Blue Star Helium Limited (ASX:BNL, OTCQB:BSNLF) (Blue Star or the Company) provides an update on progress on its maiden Voyager helium development in Las Animas County, Colorado.
Highlights
Voyager helium development wells approved for drilling
The Colorado Oil and Gas Conservation Commission (COGCC) has approved the Forms 2 relating to each of the BBB 33#1 and BBB 34#1 helium development wells (refer Figure 1). These wells relate to the “BBB 2860” Oil and Gas Development Plan (OGDP) located within the Company’s high-grade Voyager helium development. This is the final COGCC approval required to be able to drill these wells.
These two wells offset the BBB#1 helium discovery and are intended to produce into the initial Voyager facility (see BNL announcement dated 19 December 2022). Drilling of the first of these wells is expected to commence in late Q2 or Q3 and is planned to include subsequent flow and pressure testing evaluation.
Additional Voyager helium development wells submission
Following the acquisition of strategic mineral leases and surface access agreements (see BNL release of 11 April 2023), the next planned OGDP submission at Voyager has been expanded to five wells and is planned to be submitted in the first week of May after expiry of mandatory pre- submission notices to the County.
Previously this OGDP included the three eastern wells on the map below (on existing leases shown in blue). Submission of the OGDP was paused to add the two highly regarded well locations associated with the newly acquired strategic minerals leases (shown in yellow). This approach follows COGCC guidance.
Coupled with BBB 33#1 and 34#1, approval of these further locations is expected to deliver a robust inventory of permitted wells from which to select the initial 3-4 production well locations at Voyager.
COGCC advised at the operator meeting on 14 March 2023 that it is implementing a revised permitting process which is designed to shorten the time between submission and hearing to 4.5 months. COGCC says that the current process takes on average 7 months.
Figure 1: Voyager helium development planned well locations
Helium processing facility commercial discussions
Blue Star is progressing negotiations with a mid-stream company for the lease of a helium processing facility at Voyager (see BNL announcement of 19 December 2022). These discussions are now highly advanced and expected to conclude in execution of a facilities agreement in the coming weeks for supply and operation of the helium processing plant. Accordingly, given the COGCC’s revised permitting guidance, Blue Star is continuing to target first helium production and sales from Voyager during H2 CY2023.
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Trillion Energy International Inc. (" Trillion " or the "Company ") (CSE: TCF) (OTCQB: TRLEF) (Frankfurt: Z62), has reissued its consolidated financial statements for the year ended December 31, 2023 to correct an identified error. As a result, the Company's Net Loss is reduced to $43,842 for the year from the previously reported net loss of $1,102,194.
The error is the result of a foreign exchange loss on intercompany accounts that was recorded in net loss and which should have been recorded in other comprehensive loss. IAS 21, The effects of changes in foreign exchange rates , requires that foreign exchange gains and losses on items that form part of an entity's net investment in a foreign operation, should be recognized in other comprehensive income or loss in the Company's consolidated financial statements.
The following table summarizes the line items impacted in the consolidated statements of financial position:
| As at December 31, 2023 | As previously reported $ | Restatement Adjustment $ | Restated Amount $ |
| Accumulated other comprehensive loss | (12,964,837) | (1,058,352) | (14,023,189) |
| Accumulated deficit | (45,939,198) | 1,058,352 | (44,880,846) |
| Total stockholders' equity | 22,212,572 | - | 22,212,572 |
The following table summarizes the line items impacted in the consolidated statements of income (loss) and comprehensive income (loss):
| For the year ended December 31, 2023 | As previously reported $ | Restatement Adjustment $ | Restated Amount $ |
| Foreign exchange gain (loss) | (10,990,604) | 1,058,352 | (9,932,252) |
| Total other income (expense) | 4,239,593 | 1,058,352 | 5,297,945 |
| Net income (loss) before taxes | 758,132 | 1,058,352 | 1,816,484 |
| Net loss | (1,102,194) | 1,058,352 | (43,842) |
| Other comprehensive loss Foreign currency translation | (8,954,840) | (1,058,352) | (10,013,192) |
| Comprehensive loss | (10,057,034) | - | (10,057,034) |
| Net income (loss) per share – Basic and diluted | (0.01) | 0.01 | (0.00) |
The above changes were adjusted through to the consolidated statements of stockholder' equity, cash flows, and notes to the consolidated financial statements for the year ended December 31, 2023. However, there were no changes to the reported totals of cash flows from (used in) operating, investing and financing activities.
