EPSN - Epsilon Reports Second Quarter 2020 Results

HOUSTON, Aug. 13, 2020 (GLOBE NEWSWIRE) -- Epsilon Energy Ltd. (“Epsilon” or the “Company”) (NASDAQ: EPSN) today reported second quarter 2020 financial and operating results and material subsequent events following the end of the quarter through the date of this release.

• Net cash provided by operations of $3.1 million and $8.3 million for the three and six months ended June 30, 2020, respectively, with free cash flow (FCF) of $1.3 million and $4.2 million for the same periods.
  
  
• Realized gas prices of $1.36/Mcfe, (excluding hedges) and $1.75/Mcfe (including hedges).
   
• Returned $0.4 million to shareholders through open market purchases of 169,285 shares through June 30, 2020 for an average price of $2.51/share. Following the June 30, 2020 deadline for the previously announced Tender Offer, $7.15 million was returned to shareholders in exchange for 2,337,034 shares which were properly tendered representing 8.9% of outstanding shares for $3.06/share.
   
• Marcellus net revenue interest (NRI) gas production averaged 30.6 MMcf/d (Working Interest of 35.2 MM/d) for the second quarter.
   
• During the second quarter the Marcellus operator turned to sales 4 Gross wells (0.16 Net wells). In addition, during the quarter, at the request of the upstream producers (including Epsilon), the operator of the Auburn System reduced the gathering pressure in a step-wise manner to 550 psi from the historical gathering pressure of 700 psi. This reduced pressure allowed all wells to increase production in varying degrees. The June 30^th, 2020 NRI exit rate was 39.6 MMcf/d (Working Interest of 45.5 MMcfe/d).
   
• Auburn System gathered and delivered 15.6 Bcfe gross (5.5 Bcfe net to Epsilon’s interest) which represents approximately 86% of maximum throughput as currently configured. The June 30^th exit gathering volume rate was 183.6 MMcf/d.
   
• Total revenues of $6.3 million; net loss of $0.6 million; and EBITDA of $3.1 million for the quarter.
   
• Cash at quarter end of $16.3 million.
   
• Net loss before tax of $0.74 million for the quarter included a bad debt allowance of $0.82 million.
   
• Operating expenses including SG&A was $1.19/Mcfe and $1.09/Mcfe excluding $0.3 million of non-recurring legal costs.

Michael Raleigh, CEO, commented, “We are very pleased with the financial performance of the company as we continue to generate free cash flow even within a challenged price environment. At the current production rate and natural gas prices for the remainder of the year we anticipate the company should be able to generate $9.0 - $10.0 million of free cash flow for the full year. We anticipate exiting the year between 32-33 MMcfe/d of NRI production.  Epsilon recorded a bad debt reserve of $0.8 million related to a receivable from a shipper on the Auburn Gas Gathering system who filed for bankruptcy protection during the quarter. Post-filing, the shipper continues to invest capital in both existing and new wells in the contract area. While we ultimately believe that it is possible that some, if not all, of this receivable may be collected, the timing is uncertain, and therefore we recognized this as an allowance for bad debt. As anticipated, the restraint in capital spending across the E&P industry that began in the first quarter of 2020 is having a meaningful impact on natural gas supply. Although the natural gas supply/demand balance has been disappointing this past quarter due to exiting the mild winter with high storage levels and the curtailment of LNG exports, the market is beginning to discount a much tighter balance in 2021 as evidenced by higher prices for future delivery of natural gas.

In June, Epsilon elected to participate in three new wells proposed by the operator. While Epsilon’s net interest is minor, these wells are all long reach horizontals, and two of the wells are targeting the Upper Marcellus zone which should provide more productivity data on the Upper Marcellus helping us to better understand how to efficiently develop the significant potential of our acreage.”

Financial and Operating Results

Capital Expenditures

Epsilon’s capital expenditures were $1.2 million for the three months ended June 30, 2020.  This capital was mainly residual spending for the completion of four wells drilled in Q1 2020 in Pennsylvania as well as expenditures for the Auburn Gas Gathering system.

Marcellus Operational Guidance

During the second quarter of 2020, the operator completed, tested and turned to sales 4 gross (0.16 net to EPSN) wells. In June, the operator proposed 3 gross (.03 net to EPSN) wells in which Epsilon elected to participate with a required capital commitment of less than $250,000.

