on each system into which Epsilon produces natural gas. These rates will be adjusted annually by the Consumer Price Index for All Urban Consumers ("CPI-U”) commencing January 2025. Notably, the gathering rates in Auburn GGS, Rome GGS & Overfield GGS will no longer be subject to a cost-of-service redetermination annually; however, acreage dedications, service priority levels, required shipper approvals and shipper voting procedures are all substantially similar to the prior agreement. The new fixed rate for gathering services in Auburn GGS for 2024 is $0.475 per MMBtu.

● At September 30, 2024, the Company had seven gross (.7 net) drilled and completed wells waiting to be turned in line.

Permian Basin – Texas and New Mexico

● During the three months ended ~~September~~March 3031, ~~2024~~2025, Epsilon's realized price for all Permian Basin production was $54.1960 per Boe (9087% liquids), a 162% increase over the three months ended ~~September~~March 3031, ~~2023. During the nine months ended September 30,~~ 2024~~, Epsilon's realized price for all Permian Basin production was $53~~.~~82 per Boe (86% liquids), a 14% increase over the nine months ended September 30, 2023.~~

● Total net revenue interest production for the three months ended ~~September~~March 3031, ~~2024~~2025, which included oil, natural gas liquids, and natural gas, was 7361.39 Mboe compared to 1352.93 Mboe during the same period in ~~2023, a 428% increase. Total net revenue interest production for the nine months ended September 30,~~ 2024, ~~which~~an ~~included oil, natural gas liquids, and natural gas, was 191.4 Mboe compared to 28.8 Mboe during the same period in 2023, a 565~~18% increase.

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Anadarko, NW Stack Trend – Oklahoma

● During the three months ended ~~September~~March 3031, ~~2024~~2025, Epsilon's realized price for all Oklahoma production was $45.1229 per Mcfe (5860% natural gas), a 1617% ~~decline~~increase from the three months ended ~~September~~March 3031, ~~2023. During the nine months ended September 30,~~ 2024~~, Epsilon's realized price for all Oklahoma production was $4~~.~~31 per Mcfe (59% natural gas), a 20% decline from the nine months ended September 30, 2023.~~

● Total net revenue interest production for the three months ended ~~September~~March 3031, ~~2024~~2025 included natural gas, oil and other liquids and was 0.1009 Bcfe, a 3418% decrease from the same period in ~~2023. Total net revenue interest production for the nine months ended September 30,~~ 2024 ~~included natural gas, oil and other liquids and was 0~~.~~32 Bcfe, a 36% decrease from the same period in 2023.~~

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.

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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 nine~~ months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024, which is the most directly comparable measure of financial performance calculated under U.S. GAAP and should be reviewed carefully.

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Net income

~~366~~4,~~021~~016,034

~~388~~1,~~775~~506,896

~~2,688,577~~

~~4,349,191~~

Add Back:

Interest income, net

(433,~~095~~088)

(~~375~~257,~~972~~512)

~~(400,791)~~

~~(1,237,076)~~

Income tax expense

~~368~~1,~~398~~670,194

~~710~~54,~~164~~050

~~881,464~~

~~2,283,228~~

Depreciation, depletion, amortization, and accretion

23,~~698~~475,~~812~~857

12,~~392~~380,~~032~~426

~~7,127,641~~

~~4,780,766~~

Stock based compensation expense

309,109

439,653

944,267

799,149

Impairment expense

6,669

—

Loss on sale of assets

—

1,449,871

Stock based compensation expense

385,838

321,569

Loss on derivative contracts net of cash received or paid on settlement

441,~~677~~047,127

1589,~~370,573~~011

~~1,000,836~~

~~1,306,593~~

Foreign currency translation loss

—10,289

~~(98)~~570

~~570~~

~~(1,086)~~

Adjusted EBITDA

310,~~743~~608,~~922~~920

34,~~925~~595,~~127~~010

~~12,242,564~~

~~13,730,636~~

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Results of Operations

Net Operating Revenues

For the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 revenues increased $08.42 million, or 2102%, to $2216.62 million from $228.20 million during the same period of ~~2023~~2024.

