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CALGARY, Alberta, Dec. 05, 2024 (GLOBE NEWSWIRE) -- Athabasca Oil Corporation (TSX: ATH) (“Athabasca” or the “Company”) is pleased to announce its 2025 budget with capital projects that will balance cash flow growth while continuing to deliver a durable return of capital framework that will direct 100% of Free Cash Flow to share buybacks in 2025. Corporate Consolidated Strategy and Outlook Value Creation Strategy. Athabasca provides a differentiated liquids-weighted growth platform through its low-decline, long-life Thermal Oil assets. Athabasca’s subsidiary company, Duvernay Energy Corporation (“DEC”), is designed to enhance value for Athabasca’s shareholders by providing a clear path for self-funded production and cash flow growth in the Kaybob Duvernay resource play. Athabasca (Thermal Oil) and DEC have independent strategies and capital allocation frameworks. The primary strategic objective is to generate top-tier cash flow per share growth over the long term. 2025 Consolidated Budget. Athabasca is planning capital expenditures of ~$335 million with average production of 37,500 – 39,500 boe/d (98% Liquids) and an exit rate of ~41,000 boe/d. Growth in production comes from the expansion plans at Leismer and development of the Duvernay assets. Cash Flow Per Share Growth . The Company forecasts consolidated Adjusted Funds Flow between $525 – $550 million 1 . Every +US$1/bbl move in West Texas Intermediate (“WTI”) and Western Canadian Select (“WCS”) heavy oil impacts annual Adjusted Funds Flow by ~$10 million and ~$17 million, respectively. Athabasca forecasts generating ~$1.8 billion of Free Cash Flow 1 from its Thermal Oil assets over five years (2025-29), representing ~65% of its current equity market capitalization. Investing in attractive capital projects and prioritizing share buybacks results in ~20% compounded annual cash flow per share 2 growth through this forecast period. Financial Resiliency. Athabasca maintains a strong and differentiated balance sheet with a $135 million consolidated Net Cash position, including ~$335 million of cash. DEC has no debt and operates within its annual Adjusted Funds Flow and its balance sheet. Athabasca (Thermal Oil) also has $2.4 billion in tax pools, including $1.9 billion of immediately deductible non-capital loses and exploration pools, sheltering cash taxes until beyond 2030. Athabasca (Thermal Oil) – 2025 Budget Highlights Capital Program . The Thermal Oil budget is ~$250 million with activity focused primarily on advancing progressive growth to 40,000 bbl/d at Leismer by the end of 2027. The program at Leismer will include the tie-in of six redrills and four new sustaining well pairs on Pad 10 early in 2025, additional development at Pad 10 and 11, and continued facility expansion work. At Hangingstone two new extended reach sustaining well pairs (~1,400 meter average laterals) will be on stream in Q1 2025 and are expected to maintain annual production. The Budget includes routine maintenance at both assets. Production Growth . Annual Thermal Oil production guidance is 33,500 – 35,500 bbl/d. Leismer is expected to achieve 40,000 bbl/d by the end of 2027 at an attractive capital efficiency of ~$25,000/bbl/d. Hangingstone production will be maintained by utilizing existing plant capacity, resulting in capital efficiencies of ~$15,000/bbl/d. The Company has ~1.2 billion barrels of Proved plus Probable reserves and ~1 billion of Contingent Resource. These Thermal Oil assets underpin decades of reserve life with estimated sustaining capital investment of ~C$8/bbl (five-year annual average) to hold production flat. Robust Free Cash Flow. During the five-year time frame (2025-29), Athabasca (Thermal Oil) forecasts generating $1.8 billion in Free Cash Flow 1 , representing ~65% of its current equity market capitalization. Competitive and Resilient Break-evens. Thermal Oil is competitively positioned with sustaining capital to hold production flat funded within cash flow below US$50/bbl WTI 1 and growth initiatives fully funded within cash flow below US$60/bbl WTI 1 . The Company’s operating break-even is estimated at ~US$40/bbl WTI 1 . Exposure to Strong Heavy Oil Pricing. With the start-up of the Trans Mountain pipeline expansion in May, spare pipeline capacity is driving tighter and less volatile WCS heavy differentials. Regional liquids pricing benchmarks have also been supported by a depreciating Canadian currency relative to the United States. Every +US$1/bbl move in West Texas Intermediate (“WTI”) and WCS heavy oil impacts annual Adjusted Funds Flow by ~$10 million and ~$17 million, respectively. Pre-payout Thermal Oil Differentiation. Strong margins and Free Cash Flow are supported by a Thermal Oil pre-payout Crown royalty structure, with royalty rates between 5 – 9% anticipated to last to the end of 2027 at Leismer and beyond 2030 at Hangingstone. Duvernay Energy