"The Company considers these changes to have a negligible impact on the Company's financial position as there are no cash items impacted" said David Thompson, CFO.
The Company has recently filed its quarterly consolidated financial statements for 30 th September 2024 which are not impacted by the adjustments to the prior year.
About the Company
Trillion Energy International Inc is focused on oil and natural gas production for Europe and Türkiye with natural gas assets in Türkiye. The Company is 49% owner of the SASB natural gas field, a Black Sea natural gas development and a 19.6% (except three wells with 9.8%) interest in the Cendere oil field. More information may be found on www.sedar.com , and our website.
Contact
David Thompson, CFO
1-778-819-1585
E-mail: info@trillionenergy.com
Website: www.trillionenergy.com
Cautionary Statement Regarding Forward-Looking Statements
This news release may contain certain forward-looking information and statements, including without limitation, statements pertaining to the Company's ability to obtain regulatory approval of the executive officer and director appointments. All statements included herein, other than statements of historical fact, are forward-looking information and such information involves various risks and uncertainties. Trillion does not undertake to update any forward-looking information except in accordance with applicable securities laws.
These statements are no guarantee of future performance and are subject to certain risks, uncertainties, delay, change of strategy, and assumptions that are difficult to predict and which may change over time. Accordingly, actual results and strategies could differ materially and adversely from those expressed in any forward-looking statements as a result of various factors. These factors include unforeseen securities regulatory challenges, COVID, oil and gas price fluctuations, operational and geological risks, changes in capital raising strategies, the ability of the Company to raise necessary funds for development; the outcome of commercial negotiations; changes in technical or operating conditions; the cost of extracting gas and oil may increase and be too costly so that it is uneconomic and not profitable to do so and other factors discussed from time to time in the Company's filings on www.sedar.com, including the most recently filed Annual Report on Form 20-F and subsequent filings. For a full summary of our oil and gas reserves information for Turkey, please refer to our Forms F-1,2,3 51-101 filed on www.sedar.com, and or request a copy of our reserves report effective December 31, 2022 and updated January 31 2023.
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Coelacanth Energy Inc. (TSXV: CEI) ("Coelacanth" or the "Company") announces that it has completed and tested 4 additional wells at its Two Rivers East Project including 3 Lower Montney Wells and 1 Upper Montney well on the 5-19 pad.
LOWER MONTNEY
The 3 new Lower Montney wells (F5-19, G5-19, H5-19) were drilled with an average horizontal length of 3,285 metres and completed with approximately 2.5 tons of sand per horizontal metre. The wells were placed on test for clean-up for an average of 7 days until a stabilized rate was achieved. The test rates noted below are based on the final 24 hours of each test.
The average rate achieved for the 3 new Lower Montney wells was 1,624 boepd per well comprised of 989 bbls per day of 41 API light sweet oil and 3.8 mmcf/d of liquids-rich gas. The rates per well are outlined in the table below:
| Well | Oil - bbls/d | Gas - mmcf/d | Total - boe/d | % Light Oil |
| F5-19 | 1,061 | 3.2 | 1,595 | 67 |
| G5-19 | 900 | 4.0 | 1,573 | 57 |
| H5-19 | 1,007 | 4.2 | 1,703 | 59 |
| Average | 989 | 3.8 | 1,624 | 61 |
The overall rates and more specifically the oil rates were materially higher than the previous 3 wells on the pad (C5-19, D5-19 and E5-19) that achieved an average test rate of 1,338 boepd including 729 bbls/d of light oil and 3.7 mmcf/d of gas (see press release dated January 18, 2024 for more information including per well test results and initial production rates). Although the 3 new Lower Montney wells were drilled with slightly longer lateral lengths and the completion design was slightly modified in an attempt to increase the overall oil production, the tests have exceeded expectations.
