Form 8-K

8-K — Epsilon Energy Ltd.

Accession: 0001104659-26-098127

Filed: 2026-08-18

Period: 2026-08-17

CIK: 0001726126

SIC: 1311 (CRUDE PETROLEUM & NATURAL GAS)

Item: Regulation FD Disclosure

Item: Financial Statements and Exhibits

Documents

8-K — epsn-20260817x8k.htm (Primary)

EX-99.1 (epsn-20260817xex99d1.htm)

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8-K

8-K (Primary)

Filename: epsn-20260817x8k.htm · Sequence: 1

EPSILON ENERGY LTD._August 17, 2026

0001726126false00017261262026-08-172026-08-17

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the

Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): August 17, 2026

EPSILON ENERGY LTD.

(Exact name of registrant as specified in charter)

Alberta, Canada

001-38770

98-1476367

(State or Other Jurisdiction of Incorporation)

(Commission File Number)

(I.R.S. Employer Identification Number)

500 Dallas St., Suite 1250

Houston, Texas 77002

(Address of principal executive offices, including zip code)

(281) 670-0002

(Registrant’s telephone number, including area code)

Not Applicable

(Former name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

☐ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) Securities registered pursuant to Section 12(b) of the Act:

Title of each class:

Trading Symbol(s)

Name of each exchange on which registered:

Common Shares, no par value

EPSN

NASDAQ Capital Market

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter). ☐ 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. ☐

Item 7.01 Regulation FD Disclosure.

On August 17, 2026, the Company issued its August 2026 corporate presentation. A copy of the presentation is attached hereto as Exhibit 99.1 and is incorporated herein by reference.

Item 9.01 Financial Statements and Exhibits.

(d) Exhibits

Exhibit

Number

Description

99.1*

Epsilon Energy's August 2026 Corporate Presentation

104

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

*Filed or furnished herewith

SIGNATURES

Pursuant to the requirements 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 hereunto duly authorized.

EPSILON ENERGY LTD.

Date: August 18, 2026

By:

/s/ J. Andrew Williamson

J. Andrew Williamson

Chief Financial Officer

EX-99.1

Filename: epsn-20260817xex99d1.htm · Sequence: 2

Exhibit 99.1

Epsilon Energy

Multi-Basin High Growth Small Cap

Corporate Presentation - August 2026

Disclaimers

Certain statements contained in this presentation constitute forward looking statements. The use of any of the words “anticipate”, “continue”, “estimate”, “expect”, ‘may”, “will”, “project”, “should”,

‘believe”, and similar expressions are intended to identify forward-looking statements. These statements involve known and unknown risks, uncertainties and other factors that may cause actual

results or events to differ materially from those anticipated. Forward-looking statements are based on reasonable assumptions, but no assurance can be given that these expectations will prove to be

correct. There are a number of important factors that could cause actual results to differ materially from those suggested or indicated by the forward-looking statements. Additional information

regarding the factors that may cause actual results to differ materially from these forward-looking statements is available in our filings with the Securities and Exchange Commission, including but not

limited to our Annual Report on Form 10-K for the year ended December 31, 2025 and our Quarterly Reports on Form 10-Qfor subsequent periods.

The reserves and associated future net revenue information set forth in this presentation are estimates only. In general, estimates of oil and natural gas reserves and the future net revenue therefrom

are based upon a number of variable factors and assumptions, such as production rates, ultimate reserves recovery, timing and amount of capital expenditures, ability to transport production,

marketability of oil and natural gas, royalty rates, the assumed effects of regulation by governmental agencies and future operating costs, all of which may vary materially from actual results. For

those reasons, estimates of the oil and natural gas reserves attributable to any particular group of properties, as well as the classification of such reserves and estimates of future net revenues

associated with such reserves prepared by different engineers (or by the same engineers at different times) may vary. Our actual reserves may be greater or less than those calculated. In addition, our

actual production, revenues, development and operating expenditureswill vary fromestimates thereof and such variations could be material.