Corporation – 2025 Budget Highlights Capital Program. The DEC budget is ~$85 million with activity including the completion of a 100% working interest (“WI”) three-well pad that was drilled in 2024 and the drilling and completion of a 30% WI multi-well pad. Activity will also include spudding two additional multi-well pads in H2 2025 (one operated 100% WI pad and one 30% WI pad) with completions to follow in 2026. DEC is also constructing strategic water and egress expansions on its operated assets. High Netback Production. Annual production guidance is ~4,000 boe/d (77% Liquids) with growth to ~5,500 boe/d by the end of 2025. The Kaybob Duvernay’s high liquid weighting supports strong margins with current type wells forecasted to payout in ~13 months 1 and further cost improvements are expected as the Company executes larger multi-well pad design. Growth Plans. Development will be self-funded within DEC through utilization of 100% of its annual Adjusted Funds Flow and its balance sheet. The Company has self-funded growth potential to in excess of ~20,000 boe/d (75% Liquids) by the late 2020s 1 . Return of Capital 100% of Free Cash Flow Directed to Share Buybacks. In 2025, the Company plans to maintain its commitment to return 100% of Thermal Oil Free Cash Flow to shareholders through share buybacks. In 2024, the Company has completed ~$280 million in share buybacks to the end of November. Share buybacks were initiated in April 2023 and have totaled ~$440 million to date. Focus on Per Share Metrics: A steadfast commitment to cash flow growth and return of capital has driven a 108 million share reduction (~17%) in the Company’s fully diluted share count since March 31, 2023. The Company has realized ~100% cash flow per share growth since 2022 and the corporate strategy is to continue to generate top tier cash flow per share growth over the long term. Footnote: Refer to the “Reader Advisory” section within this news release for additional information on Non‐GAAP Financial Measures (e .g. Adjusted Funds Flow, Free Cash Flow, Sustaining Capital, Net Cash ) and production disclosure. 1 Pricing Assumptions: 2025: US$70 WTI, US$12.50 WCS heavy differential, C$2 AECO, and 0.725 C$/US$ FX. 2026+: US$70 WTI, US$12.50 WCS heavy differential, C$3 AECO, and 0.725 C$/US$ FX. 2 The Company’s illustrative multi-year outlook assumes a 10% annual share buyback program at an implied share price of 4.5x Enterprise Value/Debt Adjusted Cash Flow in 2026 and beyond. About Athabasca Oil Corporation Athabasca Oil Corporation is a Canadian energy company with a focused strategy on the development of thermal and light oil assets. Situated in Alberta’s Western Canadian Sedimentary Basin, the Company has amassed a significant land base of extensive, high quality resources. Athabasca’s light oil assets are held in a private subsidiary (Duvernay Energy Corporation) in which Athabasca owns a 70% equity interest. Athabasca’s common shares trade on the TSX under the symbol “ATH”. For more information, visit www.atha.com . Reader Advisory: This News Release contains forward-looking information that involves various risks, uncertainties and other factors. All information other than statements of historical fact is forward-looking information. The use of any of the words “anticipate”, “plan”, “project”, “continue”, “maintain”, “may”, “estimate”, “expect”, “will”, “target”, “forecast”, “could”, “intend”, “potential”, “guidance”, “outlook” and similar expressions suggesting future outcome are intended to identify forward-looking information. The forward-looking information is not historical fact, but rather is based on the Company’s current plans, objectives, goals, strategies, estimates, assumptions and projections about the Company’s industry, business and future operating and financial results. This information involves 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 information. No assurance can be given that these expectations will prove to be correct and such forward-looking information included in this News Release should not be unduly relied upon. This information speaks only as of the date of this News Release. In particular, this News Release contains forward-looking information pertaining to, but not limited to, the following: our strategic plans; the allocation of future capital; timing and quantum for shareholder returns including share buybacks; the terms of our NCIB program; our drilling plans and capital efficiencies; production growth to expected production rates and estimated sustaining capital amounts; timing of Leismer’s and Hangingstone’s pre-payout royalty status; applicability of tax pools and the timing of tax payments; Adjusted Funds Flow and Free Cash Flow over various periods; type well economic metrics; number of drilling locations; forecasted daily production and the composition of production; our outlook in respect of the Company’s business environment, including in