HOUSTON, TEXAS–(Marketwired – July 23, 2015) – Epsilon Energy Ltd. (“Epsilon” or the “Company“) (TSX:EPS) today reported second quarter 2015 financial and operating results.
Mr. Michael Raleigh, Chief Executive Officer, commented, “Despite the challenging macro energy environment, the company has continued to generate positive cash and at the end of Q2 had over $19MM in cash.
As in Q1 we voluntarily imposed production ceilings during the quarter. We are, as other operators in the area, attempting to balance local and regional demand with the very robust productivity of the basin.
We continue to develop our industry relationships in anticipation of better markets for our gas production and appraise and develop our considerable inventory of high productivity gas resources in the Lower and Upper Marcellus. We are pleased with the contribution of our Midstream assets to the positive cash flow position the company has established”.
Highlights for the second quarter and material subsequent events following the end of the quarter through the date of this release include:
- Upstream EBITDA of $1.1 million and Midstream EBITDA of $3.0 million for the quarter.
- Marcellus working interest (WI) gas production averaged 35 MMcf/d for the second quarter of 2015. Working interest gas production as of this release is approximately 30 MMcf/d in order to voluntarily manage production ceilings.
- Gathered and delivered 30 Bcfe gross (10.5 Bcfe net to Epsilon’s interest) during the quarter, or 329 MMcfe/d through the Auburn System which represents approximately 91% of maximum throughput. Current system throughput is averaging 267 MMcfe/d.
- Auburn Gas gathering and compression services included third party gas of 4.1 Bcfe during the quarter or approximately 45 MMcf/d.
Financial and Operating Results
|Three months ended
|Six months ended
|Revenue by product – total period ($000)|
|Natural gas revenue ($000)||$||3,450||$||11,748||$||6,671||$||25,850|
|Avg. Price ($/Mcfe)||$||1.25||$||2.86||$||1.32||$||3.15|
|Exit Rate (MMcfepd)||30.7||48.5||30.7||48.5|
|Oil revenue ($000)||$||–||$||–||$||2||$||196|
|Avg. Price ($/Bbl)||$||–||$||–||$||80.66||$||80.66|
|Midstream gathering system revenue ($000)||$||3,719||$||3,298||$||7,142||$||6,625|
Epsilon’s total capital expenditures were $1.8 million for the three months ended June 30, 2015. $0.5 million was allocated to completing Marcellus wells, and $1.3 million was allocated to the Auburn Gas Gathering system.
Epsilon’s 2015 capital forecast for the remainder of the year is revised to $10 million. Approximately $3.4 million is allocated to the Auburn Gas Gathering system. The remaining $6.6 million upstream budget remains discretionary and will be driven by natural gas pricing in the basin and management’s elected pace of proving Upper Marcellus resource on Epsilon’s leasehold.
Marcellus Operational Guidance
During the second quarter, Epsilon turned 4 (.12 net) new wells in line; however, the Operator continued to periodically shut-in various combinations of producing wells throughout the second quarter in response to poor natural gas prices. At quarter end, 15 (2.63 net) wells remained shut-in.
The Operator did not drill or propose any new wells during the quarter. The table below details Epsilon’s well development status at June 30, 2015:
|March 31, 2015||June 30, 2015|
|Shut-in for adjacent frac||11||0.71||15||2.63|
|Waiting on pipeline||–||–||–||–|
|Waiting on completion||6||0.13||2||0.01|
Epsilon has not received any well proposals from the Operator subsequent to quarter end.
Second Quarter Results
Epsilon generated revenues of $7.2 million for the three months ended June 30, 2015 compared to $15.0 million for the three months ended June 30, 2014. The Company’s Marcellus net revenue interest production was 2.8 Bcfe in the second quarter.
Realized natural gas prices averaged $1.25 per Mcf in the second quarter of 2015. Realized natural gas prices in Northeast Pennsylvania continue to be negatively impacted by a significant differential to depressed NYMEX Henry Hub prices. Operating expenses for Marcellus Upstream operations in the second quarter were $2.3 million.