Statements relating to "reserves" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described exist

in the quantities predicted or estimated and can be profitably produced in the future. There is no assurance that forecast price and cost assumptionswill be attained and variances could be material.

Proved reserves are those reserves which are most certain to be recovered. Probable reserves are those additional reserves that are less certain to be recovered than Proved reserves but which,

together with Proved reserves, are as likely as not to be recovered. Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for

example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (Proved or Probable) to

which they are assigned.

The estimates of reserves and future net revenue for individual properties may not reflect the same confidence level as estimates of reserves and future net revenue for all properties due to the effects

of aggregation. The estimated future netrevenues contained in this presentation do not necessarily representthe fair market value of our reserves.

Viewers are cautioned that the assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be imprecise, and as such, undue

reliance should not be placed on forward-looking statements. Our actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking

statements, and accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or, if any of them do, what benefits that we will

derive therefrom. We disclaim any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. This presentation is

neither an offer to sell nor a solicitation of any offer to buy any securities. This presentation does not contain all of the information necessary to make an investment decision.

The contents of this presentation are based upon conditions as they exist on the date of this presentation, and, except where otherwise indicated, reflect information as at the date of this

presentation. By delivering this presentation we do not undertake to update any of the information, representations, or conclusions contained herein. The information and comments provided are

strictly for information purposes only, and are not to be construed in any way as invitations to purchase securities, nor distributed to others for said purpose.

Epsilon – Key Take-Aways

• Multi-year transformation from a single-basin and commodity concentrated non-op to a diversified

platform across 3 basins with deep inventory and operated control

• Growth inflection starting in 2H 2026, carrying into 2027

• Near term value catalysts: operated activity ramp in PRB, scaled operator ramp in the Permian, higher pace

of development with associated midstream throughput in the Marcellus

• Plan to drive >20% annual production CAGR (also on a per share basis) over the next 2 years (2026 – 2028)

while maintaining leverage below 1.5X

Total Production (MMCFE) Adjusted EBITDA ($M)

4% Oil

FY 2026 Guidance Mid-point

6 mos.

28% Oil

Epsilon – At A Glance

Ticker: EPSN (Nasdaq) Enterprise Value1: $208 MM

Q2 Net Total Production:

33.9 MMcfe/d (25% Oil)

Q2 Net Oil Production:

1,380 Bbl/d

Leverage2:

0.9X (LTM EBITDA)

Regular Annual Dividend:

$0.25 p/share

47,100 net acres3 ADTV: 180,000 shares

90-Day AVG4

Mid-Point 2026 Guidance:

38.4 MMcfe/d (Total Prod)

+13% vs. Q2 Actual

Mid-Point 2026 Guidance:

1,795 Bbl/d (Oil Prod)

+30% vs. Q2 Actual

Dev Location Inventory (Net):

216 (Total)

Dev Location Inventory (Net):

115 (Priority5)

• Diversified upstream business across the Powder River Basin,

Marcellus, and Permian coupled with a capital efficient

midstream platform

• Management team has materially expanded inventory,

operational control and strategic flexibility since mid-2022

• 115 net drilling locations with average lateral length of 10,300

CLL ft. and average returns of 45% IRR ($70 WTI and $3.50 HH)

• Active development program across all three core assets:

- New development in the Powder River Basin (PRB) began

in early Q3 2026 (Parkman)

- Ongoing Permian Barnett development with acceleration

under new operator (Firebird II)

- 15 gross Marcellus wells expected online through

YE2028

• Multiple near-term value catalysts:

• Development pace inflection starting in Q3 2026 across

all three core areas, led by operated PRB

• PRB shale inventory acceleration opportunities through

partnerships

• Increased throughput in the AGGS midstream asset

expected to start in Q4 2026, accelerating in 2027

Statistics Executive Summary

1. Using closing share price of $5.94 on 8.12.26

2. Net Debt / LTM EBITDA (as of 6.30.26) – Q3 & the first half of Q4 2025 EBITDA does not reflect PRB assets (closed Nov 2025)

