CALGARY, ALBERTA–(Marketwired – Nov. 23, 2016) – LEUCROTTA EXPLORATION INC. (TSX VENTURE:LXE) (“Leucrotta” or the “Company”) is pleased to announce its financial and operating results for the three and nine months ended September 30, 2016. All dollar figures are Canadian dollars unless otherwise noted.
- Maintained a working capital balance of $37.9 million, including cash of $41.4 million, at September 30, 2016
- Commenced fall capital program that includes drilling 3 wells and expanding pipeline/infrastructure system
- Sold certain gas plant equipment for cash proceeds of $4.0 million
- Renewed the credit facility at $5.0 million borrowing base
|Three Months Ended September 30||Nine Months Ended September 30|
|($000s, except per share amounts)||2016||2015||% Change||2016||2015||% Change|
|Oil and natural gas sales||2,309||972||138||6,563||8,040||(18||)|
|Funds from (used in) operations (1)||(124||)||(808||)||(85||)||(898||)||151||(695||)|
|Per share – basic and diluted||–||(0.01||)||(100||)||(0.01||)||–||(100||)|
|Net (loss) earnings||(4,994||)||(3,086||)||62||(10,525||)||26,617||(140||)|
|Per share – basic and diluted||(0.03||)||(0.02||)||50||(0.06||)||0.16||(138||)|
|Capital expenditures and acquisitions||5,775||7,876||(27||)||10,856||29,693||(63||)|
|Sale of gas plant equipment||4,000||–||100||4,000||–||100|
|Common shares outstanding (000s)|
|Weighted average – basic and diluted||165,227||165,227||–||165,227||165,227||–|
|End of period – basic||165,227||165,227||–|
|End of period – diluted||189,297||185,074||2|
|(1) See “Non-GAAP Measures” section.|
OPERATING RESULTS (1)
|Three Months Ended September 30||Nine Months Ended September 30|
|2016||2015||% Change||2016||2015||% Change|
|Oil and NGLs (bbls/d)||300||157||91||345||261||32|
|Natural gas (mcf/d)||4,138||2,244||84||4,588||6,964||(34||)|
|Oil equivalent (boe/d)||989||531||86||1,110||1,422||(22||)|
|Oil and NGLs ($/bbl)||48.28||45.00||7||43.08||45.06||(4||)|
|Natural gas ($/mcf)||2.57||1.55||66||2.00||2.54||(21||)|
|Oil equivalent ($/boe)||25.37||19.89||28||21.67||20.71||5|
|Oil and NGLs ($/bbl)||5.88||7.65||(23||)||4.16||5.68||(27||)|
|Natural gas ($/mcf)||0.10||0.14||(29||)||0.03||0.07||(57||)|
|Oil equivalent ($/boe)||2.20||2.85||(23||)||1.42||1.37||4|
|Oil and NGLs ($/bbl)||18.92||20.83||(9||)||16.76||10.11||66|
|Natural gas ($/mcf)||1.29||0.92||40||1.14||1.20||(5||)|
|Oil equivalent ($/boe)||11.12||10.06||11||9.94||7.72||29|
|Oil and NGLs ($/bbl)||6.02||9.24||(35||)||5.06||4.03||26|
|Natural gas ($/mcf)||0.44||0.43||2||0.43||0.30||43|
|Oil equivalent ($/boe)||3.65||4.56||(20||)||3.37||2.22||52|
|Operating netback (2)|
|Oil and NGLs ($/bbl)||17.46||7.28||140||17.10||25.24||(32||)|
|Natural gas ($/mcf)||0.74||0.06||1,133||0.40||0.97||(59||)|
|Oil equivalent ($/boe)||8.40||2.42||247||6.94||9.40||(26||)|
|Depletion and depreciation ($/boe)||(15.46||)||(14.29||)||8||(13.07||)||(8.68||)||51|
|Asset impairment ($/boe)||–||(19.29||)||(100||)||–||(2.43||)||(100||)|
|General and administrative expenses ($/boe)||(10.90||)||(24.36||)||(55||)||(11.11||)||(9.95||)||12|
|Share based compensation ($/boe)||(9.53||)||(25.71||)||(63||)||(9.93||)||(11.07||)||(10||)|
|Finance expenses ($/boe)||(0.52||)||(0.75||)||(31||)||(0.41||)||(0.50||)||(18||)|
|Finance income ($/boe)||1.31||5.49||(76||)||1.30||1.16||12|
|Gain (loss) on sale of assets ($/boe)||(28.15||)||–||100||(8.46||)||117.82||(107||)|
|Deferred tax expense ($/boe)||–||13.40||(100||)||–||(27.19||)||(100||)|
|Net (loss) earnings ($/boe)||(54.85||)||(63.09||)||(13||)||(34.74||)||68.56||(151||)|
|(1) See “Frequently Recurring Items” section.|
|(2) See “Non-GAAP Measures” section.|
Selected financial and operational information outlined in this news release should be read in conjunction with Leucrotta’s unaudited condensed interim financial statements and related Management’s Discussion and Analysis (“MD&A”) for the three and nine months ended September 30, 2016, which are available for review at www.sedar.com and on our website at www.leucrotta.ca.