Revenue and volume statistics for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024 were as follows:


	Three months ended				~~Nine months ended~~
	~~September~~March 3031,				~~September 30,~~
	~~2024~~2025		~~2023~~2024		~~2024~~		~~2023~~
Revenues
Pennsylvania
Natural gas revenue	$	110,~~833~~327,~~371~~894	$	12,~~873~~758,~~658~~108	$	~~6,435,027~~	$	~~10,482,695~~
Volume (MMcf)		12,~~190~~637		1,~~746~~557		~~4,032~~		~~6,035~~
Avg. Price ($/Mcf)	$	13.5492	$	1.0777	$	~~1.60~~	$	~~1.74~~
Gathering system revenue (net of elimination)	$	1,~~083~~892,~~988~~350	$	31,~~068~~935,~~996~~698	$	~~4,464,134~~	$	~~7,657,755~~
Total PA Revenues	$	212,~~917~~220,~~359~~244	$	4,~~942~~693,~~654~~806	$	~~10,899,161~~	$	~~18,140,450~~
Permian Basin
Natural gas revenue	$	~~(27~~78,~~499)~~339	$	2341,~~298~~578	$	~~11,322~~	$	~~57,742~~
Volume (MMcf)		5750		1543		~~158~~		35
Avg. Price ($/Mcf)	$	(01.~~48)~~57	$	10.5396	$	~~0.07~~	$	~~1.67~~
Natural gas liquids revenue	$	~~239~~284,~~262~~961	$	67259,~~441~~914	$	~~780,946~~	$	~~136,640~~
Volume (MBOE)		1312.1		311.24		~~39.1~~		~~7.1~~
Avg. Price ($/Bbl)	$	1823.3156	$	2122.0971	$	~~19.99~~	$	~~19.30~~
Oil and condensate revenue	$	3,~~757~~019,~~574~~495	$	~~555~~2,~~335~~486,513	$	~~9,510,780~~	$	~~1,158,750~~
Volume (MBbl)		5041.75		833.17		~~126.1~~		~~15.9~~
Avg. Price ($/Bbl)	$	7472.1172	$	6873.1987	$	~~75.45~~	$	~~72.73~~
Total Permian Basin Revenues	$	3,~~969~~382,~~337~~795	$	~~646~~2,~~074~~788,005	$	~~10,303,048~~	$	~~1,353,132~~
Oklahoma
Natural gas revenue	$	98207,~~074~~340	$	~~191~~163,~~789~~293	$	~~381,806~~	$	~~811,181~~
Volume (MMcf)		5753		8866		~~188~~		~~278~~
Avg. Price ($/Mcf)	$	13.7294	$	2.1947	$	~~2.04~~	$	~~2.92~~
Natural gas liquids revenue	$	96102,~~009~~289	$	~~160~~113,~~571~~070	$	~~315,732~~	$	~~532,655~~
Volume (MBOE)		43.17		5.4.7		~~13.4~~		~~19.0~~
Avg. Price ($/Bbl)	$	2327.6068	$	2924.7026	$	~~23.55~~	$	~~28.08~~
Oil and condensate revenue	$	~~207~~157,~~162~~937	$	~~369~~228,~~439~~569	$	~~682,755~~	$	~~1,329,521~~
Volume (MBbl)		2.72		43.70		~~8.7~~		~~17.5~~
Avg. Price ($/Bbl)	$	7770.3335	$	7977.4204	$	~~78.06~~	$	~~75.77~~
Total OK Revenues	$	~~401~~467,~~245~~566	$	~~721~~504,~~799~~932	$	~~1,380,293~~	$	~~2,673,357~~
Total Revenues	$	7,287,941	$	6,310,527	$	22,582,502	$	22,166,939
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 ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 ~~decreased~~increased by $47.56 million, or 40258%, over the same period in ~~2023~~2024. AAn ~~decrease~~increase of $1.09 million was due to ~~lower~~higher natural gas prices and aan ~~decrease~~increase of $3.5.7 million was ~~due to lower sales volumes as~~ a result of ~~natural~~previously ~~decline~~delayed turn in ~~the~~line wells ~~and~~coming ~~operator~~online ~~elected well shut-ins due to poor natural gas pricing~~ in Pennsylvania. ~~Upstream~~and ~~natural gas revenue for~~ the ~~three~~end ~~months ended September 30, 2024 decreased by $0.2 million, or 9%, over the same period in 2023. An increase~~ of ~~$0.4 million was due to higher natural gas prices and a decrease of $0.6 million was due to lower sales volumes as a result of natural decline in the wells and~~ operator -elected well shut-ins ~~due to poor natural gas pricing~~ in Pennsylvania.