UPPER MONTNEY
The Upper Montney well (B5-19) was drilled with a horizontal length of 2,647 metres and completed with approximately 2.5 tons of sand per horizontal metre. The well flowed on cleanup for 6 days and achieved a rate of 1,136 boepd comprised of 271 bbls/d of 40 API light oil and 5.2 mmcf/d of liquids-rich gas. In comparison to the Lower Montney Wells noted above, the B5-19 was 20% shorter in horizontal length and had 42% less frac stages leaving room for future optimization.
Management is very pleased with the B5-19 test result particularly the potential impact on Coelacanth's development inventory over its 150-section contiguous Montney land block. The Upper Montney is extensively mapped over Coelacanth's lands, but the impact of this test is amplified given it is a 10-mile step-out from Coelacanth's Two Rivers West project and 5 miles from the nearest competitor well.
INFRASTRUCTURE & TAKEAWAY
As previously disclosed, Coelacanth has secured long-term takeaway and processing for up to 60 mmcf/d of gas and is in process of constructing the required facilities and pipelines to handle the 5-19 and subsequent pads. Initial testing and start-up of the facility is anticipated for late April 2025.
Overall, Coelacanth believes this was a very significant second step in its development that has materially expanded the development fairway of the Upper Montney as well as increased the productivity of the Lower Montney that was already established as productive.
FOR FURTHER INFORMATION PLEASE CONTACT:
Coelacanth Energy Inc.
2110, 530 - 8th Ave SW
Calgary, Alberta T2P 3S8
Phone: 403-705-4525
www.coelacanth.ca
Mr. Robert J. Zakresky
President and Chief Executive Officer
Mr. Nolan Chicoine
Vice President, Finance and Chief Financial Officer
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.
Oil and Gas Terms
The Company uses the following frequently recurring oil and gas industry terms in the news release:
| Liquids | |
| Bbls | Barrels |
| Bbls/d | Barrels per day |
| NGLs | Natural gas liquids (includes condensate, pentane, butane, propane, and ethane) |
| Natural Gas | |
| Mcf | Thousands of cubic feet |
| Mcf/d | Thousands of cubic feet per day |
| MMcf/d | Millions of cubic feet per day |
| Oil Equivalent | |
| Boe | Barrels of oil equivalent |
| Boe/d | Barrels of oil equivalent per day |
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 the 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.
Product Types
The Company uses the following references to sales volumes in the news release:
Natural gas refers to shale gas
Oil refers to tight oil
NGLs refers to butane, propane and pentanes combined
Liquids refers to tight oil and NGLs combined
Oil equivalent refers to the total oil equivalent of shale gas, tight oil, and NGLs combined, using the conversion rate of six thousand cubic feet of shale gas to one barrel of oil equivalent as described above.
Forward-Looking Information
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 document contains forward-looking statements and information relating to the Company's oil, NGLs and natural gas production and capital programs. 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 labor 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.
Test Results and Initial Production Rates
The B5-19 Upper Montney well was production tested for 6.3 days and produced at an average rate of 92 bbl/d oil and 2,100 mcf/d gas (net of load fluid and energizing fluid) over that period which includes the initial cleanup where only load water was being recovered. At the end of the test, flowing wellhead pressure and production rates were stable.
The F5-19 Lower Montney well was production tested for 4.9 days and produced at an average rate of 728 bbl/d oil and 1,607 mcf/d gas (net of load fluid and energizing fluid) over that period which includes the initial cleanup where only load water was being recovered. At the end of the test, flowing wellhead pressure and production rates were stable.
The G5-19 Lower Montney well was production tested for 7.1 days and produced at an average rate of 415 bbl/d oil and 1,489 mcf/d gas (net of load fluid and energizing fluid) over that period which includes the initial cleanup where only load water was being recovered. At the end of the test, flowing wellhead pressure and production rates were stable.
The H5-19 Basal Montney well was production tested for 8.1 days and produced at an average rate of 411 bbl/d oil and 1,166 mcf/d gas (net of load fluid and energizing fluid) over that period which includes the initial cleanup where only load water was being recovered. At the end of the test, flowing wellhead pressure was stable and production was starting to decline.
A pressure transient analysis or well-test interpretation has not been carried out on these four 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, particularly those short in duration, may not necessarily be indicative of long-term performance or of ultimate recovery.
To view the source version of this press release, please visit https://www.newsfilecorp.com/release/232259
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