3. Excludes WCSB assets

4. 90 days from 8.12.26

5. Defined as >45% WI, >8,000 CLL ft., and >25% IRR @ $70 WTI / $3.50 HHUB

Asset Portfolio Overview

Appalachian Basin Marcellus (Non-Operated)

Epsilon - PRB Operator and Project Based Non-Op in the Marcellus & Permian

• Core non-op position in the most economic dry gas play in NAM - operated by Expand Energy

• 5,100 net acres (95% HBP)

• 21.7 MMcf/d NRI production (146 producing wells) YTD 20261

• 218.2 Bcf net Proved + Probable reserves (12/31/25)2

• Substantial undeveloped Marcellus inventory: ~400-450K ft. CLL gross (EPSN ~21% WI)

1. 6mos. through 6.30.26

2. Independent reserve report (DeGolyer & McNaughton (YE25 SEC Reserves Report)

3. Defined as >45% WI, >8,000 CLL ft., and >25% IRR @ $70 WTI / $3.50 HHUB

Powder River Basin (PRB) (Majority Operated)

• Majority – operated acreage position in core PRB (37,800 net acres – 75% HBP)

• 1,868 BOE/d NRI production (149 producing wells (107 operated), 57% oil) YTD 20261

• 70.1 MMboe net Proved + Probable reserves (50% oil) (12/31/25)2

• Experienced operating team with 10+ years of basin experience

• 101 net priority3 locations across multiple conventional and unconventional formations

• Scalable platform with full control of investment pace

Permian Basin Barnett (Non-Operated)

• Non-op position on the CBP – Mississippian Barnett development

• 4,100 net acres – 25% WI in ~16,600 gross contiguous acres (12,940 undeveloped)

• 573 BOE/d NRI production (66% oil, 9 producing wells) YTD 20261

• 2.57 MMboe net Proved + Probable reserves (12/31/25)2

• Substantial undeveloped Barnett inventory: ~450K ft. CLL gross

Appalachian Basin Marcellus Midstream (Non-Operated) 4

Powder River Basin

Wyoming

Appalachian Basin

Pennsylvania

Permian Basin 3 Texas

• 35% ownership in 45 mile gathering system

• Operated by the Williams Companies

• 155 MMcfd max capacity at 450 psig target suction pressure.

• 94 MMcf/d gathered YTD 20261

WCSB (Alberta) 5

• JV with Canadian private operator

• 25% WI in >100,000 gross acres

• 2 producing wells

• 25+ 2-mile locations identified in Garrington area (est. 30K acres)

• Currently does not compete for capital in the portfolio

5 WCSB

Alberta

Opportunities for Capital Allocation (Unique Attribute for Micro-Cap E&P)

Portfolio Growth Drivers

1. Defined as >45% WI, >8,000 CLL ft., and >25% IRR @ $70 WTI / $3.50 HHUB

2. Company weighted average type curves

3. $70 WTI / $3.50 HHUB (then less applicable basis)

OCF = Revenues – Operating Expenses

Upper Marcellus2 PRB U Nio (Camp)2 PRB Parkman2 Permian Barnett2

Per Net Well

D&C Capital: $11.1MM

IRR3: 71%

12 mos. Prod: 6.0 BCF (8/8)

AVG Gross CLL (Ft.): 14,500

Inventory: 7 net locations

Non - Operated Operated Operated

Per Net Well

D&C Capital: $12.6MM

IRR3: 32%

12 mos. Prod: 218 MBOE (8/8)

74% Oil

AVG Gross CLL (Ft.): 11,200

Inventory: 26 net locations

Per Net Well

D&C Capital: $7.9MM

IRR3: 72%

12 mos. Prod: 178 MBOE (8/8)

92% Oil

AVG Gross CLL (Ft.): 10,000

Inventory: 17 net locations

Non - Operated

Per Net Well

D&C Capital: $14.9MM

IRR3: 53%

12 mos. Prod: 300 MBOE (8/8)