Upstream natural gas liquids revenue for the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 ~~increased~~was byconstant ~~$0.4~~with ~~million, or 64% over~~ the same period in 2023. An increase of $0.7 million was due to additional sales volumes from new wells drilled and acquired in the Permian Basin and a decrease of $0.3 million was due to lower sales prices. Upstream natural gas liquids revenue for the three months ended September 302024, ~~2024~~increasing ~~increased~~ by $0.101 million, or 474% ~~over the same period in 2023~~. ~~An increase of $0.2 million was due to additional sales volumes from a new well drilled in the Permian Basin and a decrease of $0.1 million was due to lower sales prices.~~

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Upstream oil and condensate revenue for the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 increased by $70.76 million, or ~~310~~20% over the same period in ~~2023~~2024. An increase of $70.57 million was due to additional sales volumes from new wells drilled and acquired in the Permian Basin and anCanada ~~increase~~partially ofoffset ~~$0.2 million was due to slightly higher prices. Upstream oil and condensate revenue for the three months ended September 30, 2024 increased~~ by ~~$3.0 million, or 329% over the same period in 2023. An increase of $2.9 million was due to additional sales volumes from~~ a ~~new~~decrease ~~well drilled in the Permian Basin offset and an increase~~ of $0.1 million was due to slightly ~~higher~~lower prices.

Gathering system revenue ~~decreased $3.2 million, or 42%,~~ for the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 ~~over~~was ~~the~~relatively ~~same~~flat ~~period~~compared inwith ~~2023. This was primarily~~ the ~~result~~same ofperiod ~~lower anchor shipper volumes due to natural decline~~ in ~~the wells and operator elected well shut-ins~~2024, ~~offset~~decreasing ~~partially by a 17% increase in the Auburn gathering rate. Gathering system revenue decreased~~ $2.0.04 million, or 652%~~, for the three months ended September 30, 2024 over the same period in 2023~~. ~~This was primarily the result of lower anchor shipper volumes due to natural decline in the wells and operator elected well shut-ins, offset partially by a 17% increase in the Auburn gathering rate.~~ Revenues derived from transporting and compressing our production, which have been eliminated from gathering system revenues amounted to $0.36 million ~~and $0.8 million, respectively,~~ for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2024, and $0~~2025.~~3 million and $1.0 million, respectively, for the three and nine months ended September 30, 2023.~~

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 nine~~ months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024:

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Lease operating costs (net of elimination)

2,~~099~~755,~~501~~898

1,~~559~~768,~~957~~462

~~5,517,830~~

~~4,404,757~~

Gathering system operating costs

~~490~~552,~~325~~651

~~631~~552,~~725~~570

~~1,692,862~~

~~1,854,000~~

23,~~589~~308,~~826~~549

2,~~191~~321,~~682~~032

~~7,210,692~~

~~6,258,757~~

Upstream operating costs—Total $/Mcfe

10.2289

0.7989

~~1.00~~

~~0.66~~

Gathering system operating costs $/Mcf

0.2313

0.1511

~~0.39~~

~~0.16~~

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 ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 these costs increased by $1.10 million, or 2556%, over the same period in ~~2023. The increase is primarily due to the acquired and developed wells in the Permian Basin during the fourth quarter of 2023 and~~ 2024. ~~For the three months ended September 30, 2024 these costs increased by $0.5 million, or 35%, over the same period in 2023.~~ The increase is primarily due to ~~the~~higher ~~acquired and developed wells in the Permian Basin during the fourth quarter of 2023 and 2024~~volumes.

~~The~~Gathering ~~higher~~system ~~unit~~ operating costs inconsist primarily of rental payments for the ~~three~~natural gas fueled compression units and ~~nine~~overhead fees due to the system’s operator. For the three months ~~ending~~ended ~~September~~March 3031, ~~2024~~2025, gathering system operating costs were ~~primarily~~constant ~~due~~compared to the ~~higher~~same ~~liquids~~period ~~proportion~~in ~~of sales (Mcfe)~~2024.