Second Quarter Results

Epsilon generated revenues of $6.3 million for the three months ended June 30, 2020 compared to $6.8 million for the three months ended June 30, 2019.

Realized natural gas prices averaged $1.36/Mcf (excluding hedges) for Marcellus Upstream operations in the second quarter of 2020. Operating expenses for Marcellus Upstream operations in the second quarter were $1.4 million.

The Auburn Gas Gathering system delivered 15.6 Bcfe of natural gas during the quarter as compared to 23.3 Bcfe during the first quarter of 2020.  Primary gathering volumes were flat quarter over quarter at 15.1 Bcfe.  Imported cross-flow volumes decreased 94% to 0.5 Bcfe.

Epsilon reported net after tax loss of $0.6 million attributable to common shareholders or $0.02 per basic and diluted common share outstanding for the three months ended June 30, 2020, compared to net income of $3.8 million, and $0.14 per basic and diluted common share outstanding for the three months ended June 30, 2019. 

For the three months ended June 30, 2020, Epsilon's Adjusted Earnings Before Interest, Taxes, Depreciation, Amortization ("Adjusted EBITDA") was $3.1 million as compared to $5.2 million for the three months ended June 30, 2019.

Recent Developments

Epsilon is closely monitoring the current and potential impacts of the COVID-19 pandemic on all aspects of our business and geographies, including how it has impacted, and may in the future impact our operations, financial results, liquidity, contractors, customers, employees and vendors. Epsilon has also taken, and is continuing to take, proactive steps to manage any disruption in our business caused by COVID-19. For instance, the Company was an early adopter in employing a work-from-home system, even before any government mandate on non-essential businesses was enacted. Epsilon increased its technology platform, infrastructure and security to allow for a work-from-home environment ahead of the actual need, and therefore, once the hypothetical became a reality, we believe Epsilon was ahead of many companies in this respect. Epsilon has also deployed additional layered safety protocols at our office in order to keep our employees safe and to keep our operations running without material disruption.

About Epsilon

Epsilon Energy Ltd. is a North American onshore natural gas production and midstream company with a current focus on the Marcellus Shale of Pennsylvania and the Anadarko Basin in Oklahoma.

Forward-Looking Statements

Certain statements contained in this news release 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 and the forward-looking statements included in this news release should not be unduly relied upon.

The reserves and associated future net revenue information set forth in this news release 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. The actual reserves of the Company may be greater or less than those calculated. In addition, the Company's actual production, revenues, development and operating expenditures will vary from estimates 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 assumptions will be attained and variances could be material.

Proved reserves are those reserves which are most certain to be recovered. There is at least a 90% probability that the quantities actually recovered will equal or exceed the estimated proved reserves.  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, probable) to which they are assigned. Proved undeveloped reserves are those reserves that can be estimated with a high degree of certainty and are expected to be recovered from known accumulations where a significant expenditure is required to render them capable of production.

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 net revenues contained in this news release do not necessarily represent the fair market value of the Company's reserves.

Contact Information:

281-670-0002
Michael Raleigh
Chief Executive Officer
Michael.Raleigh@EpsilonEnergyLTD.com

Special note for news distribution in the United States
The securities described in the news release have not been registered under the United Stated Securities Act of 1933, as amended, (the “1933 Act”) or state securities laws. Any holder of these securities, by purchasing such securities, agrees for the benefit of Epsilon Energy Ltd. (the “Corporation”) that such securities may not be offered, sold, or otherwise transferred only (A) to the Corporation or its affiliates; (B) outside the United States in accordance with applicable state laws and either (1) Rule 144(as) under the 1933 Act or (2) Rule 144 under the 1933 Act, if applicable.

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

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

Epsilon defines Free cash flow (“FCF”) as net cash provided by operating activities in the period minus payments for property and equipment made in the period. FCF is considered a non-GAAP financial measure under the SEC’s rules. Management believes, however, that FCF is an important financial measure for use in evaluating the Company’s financial performance, as it measures our ability to generate additional cash from our business operations. FCF should be considered in addition to, rather than as a substitute for, net income as a measure of our performance or net cash provided by operating activities as a measure of our liquidity. Additionally, our definition of FCF is limited and does not represent residual cash flows available for discretionary expenditures due to the fact that the measure does not deduct the payments required for debt service and other obligations, payments made for business acquisitions, or amounts spent to buys back shares. Therefore, we believe it is important to view FCF as supplemental to our entire statement of cash flows.