88% Oil

AVG Gross CLL (Ft.): 14,700

Inventory: 7 net locations

Total Inventory: 216 net locations Priority1 Inventory: 116 net locations

PRB Turner (Conv)2

Operated

Per Net Well

D&C Capital: $6.2MM

IRR3: 80%

12 mos. Prod: 150 MBOE (8/8)

81% Oil

AVG Gross CLL (Ft.): 8,200

Inventory: 16 net locations

Focus area, type curve details below

Powder River Basin Overview (Operated)

• Core 37,800 net acre PRB position, directly offset premier operators in

both Campbell and Converse County, WY.

» Net Production: 1,868 Boe/d (57% oil) (YTD 2026)

» Average Operated WI: 53% / Average Lease NRI: 80%

» 31,000 acres remain undeveloped (average across 5

formations)

• Provides a platform for controlled capital spending

» Leasehold is ~75% HBP with no continuous drilling

obligations

• Acreage covers four proven development formations, well delineated

by Peak and offset operators.

» Conventional targets: Parkman, Turner

» Unconventional targets: Niobrara, Mowry

» Priority Inventory1 (Net): Parkman (17), Turner (35), Niobrara

(26), Mowry (24)

» 1H 2026 activity - completed 2 gross Niobrara DUCS (34%

WI)

» 2H 2026 planned activity – drilling and completion of 3 gross

Parkman wells (72% WI)

Summary PRB Position Map

1. Defined as >45% WI, >8,000 CLL ft., and >25% IRR @ $70 WTI / $3.50 HHUB

Permian Basin Overview

• Ector Co. TX working interest

» Scaled position in one of the hottest plays in the basin

(Barnett) with an experienced PE backed operator

» 25% working interest in 16,600 gross acres (4,100 net

acres)

» Barnett 3-mile type curve: EUR 113 BOE/ft (80% Oil)

» All 9 wells drilled to date on the position are performing at

or above the type curve

» 9 gross (2.25 net) wells currently producing

• 12,940 gross acres remain undeveloped

» 30 estimated additional gross undeveloped Barnett

locations (7 net), assuming 3-4 wells per section spacing

• Additional potential in the Woodford

» Operator plans to complete the first Woodford test well

in 2H26 (EPSN non-consented the well)

• 1H 2026 activity – drilled and completed 1 gross (0.25 net) 3-mile

Barnett well, production came online in July

• 2H 2026 activity - drilling 2 gross (0.5 net) Barnett wells,

completions expected in Q1 2027

Summary Ector Co. Position

Marcellus – Upstream Overview

• 5,100 net acres in Susquehanna County, PA

» Majority operated by Expand Energy

• 146 gross (26.4 net) working interest producing wells

• Estimated 400K-450K gross CLL ft. of undeveloped inventory

remaining – 31 gross Marcellus locations

• Located in the core of the one of the lowest cost natural gas

basins in the country, in partnership with one of the largest

natural gas operators in the country

• Material upside through incremental development (see slide 11)

• Current operator plan calls for the development of 15 gross wells

through YE2028

• Current 2026 plans include the development of 5 gross wells

(0.4 net) which have been drilled. Completion operations are

scheduled for late Q426.

Summary Interest in Core NE PA Marcellus

Marcellus – Midstream Overview

Summary Auburn Compression Facility: Susquehanna Co., PA

• 35% interest in the Auburn Gas Gathering System (GGS)

• Partners: Williams Companies (operator) & Equinor

• 45 miles of gathering pipelines

• Current system capacity 155 MMcf/d at current 450 psig

target suction pressure

• Gas discharges into Tennessee Gas Pipeline, Zone 4

• Reserves dedications from shippers Expand, Equinor & Epsilon

» System supports ~ 1 TCF of 8/8ths dedicated reserves1

• Fixed rate contract – 2026 gathering fee is $0.502 /MMBTU2

• High margin gathering revenue through the natural gas price cycle

(20+ years useful life remaining)