~~Gathering~~The ~~system~~higher ~~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 nine months ended September 30, 2024,~~ gathering system unit operating costs ~~were constant, decreasing by $0.2 million, or 9% from the same period~~ in ~~2023. For~~ the three months ~~ended~~ending ~~September~~March 3031, ~~2024,~~2025 ~~gathering~~were ~~system~~primarily ~~operating~~due ~~costs~~to ~~decreased~~a ~~by $0.1 million, or 22~~17% ~~from~~decrease ~~the same period~~ in ~~2023. The decrease related to lower~~ throughput volumes.

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

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Depletion, depreciation, amortization and accretion

23,~~698~~475,~~812~~857

12,~~392~~380,~~032~~426

~~7,127,641~~

~~4,780,766~~

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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.~~

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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 nine~~ months ended ~~September~~March 3031, ~~2024~~2025 increased by $1.31 million, or 9446%, ~~and $2.3 million, or 49%, respectively,~~ from the same ~~periods~~period in ~~2023~~2024. This increase was a result of ~~the~~higher ~~new~~produced ~~production~~volumes in ~~the~~Pennsylvania ~~Permian Basin~~ and ~~a lower reserve base in Pennsylvania used in~~ the ~~calculation,~~Permian ~~driven by lower SEC realized natural gas prices~~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”)

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

General and administrative

12,~~758~~204,~~685~~256

1,~~980~~880,~~011~~592

~~5,431,081~~

~~5,959,906~~

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 ~~units~~ granted.

G&A expenses for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024 ~~decreased~~increased by $0.23 million, or 1117%, ~~and $0.5 million, or 9%, respectively,~~ from the same period in ~~2023~~2024. This was primarily due to ~~lower~~higher ~~cash~~compensation ~~bonus~~ expenses ~~and lower legal fees~~.

Interest Income

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Interest income

9615,~~220~~299

~~384~~266,~~732~~272

~~471,435~~

~~1,308,695~~

Interest income for the three ~~and nine~~ months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024 decreased by $0.3 million, or 7594%, ~~and $0.8 million, or 64%, respectively,~~ from the same period in ~~2023~~2024. This was primarily due to a reduction in the ~~amount~~balance of ~~outstanding~~cash ~~financial~~and ~~instruments in~~ short term investments.

Interest Expense

Three months ended ~~September~~March 3031,

~~Nine months ended September 30,~~

~~2024~~2025

~~2023~~2024

~~2024~~

~~2023~~

Interest expense

5312,~~125~~211

8,760

~~70,644~~

~~71,619~~

~~Interest expense is related to the fees paid on the revolving credit facility.~~28

Interest expense during the nine months ended September 30, 2024 and 2023 was materially unchanged. Interest expense for the three months ended September 30, 2024 and 2023 increased by $0.04 million, or 506%, as a result of a change in the fee structure under the new credit facility.

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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.

~~Gain (~~Loss) on Derivative Contracts


	Three months ended ~~September~~March 3031,				~~Nine months ended September 30,~~
	~~2024~~2025		~~2023~~2024		~~2024~~		~~2023~~
Gain (loss) on derivative contracts	$	440,712	$	(24,303)	$	245,095	$	1,672,535
Loss on derivative contracts	$	(1,462,170)	$	(100,726)

For the three ~~and nine~~ months ended ~~September~~March 3031, 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. ~~For~~The ~~the~~amounts ~~three~~recorded ~~and~~represent ~~nine~~the ~~months~~fair ~~ended~~value ~~September~~changes ~~30,~~on ~~2023,~~our ~~Epsilon~~derivative ~~had~~instruments ~~NYMEX~~during HHthe ~~Natural~~year. ~~Gas~~During ~~Futures~~the ~~swaps~~three ~~and~~months ~~Tennessee~~ended ~~Gas~~March ~~Pipeline~~31, ~~Zone~~2025, 4we ~~basis~~paid ~~swap~~net ~~derivative~~cash ~~contracts~~settlements ~~for~~of $415,043. During the ~~purpose~~three ofmonths ~~hedging~~ended aMarch ~~portion~~31, of2024, ~~its~~we ~~physical~~received ~~natural~~net ~~gas~~cash ~~sales~~settlements ~~revenue~~of $488,285.