In September 2016, Leucrotta commenced its fall/winter capital program that encompasses drilling 3 wells, installing main gathering lines and modifying its sweet gas plant at Doe for an estimated cost of $26 million. The capital program has experienced delays due to extremely wet conditions and a lack of cold weather. As of mid-November, Leucrotta has drilled two of the three wells and completed a portion of the facility upgrades. With recent cold weather, Leucrotta is proceeding with the construction of the pipelines and will finish the remaining drilling and completions as outlined in our Q2 2016 release. Leucrotta expects to have the 2 new horizontal wells completed and tested by early January. The major gathering lines to tie in the 4 previously drilled wells are expected to be completed in Q2 2017.
The description of the capital program as previously released August 17, 2016 is as follows:
- Focus of the capital program will be building out the pipeline system and infrastructure;
- Wells previously drilled and not on production include 2 Liquids-rich Lower Montney Turbidite gas wells, 1 Lower Montney Turbidite oil well, and 1 Liquids-rich Upper Montney gas well;
- The combined total tested production rate from these wells was approximately 3,100 boepd(1);
- Approximately $17 million will be spent on the tie-ins and related equipment (including plant modifications) to place the 4 wells noted above on-stream mainly through Leucrotta’s 100% owned Doe facility. The pipelines installed will be sized as main gathering lines to each area to accommodate larger scale developments in the future.
On completion of the capital program, Leucrotta will have the 4 previously drilled wells on stream and an extended infrastructure footprint that will position the Company to fully complete the delineation phase of the Montney turbidite on its lands by the end of 2017 pending favourable commodity prices. Leucrotta will then be in a position to start the development phase of this large resource in 2018.
We look forward to reporting the results of our current capital program in early 2017 and the 2017 capital budget by mid-late Q1 2017.
(1) See “Test Results and Production Rates” section of MD&A for more details.
FREQUENTLY RECURRING TERMS
The Company uses the following frequently recurring industry terms in this news release: “bbls” refers to barrels, “mcf” refers to thousand cubic feet, and “boe” refers to barrel of oil equivalent. Disclosure provided herein in respect of a boe may be misleading, particularly if used in isolation. A boe conversion rate of six thousand cubic feet of natural gas to one barrel of oil equivalent has been used for the calculation of boe amounts in this news release. This boe conversion rate is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.
This news release refers to certain financial measures that are not determined in accordance with IFRS (or “GAAP”). This news release contains the terms “funds from (used in) operations”, “funds from (used in) operations per share”, and “operating netback” which do not have any standardized meaning prescribed by GAAP and therefore may not be comparable to similar measures used by other companies. The Company uses these measures to help evaluate its performance.
Management uses funds from (used in) operations to analyze performance and considers it a key measure as it demonstrates the Company’s ability to generate the cash necessary to fund future capital investments and to repay debt. Funds from (used in) operations is a non-GAAP measure and has been defined by the Company as cash flow from (used in) operating activities excluding the change in non-cash working capital related to operating activities and expenditures on decommissioning obligations. The Company also presents funds from (used in) operations per share whereby amounts per share are calculated using weighted average shares outstanding, consistent with the calculation of earnings (loss) per share. Funds from (used in) operations is reconciled from cash flow from (used in) operating activities under the heading “Funds from (used in) Operations”.