• 94 MMcf/d gathered YTD 2026

» >60 MMcf/d of excess capacity for Auburn volumes at

current target suction pressure3

• Expansion project at Auburn CF under review; additional CAT

3612 compressor anticipated for development volumes in 2028+3

• Large upside to midstream earnings with incremental Auburn

area development (see slide 8)

1. Per 2025 year-end third-party reserves report completed by DeGolyer & MacNaughton (Proved + Probable, including reserves dropped out due to SEC pricing)

2. Escalates annually at CPI-U

3. Total capacity can be increased to >200 MMcf/d with additional compression

Leverage to Incremental Marcellus Development

• First 12 mos. net contribution from a notional 4 gross well pad

development (assumes 25% WI / 22% NRI):

» Est. incremental 12 mos. net gas volumes: 4.7 Bcf

» Est. incremental 12 mos. OCF: $9.6MM ($3.50 HHUB1)

» Est. net investment: $10.8 MM

• Expand (operator) current development plans include 15 gross

wells drilled in Auburn over 2026-2028 (EPSN average WI: ~20%)

Auburn - 4 Well Upper Marcellus Pad (56K Gross CLL ft.) Auburn GGS – Cash Flow Sensitivity to Annual Throughput

16.0

20.5

17.7

15.6

14.0

12.7

11.610.7 9.9 9.3 8.7 8.2

$2,000

$4,000

$6,000

$8,000

$10,000

$12,000

0.0

5.0

10.0

15.0

20.0

25.0

1 2 3 4 5 6 7 8 9 10 11 12

MMcf/d

Months From TIL

Net Gas (Daily) Cum OCF

$5,141

$6,798

$8,454

$10,111

$11,768

$2,000

$4,000

$6,000

$8,000

$10,000

$12,000

$14,000

100,000 125,000 150,000 175,000 200,000

Annual Average Daily Throughput (MMcf/d)

Annual OCF

• 2026 YTD2 Throughput: 94 MMcf/d

• Incremental est. throughput (first 12 mos.) from 4 well pad: 60

MMcf/d

• Assumes 2026 fee structure - $0.50 / MMbtu gathering, $ 0.11 /

MMbtu compression (escalates annually at CPI-U)

OCF = Revenues – Operating Expenses OCF = Revenues – Operating Expenses

1. Assumes $(0.76) differential (Tenn Z4)

2. Through 6.30.26

Leverage to Incremental Barnett and PRB Development

• First 12 mos. net contribution from a notional 4 gross well pad

development (assumes 22% WI / 17% NRI ):

» Net volumes: 242 MBoe (73% oil)

» OCF: $10.8MM ($70 WTI, $3.50 HHUB)

» Est. net investment: $14.8MM

• Company expects pad development to commence on the project

over the next 12-18 mos.

Permian - 4 Well 3-mile Barnett Pad (67K Gross CLL ft.) PRB - 3 Well Parkman Converse Co. Pad (26K Gross CLL ft.)

809

911

851

775

713

662

619 582 549 521 496 474

$2,000

$4,000

$6,000

$8,000

$10,000

$12,000

100

200

300

400

500

600

700

800

900

1,000

1 2 3 4 5 6 7 8 9 10 11 12

BOE/d

Months From TIL

Net BOE (Daily) Cum OCF

OCF = Revenues – Operating Expenses OCF = Revenues – Operating Expenses

1,389

1,818

1,442

1,212

1,057

935

832

750 684 630 584 544

2,000

4,000

6,000

8,000

10,000

12,000

14,000

16,000

18,000

20,000

200

400

600

800

1,000

1,200

1,400

1,600

1,800

2,000

1 2 3 4 5 6 7 8 9 10 11 12

BOE/d

Months From TIL

Net BOE (Daily) Cum OCF

• First 12 mos. net contribution from a notional 3 gross well pad

development (assumes 81% WI, 65% NRI):

» Net volumes: 361 MBoe (90% oil)

» OCF: $18.5MM ($70 WTI, $3.50 HHUB)

» Est. net investment: $16.5MM

• Current plans are to initiate Converse Co. Parkman pad

development in 1H27.