~~During~~For the three ~~and nine~~ months ended ~~September~~March 3031, ~~2024~~2025, werealized ~~received~~losses ~~net~~on ~~cash~~derivative ~~settlements~~contracts ofincreased ~~$485,389~~by ~~and~~ $1~~,245,931,~~.4 ~~respectively~~million. ~~During~~This ~~the~~increase ~~three~~was ~~and~~primarily ~~nine~~the ~~months~~result ~~ended~~of ~~September~~a ~~30,~~significant ~~2023,~~increase wein ~~received~~Henry ~~net~~Hub ~~cash~~prices ~~settlements~~during ofthe ~~$1,346,270 and $2,979,128, respectively~~quarter.

For the nine months ended September 30, 2024, net gains on derivative contracts decreased by $1.4 million. This decrease was primarily the result of NYMEX Henry Hub prices not declining as much relative to the strike price of the hedge in 2024 as compared to 2023. For the three months ended September 30, 2024, net gains on derivative contracts increased by $0.5 million. This increase was primarily a result of declining NYMEX Henry Hub and WTI CMA prices in 2024. There were minimal price fluctuations for the same period in 2023.

Capital Resources and Liquidity

Cash Flow

The primary source of cash for Epsilon during the three ~~and~~months ~~nine~~ended March 31, 2025 was funds generated from operations. The primary source of cash for Epsilon during the three months ended ~~September~~March 3031, 2024 ~~and 2023~~ 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 ~~nine~~the distribution of dividends. The primary uses of cash for the three months ended ~~September~~March 3031, 2024 ~~and 2023~~ 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 ~~September~~March 3031, ~~2024~~2025, we had a working capital surplus of $76.52 million, a decrease of $250.79 million from the $337.21 million surplus at December 31, ~~2023~~2024. The Company anticipates its current cash balance, ~~short term investments,~~ available borrowings, and cash flows from operations to be sufficient to meet its cash requirements for at least the next twelve months.

~~Nine~~Three months ended ~~September~~March 3031, ~~2024~~2025 compared to ~~2023~~2024

During the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025, $~~11.~~8.6 million was provided by the Company’s operating activities, compared to $143.47 million during the same period in ~~2023~~2024, representing ana 18133% ~~decrease~~increase. The increase was primarily due to higher produced volumes and realized prices in Pennsylvania.

The Company used $116.08 million and $3711.18 million of cash for investing activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024, respectively. During the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025, the Company had net investments of $306.18 million primarily onin ~~leasehold~~well costs and ~~well~~leasehold ~~costs~~(drilling carry) in Pennsylvania, Texas, and Canada ~~offset by net proceeds of $19~~.1 ~~million in U.S. Treasury Bills.~~ During the ~~nine~~three months ended ~~September~~March 3031, ~~2023~~2024, the Company had net investments of $18.35 million in ~~U.S.~~leasehold ~~Treasury Bills~~ and ~~$18.8~~well ~~million~~costs in ~~leasehold~~Pennsylvania and ~~development~~Texas ~~costs~~offset ~~targeting~~by ~~increasing~~net ~~production~~proceeds inof ~~Pennsylvania,~~$6.7 ~~the~~million ~~Permian~~in ~~Basin,~~U.S. ~~and~~Treasury ~~Oklahoma~~Bills.

The Company used $51.94 million and $102.16 million of cash for financing activities during the ~~nine~~three months ended ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024, respectively. This was spent on dividend payments and the repurchase of shares of common stock.

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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 ~~commitment and~~ borrowing base is $45 million (redetermined onas ~~June~~of 25February 10, ~~2024~~2025), supported by the Company’s upstream assets in Pennsylvania and subject to semi-annual redeterminations with a maturity date of ~~the earlier of~~ June 28, 2027 ~~or the date that the commitments are terminated~~. 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) ~~and guaranteed by the Company and the other wholly owned subsidiaries~~. 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

On ~~March~~February 2012, ~~2024~~2025, ~~the~~Epsilon’s ~~Board~~board of ~~Directors~~directors (the “Board”) authorized a new share repurchase program of up to 2,~~191~~200,~~320~~876 common shares, representing 10% of the current outstanding common shares of Epsilon ~~at such time~~, for an aggregate purchase price of not more than US $1213.0 million. The program ~~is pursuant to a normal course issuer bid and will be conducted in accordance with Rule 10b-18 under the Exchange Act. The program~~ commenced on ~~March~~February 2712, ~~2024~~2025 and ~~will~~ends ~~end~~ on ~~March~~February 2611, ~~2025~~2026, unless the maximum amount of common shares is purchased before then or ~~Epsilon~~the ~~provides~~Board approves earlier ~~notice of~~ termination.