The Auburn Gas Gathering system delivered 30 Bcfe of natural gas during the quarter as compared to 30 Bcfe during the first quarter of 2015. Primary gathering volumes increased 4.6% quarter over quarter to 16.1 Bcfe primarily as a result of improved well performance after the installation of a pressure regulating station at the interconnect of the Rome GGS and Auburn GGS. The regulating station reduces the pressure of the imported crossflow gas, thereby reducing the back pressure on the Auburn system wells. Imported cross-flow volumes increased 28.0% to 13.8 Bcfe.
Epsilon reported net after tax loss of $1.6 million attributable to common shareholders or ($0.03) per basic and diluted common shares outstanding for the three months ended June 30, 2015, compared to net income of $2.7 million, and $0.05 per basic and diluted common shares outstanding for the three months ended June 30, 2014.
For the three months ended June 30, 2015, Epsilon’s Adjusted Earnings Before Interest, Income Taxes, Depreciation, Amortization (“Adjusted EBITDA”) was $4.1 million as compared to $11.0 million for the three months ended June 30, 2014. The decrease in Adjusted EBITDA was primarily due to decreased production and lower natural gas prices.
Epsilon defines Adjusted EBITDA as earnings before (1) net interest expense, (2) depreciation, depletion and amortization expense, (3) recovery of prior impairments of oil and gas properties, (4) non-cash stock compensation expense, (5) unrealized gain on derivatives and (6) other income. Adjusted EBITDA is not a measure of net income or cash flows as determined by IFRS.
Management believes these non-IFRS financial measures facilitate evaluation of the Company’s business on a “normalized” or recurring basis and without giving effect to certain non-cash expenses and other items, thereby providing management, investors and analysts with comparative information for evaluating the Company in relation to other oil and gas companies providing corresponding non-IFRS financial measures. These non-IFRS financial measures should be considered in addition to, but not as a substitute for, measures for financial performance prepared in accordance with IFRS, and that the reconciliations to the closest corresponding IFRS measure should be reviewed carefully.
Epsilon Energy Ltd. is a North American onshore exploration and production company with a current focus on the Marcellus Shale of Pennsylvania.
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 in such forward-looking statements are based on reasonable assumption 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.
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 ENERGY LTD.|
|Interim Unaudited Condensed Consolidated Statements of Operations|
|(All amounts stated in US$)|
|Three months ended
|Six months ended
|Oil & gas revenue||$||3,450,462||$||11,748,130||$||6,673,389||$||26,046,196|
|Gas gathering & compression revenue||3,719,016||3,298,092||7,141,739||6,625,171|
|Operating costs and expenses:|
|Project operating costs||3,038,545||2,743,874||5,222,029||5,972,748|
|Depletion, depreciation, amortization and decommissioning accretion||4,038,799||6,581,698||7,406,703||13,161,095|
|Stock based compensation||14,052||(941,635||)||21,552||(918,747||)|
|General and administrative||484,609||571,579||1,002,565||990,935|
|Total operating costs and expenses||7,576,005||8,955,516||13,652,849||18,785,397|
|Operating income (loss)||(406,527||)||6,090,706||162,279||13,885,970|
|Other income and (expense):|
|Bad debt expense||(525,777||)||–||(525,777||)||–|
|Realized loss on commodity contracts||–||(1,622,450||)||–||(4,206,580||)|
|Net change in unrealized loss on commodity contracts||–||1,609,796||–||(597,110||)|
|Loss on sale of fixed assets||–||659,654||–||659,194|
|Net other expense||(1,109,968||)||(111,053||)||(2,108,806||)||(6,141,825||)|
|Income tax expense – current||–||–||444,743||–|
|Income tax (recovery) expense – deferred||44,312||3,286,433||(129,172||)||5,198,290|
|NET INCOME (LOSS)||$||(1,560,806||)||$||2,693,220||$||(2,262,098||)||$||2,545,855|