• >$100MM of net investment potential in the existing Parkman

inventory

Q3 2026 and FY 2026 Production & Capital Guidance

Q3 2026 & FY2026 Basin Breakout / 2H 2026 Capital Program

Primary components of the capital program for 2H2026:

• Drilling and completion of 3 gross (2.1 net) Parkman wells in the

PRB (operated)

• Facilities build-out in preparation for 2027 drilling plans in the

PRB (operated)

• Drilling of 2 gross (0.5 net) Barnett wells in the Permian Basin

(non-operated), completions are expected in Q127

• Completion of 5 gross (0.4 net) Marcellus wells (non-operated)

Q3 2026 FY 2026

Production Ranges

Total (MMcfe) [3,270 – 3,510] [13,740 – 14,280]

Midpoint Daily (MMcfe/d) [35.6 – 38.2] [37.6 – 39.1]

Oil (MBbl) [155 – 165] [640 – 670]

Midpoint Daily (BO/d) [1,686 – 1,793] [1,753 – 1,836]

Midpoint

Sequential Growth

Total +10% +18%

Oil +27% +194%

Capital Ranges

D&C ($MM) [19.9 – 23.6] [32.1 – 35.9]

Facilities ($MM) [3.7 – 4.4] [7.1 – 8.0]

Other1 ($MM) [0.4 – 0.5] [2.1 – 2.3]

Midstream ($MM) 0 [0.7 – 0.8]

Total ($MM) [24.0 – 28.5] [42.0 – 47.0]

50%

38%

12%

Q3 2026 - Total Production

37% 53%

10%

FY 2026 - Total Production

88%

10%

Q3 2026 - Total Capital

10%

72%

17%

FY 2026 - Total Capital

1. Leasehold and capitalized workover expense

Disclosures

Non-GAAP Financial Measures

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) transaction costs, (7) gain or loss on derivative contracts net of cash received or paid on settlement, (8) gain or loss on sale of assets, and (9)

gain or loss on foreign currency translations.

Additionally, Adjusted EBITDA may not be comparable to other similarly titled measures of other companies. Epsilon has included Adjusted EBITDA as a supplemental disclosure because its

management believes that EBITDA provides useful information regarding its ability to service debt and to fund capital expenditures. It further provides investors a helpful measure for comparing

operating performance on a "normalized" or recurring basis with the performance of other companies, without giving effect to certain non-cash expenses and other items. This provides management,

investors and analysts with comparative information for evaluating the Company in relation to other natural gas and oil companies providing corresponding non-U.S. GAAP financial measures or that

have different financing and capital structures or tax rates. These non-U.S. GAAP financial measures should be considered in addition to, but not as a substitute for, measures for financial

performance prepared in accordancewith U.S. GAAP.

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v3.26.1

Document and Entity Information

Aug. 17, 2026

Document and Entity Information [Abstract]

Document Type

8-K

Document Period End Date

Aug. 17, 2026

Entity Registrant Name

EPSILON ENERGY LTD.

Securities Act File Number

001-38770

Entity Incorporation, State or Country Code

Entity Tax Identification Number

98-1476367

Entity Address, Address Line One

500 Dallas St.

Entity Address, Address Line Two

Suite 1250

Entity Address, City or Town

Houston

Entity Address, State or Province

Entity Address, Postal Zip Code

77002

City Area Code

281

Local Phone Number

670-0002

Written Communications

false

Soliciting Material

false

Pre-commencement Tender Offer

false

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Title of 12(b) Security

Common Shares, no par value

Trading Symbol

EPSN

Security Exchange Name

NASDAQ

Entity Emerging Growth Company

false

Entity Central Index Key

0001726126

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