~~During~~The ~~the~~previous ~~three~~share ~~and~~repurchase ~~nine~~program ~~months~~commenced on March 19, 2024. During the year ended ~~September~~December 3031, 2024, we repurchased 125,000 common shares ~~have~~and ~~been~~spent ~~repurchased~~$627,500 at aan average price of $5.00 per share (excluding commissions) under the ~~new program~~plan. ~~These~~On ~~shares~~February ~~are~~12, ~~currently~~2025, ~~held~~the inBoard ~~treasury~~terminated and ~~will~~revoked beauthority ~~retired~~under ~~during~~ the ~~fourth quarter of 2024~~program.

During the nine months ended September 30, 2024, the Company repurchased 373,700 shares at a price of $4.88 per share (excluding commissions) under the two consecutive repurchase programs.

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.

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At ~~September~~March 3031, ~~2024~~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		~~September~~March 3031, ~~2024~~2025
2024
NYMEX Henry Hub swap	457,500	$	3.24	$	45,693
Tennessee Z4 basis swap	305,000	$	(1.04)	$	(65,925)
	762,500			$	(20,232)
2025
NYMEX Henry Hub swap	~~675~~1,564,000	$	3.4721	$	33(1,~~990~~872,793)
Tennessee Z4 basis swap	~~675~~1,564,000	$	(0.7495)	$	~~(107~~250,~~588)~~785
	13,~~350~~128,000			$	(731,~~598~~622,008)


				Fair Value
	Volume	Weighted Average		~~September~~March 3031,
Derivative Type	(Bbl)	Price ($/Bbl)		~~2024~~2025
2024
Crude Oil NYMEX WTI CMA	14,983	$	74.34	$	98,978
2025
Crude Oil NYMEX WTI CMA	1347,~~162~~000	$	7471.3417	$	9487,~~271~~333
	2847,~~145~~000			$	~~193~~87,~~249~~333

Contractual Obligations

The Company enters into commitments for capital expenditures in advance of the expenditures being made. As of ~~September~~March 3031, ~~2024~~2025, the Company has no ~~unpaid short term~~ commitments for capital expenditures and has long term commitments of $15.27 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 ~~September~~March 3031, ~~2024~~2025 and ~~2023~~2024, the outstanding principal balance under the credit agreement was nil.

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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.

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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 ~~September~~March 3031, ~~2024~~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 ~~September~~March 3031, ~~2024~~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, ~~2023~~2024.

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

~~The~~For ~~following~~the ~~table~~three ~~contains~~months ~~information~~ended ~~about~~March ~~our~~31, ~~acquisition~~2025, ofno ~~equity~~shares ~~securities~~had ~~during~~been ~~the nine months ended September 30, 2024~~repurchased.


				Maximum number
				of shares
	Total number	Average price		remaining to be
	of shares	paid per		purchased under
	purchased	share		the program
Beginning of normal-course issuer bid, March 27, 2023 (1)					1,324,495
January 2024	248,700	$	4.82
Total as of March 26, 2024	248,700	$	4.82		1,075,795

Beginning of normal-course issuer bid, March 27, 2024 (2)					2,191,320
September 2024	125,000	$	5.00
Total as of September 30, 2024	125,000	$	5.00		2,066,320

(1) Epsilon repurchased these shares under its 2023-2024 share repurchase program that commenced on March 27, 2023 and terminated on March 26, 2024.

(2) Epsilon repurchased these shares under its 2024-2025 share repurchase program that commenced on March 27, 2024 and terminates on March 26, 2025.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

Not applicable.

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ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

Not applicable.

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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: November 6, 2024	By:	/s/ J. Andrew Williamson
Date: May 14, 2025	By:	/s/ J. Andrew Williamson
		J. Andrew Williamson
		Chief Financial Officer

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Three months ended March 31,

Impairment

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