Management considers operating netback an important measure as it demonstrates its profitability relative to current commodity prices. Operating netback, which is calculated as average unit sales price less royalties, production expenses, and transportation expenses, represents the cash margin for every barrel of oil equivalent sold. Operating netback per boe is reconciled to net loss per boe under the heading “Operating Netback”.
TEST RESULTS AND PRODUCTION RATES
Test rates for the A13-19 Lower Montney Turbidite horizontal gas well were disclosed in a press release on April 27, 2016. The well was production tested for 68 hours and was producing 1,290 boe/d (87% gas, 13% Condensate), excluding load fluid and energizing fluid at the end of the test. At the end of the test, flowing wellhead pressure was stable and production rates were increasing.
Test rates for the 8-18 Lower Montney Turbidite horizontal gas well were disclosed in a press release dated April 7, 2015. The well was production tested for 39 days and was produced at an average rate of 375 boe/d (82% gas, 18% Condensate), excluding load fluid and energizing fluid. At the end of the test, flowing wellhead pressure and production rates were stable.
Test rates for the 8-22 Lower Montney Turbidite horizontal oil well were disclosed in a press release on February 29, 2016. The well was production tested for 8 days and was producing at an average rate of 713 boe/d (50% gas, 50% Oil and Condensate), excluding load fluid and energizing fluid at the end of the test. At the end of the test, flowing wellhead pressure was stable and production rates were increasing.
The A4-19 Upper Montney horizontal gas well produced for a period of four months and was last producing at a rate of 700 boe/d (90% gas, 10% Condensate).
A pressure transient analysis or well-test interpretation has not been carried out on these wells and thus certain of the test results provided herein should be considered to be preliminary until such analysis or interpretation has been completed. Test results and initial production rates disclosed herein may not necessarily be indicative of long term performance or of ultimate recovery.
This news release contains forward-looking statements and forward-looking information within the meaning of applicable securities laws. The use of any of the words “expect”, “anticipate”, “continue”, “estimate”, “may”, “will”, “should”, “believe”, “intends”, “forecast”, “plans”, “guidance” and similar expressions are intended to identify forward-looking statements or information.
More particularly and without limitation, this news release contains forward looking statements and information relating to the Company’s risk management program, oil, NGLs, and natural gas production, capital programs, oil, NGLs, and natural gas commodity prices, production expenses, and working capital. The forward-looking statements and information are based on certain key expectations and assumptions made by the Company, including expectations and assumptions relating to prevailing commodity prices and exchange rates, applicable royalty rates and tax laws, future well production rates, the performance of existing wells, the success of drilling new wells, the availability of capital to undertake planned activities, and the availability and cost of labour and services.
Although the Company believes that the expectations reflected in such forward-looking statements and information are reasonable, it can give no assurance that such expectations will prove to be correct. Since forward-looking statements and information address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results may differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production, delays or changes in plans with respect to exploration or development projects or capital expenditures, the uncertainty of estimates and projections relating to production rates, costs, and expenses, commodity price and exchange rate fluctuations, marketing and transportation, environmental risks, competition, the ability to access sufficient capital from internal and external sources and changes in tax, royalty, and environmental legislation. The forward-looking statements and information contained in this document are made as of the date hereof for the purpose of providing the readers with the Company’s expectations for the coming year. The forward-looking statements and information may not be appropriate for other purposes. The Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.
Leucrotta is an oil and natural gas company, actively engaged in the acquisition, development, exploration, and production of oil and natural gas reserves in northeastern British Columbia, Canada.
Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.
Mr. Robert J. Zakresky
President and Chief Executive Officer
Mr. Nolan Chicoine
Vice President, Finance and Chief Financial Officer
Leucrotta Exploration Inc.
Suite 700, 639 – 5th Avenue SW
Calgary, Alberta T2P 0M9
Phone: (403) 705-4525
Fax: (403) 705-4526