|Net income (loss) per share, basic||$||(0.03||)||$||0.05||$||(0.05||)||$||0.05|
|Net income (loss) per share, diluted||$||(0.03||)||$||0.05||$||(0.05||)||$||0.05|
|Weighted average number of shares outstanding, basic||47,245,228||50,058,959||47,236,278||50,130,582|
|Weighted average number of shares outstanding, diluted||47,245,228||50,128,767||47,236,278||50,193,574|
|EPSILON ENERGY LTD.|
|Interim Unaudited Condensed Consolidated Statements of Financial Position|
|(All amounts stated in US$)|
|June 30,||December 31,|
|Cash and cash equivalents||$||19,500,373||$||16,061,731|
|Other current assets||98,530||279,430|
|Total current assets||23,472,861||21,046,622|
|Oil and gas interests:|
|Intangible exploration and evaluation assets||10,200||8,800|
|Property and equipment (net)||141,209,753||145,482,656|
|Total oil and gas interests||141,219,953||145,491,456|
|EQUITY AND LIABILITIES|
|Accounts payable and accrued liabilities||$||6,715,183||$||5,868,563|
|Revolving line of credit||7,000,000||7,000,000|
|Total current liabilities||13,715,183||12,868,563|
|Deferred tax liability||28,366,625||28,495,797|
|Total non-current liabilities||60,216,839||61,985,879|
|Equity component of convertible debentures||5,024,361||5,024,690|
|Accumulated other comprehensive income||7,483,224||5,710,249|
|Total liabilities and shareholders’ equity||$||164,692,814||$||166,538,078|
|EPSILON ENERGY LTD.|
|Interim Unaudited Condensed Consolidated Statements of Cash Flows|
|(All amounts stated in US$)|
|Six months ended June 30,|
|Cash flows from operating activities:|
|Net income (loss)||$||(2,262,098||)||$||2,545,855|
|Depletion, depreciation, amortization and decommissioning accretion||7,406,703||13,161,095|
|Debenture accretion and fee amortization||594,909||627,219|
|Net change in unrealized loss on commodity contracts||–||597,110|
|Stock-based compensation expense (recovery)||21,552||(918,747||)|
|Deferred income tax expense||315,571||5,198,290|
|Income taxes paid||(400,000||)||(3,000||)|
|Bad debt expense||525,777||–|
|Loss on sale of assets||–||(659,194||)|
|Changes in non-cash balances related to operations||1,404,606||(3,224,283||)|
|Net cash provided by operating activities||7,607,020||16,903,711|
|Cash flows from investing activities:|
|Additions to oil and natural gas properties – E&E||(1,400||)||(5,598||)|
|Additions to oil and natural gas properties – PP&E||(3,167,740||)||(5,355,654||)|
|Change in working capital related to capital asset additions||(216,101||)||(401,841||)|
|Proceeds from assets sold||–||1,658,006|
|Net cash used in investing activities||(3,385,241||)||(4,105,087||)|
|Cash flows from financing activities:|
|Proceeds from exercise of options||–||548,963|
|Purchase and cancellation of options||(16,808||)||–|
|Buyback of common shares||(438,465||)||(1,722,808||)|
|Changes in restricted cash||100,000||–|
|Repayment of draw on revolving line of credit||–||(2,000,000||)|
|Net cash used in financing activities||(355,273||)||(3,173,845||)|
|Effect of currency rates on cash and cash equivalents||(427,864||)||21,326|
|Increase in cash and cash equivalents||3,438,642||9,646,105|
|Cash and cash equivalents, beginning of period||16,061,731||3,624,398|
|Cash and cash equivalents, end of period||$||19,500,373||$||13,270,503|
|Cash and cash equivalents consist of:|
|Money market funds||–||3,958,663|
|Cash and cash equivalents||$||19,500,373||$||13,270,503|
|EPSILON ENERGY LTD.|
|Adjusted EBITDA Reconciliation|
|(All amounts stated in US $000)|
|Three months ended June 30,||Six months ended June 30,|
|Net income (loss)||$||(1,561||)||$||2,693||$||(2,262||)||$||2,546|
|Net interest expense||1,016||989||2,046||2,224|
|Income tax provision||44||3,286||315||5,198|
|Depreciation, depletion, amortization, and accretion||4,039||6,582||7,407||13,163|
|Stock based compensation expense (recovery)||14||(942||)||22||(919||)|
|Net change in unrealized loss on commodity contracts||–||(1,610||)||–||597|
|Other income (loss)||524||(9||)||493||(5||)|
Epsilon Energy Ltd.
Chief Executive Officer