respect of the Trans Mountain pipeline expansion and heavy oil pricing; and other matters. In addition, information and statements in this News Release relating to "Reserves" and “Resources” are deemed to be forward-looking information, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated, and that the reserves and resources described can be profitably produced in the future. With respect to forward-looking information contained in this News Release, assumptions have been made regarding, among other things: commodity prices; the regulatory framework governing royalties, taxes and environmental matters in the jurisdictions in which the Company conducts and will conduct business and the effects that such regulatory framework will have on the Company, including on the Company’s financial condition and results of operations; the Company’s financial and operational flexibility; the Company’s financial sustainability; Athabasca's cash flow break-even commodity price; the Company’s ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the applicability of technologies for the recovery and production of the Company’s reserves and resources; future capital expenditures to be made by the Company; future sources of funding for the Company’s capital programs; the Company’s future debt levels; future production levels; the Company’s ability to obtain financing and/or enter into joint venture arrangements, on acceptable terms; operating costs; compliance of counterparties with the terms of contractual arrangements; impact of increasing competition globally; collection risk of outstanding accounts receivable from third parties; geological and engineering estimates in respect of the Company’s reserves and resources; recoverability of reserves and resources; the geography of the areas in which the Company is conducting exploration and development activities and the quality of its assets. Certain other assumptions related to the Company’s Reserves and Resources are contained in the report of McDaniel & Associates Consultants Ltd. (“McDaniel”) evaluating Athabasca’s Proved Reserves, Probable Reserves and Contingent Resources as at December 31, 2023 (which is respectively referred to herein as the "McDaniel Report”). Actual results could differ materially from those anticipated in this forward-looking information as a result of the risk factors set forth in the Company’s Annual Information Form (“AIF”) dated February 29, 2024 available on SEDAR at www.sedarplus.ca, including, but not limited to: weakness in the oil and gas industry; exploration, development and production risks; prices, markets and marketing; market conditions; climate change and carbon pricing risk; statutes and regulations regarding the environment including deceptive marketing provisions; regulatory environment and changes in applicable law; gathering and processing facilities, pipeline systems and rail; reputation and public perception of the oil and gas sector; environment, social and governance goals; political uncertainty; state of capital markets; ability to finance capital requirements; access to capital and insurance; abandonment and reclamation costs; changing demand for oil and natural gas products; anticipated benefits of acquisitions and dispositions; royalty regimes; foreign exchange rates and interest rates; reserves; hedging; operational dependence; operating costs; project risks; supply chain disruption; financial assurances; diluent supply; third party credit risk; indigenous claims; reliance on key personnel and operators; income tax; cybersecurity; advanced technologies; hydraulic fracturing; liability management; seasonality and weather conditions; unexpected events; internal controls; limitations and insurance; litigation; natural gas overlying bitumen resources; competition; chain of title and expiration of licenses and leases; breaches of confidentiality; new industry related activities or new geographical areas; water use restrictions and/or limited access to water; relationship with Duvernay Energy Corporation; management estimates and assumptions; third-party claims; conflicts of interest; inflation and cost management; credit ratings; growth management; impact of pandemics; ability of investors resident in the United States to enforce civil remedies in Canada; and risks related to our debt and securities. All subsequent forward-looking information, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements. Also included in this News Release are estimates of Athabasca's 2024 outlook which are based on the various assumptions as to production levels, commodity prices, currency exchange rates and other assumptions disclosed in this News Release. To the extent any such estimate constitutes a financial outlook, it was approved by management and the Board of Directors of Athabasca and is included to provide readers with an understanding of the Company’s outlook. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the financial outlook or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The outlook and forward-looking information contained in this New Release was made as of the date of this News release and the Company disclaims any intention or obligations to update or revise such outlook and/or forward-looking information, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Oil and Gas Information “BOEs" may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 Mcf: 1 bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value. Initial Production Rates Test Results and Initial Production Rates: The well test results and initial production rates provided herein should be considered to be preliminary, except as otherwise indicated. Test results and initial production rates disclosed herein may not necessarily be indicative of long-term performance or of ultimate recovery. Reserves Information The McDaniel Report was prepared using the assumptions and methodology guidelines outlined in the COGE Handbook and in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities, effective December 31, 2023. There are numerous uncertainties inherent in estimating quantities of bitumen, light crude oil and medium crude oil, tight oil, conventional natural gas, shale gas and natural gas liquids reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth above are estimates only. In general, estimates of economically recoverable reserves and the future net cash flows therefrom are based upon a number of variable factors and assumptions, such as historical production from the properties, production rates, ultimate reserve recovery, timing and amount of capital expenditures, 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. For those reasons, estimates of the economically recoverable reserves attributable to any particular group of properties, classification of such reserves based on risk of recovery and estimates of future net revenues associated with reserves prepared by different engineers, or by the same engineers at different times, may vary. The Company's actual production, revenues, taxes and development and operating expenditures with respect to its reserves will vary from estimates thereof and such variations could be material. Reserves figures described herein have been rounded to the nearest MMbbl or MMboe. For additional information regarding the consolidated reserves and information concerning the resources of the Company as evaluated by McDaniel in the McDaniel Report, please refer to the Company’s AIF. Reserve Values (i.e. Net Asset Value) is calculated using the estimated net present value of all future net revenue from our reserves, before income taxes discounted at 10%, as estimated by McDaniel effective December 31, 2023 and based on average pricing of McDaniel, Sproule and GLJ as of January 1, 2024. The 500 gross Duvernay drilling locations referenced include: 37 proved undeveloped locations and 76 probable undeveloped locations for a total of 113 booked locations with the balance being unbooked locations. Proved undeveloped locations and probable undeveloped locations are booked and derived from the Company's most recent independent reserves evaluation as prepared by McDaniel as of December 31, 2023 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal management estimates. Unbooked locations do not have attributed reserves or resources (including contingent or prospective). Unbooked locations have been identified by management as an estimation of Athabasca’s multi-year drilling activities expected to occur over the next two decades based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Company will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which the Company will actually drill wells, including the number and timing thereof is ultimately dependent upon the availability of funding, commodity prices, provincial fiscal and royalty policies, costs, actual drilling results, additional reservoir information that is obtained and other factors. Non-GAAP and Other Financial Measures, and Production Disclosure The "Corporate Consolidated Adjusted Funds Flow", "Athabasca (Thermal Oil) Adjusted Funds Flow", "Duvernay Energy Adjusted Funds Flow", “Corporate Consolidated Free Cash Flow”, "Athabasca (Thermal Oil) Free Cash Flow" and "Duvernay Energy Free Cash Flow" financial measures contained in this News Release do not have standardized meanings which are prescribed by IFRS and they are considered to be non-GAAP financial measures or ratios. These measures may not be comparable to similar measures presented by other issuers and should not be considered in isolation with measures that are prepared in accordance with IFRS. Sustaining Capital and Net Cash are supplementary financial measures. The Leismer and Hangingstone operating results are supplementary financial measures that when aggregated, combine to the Athabasca (Thermal Oil) segment results. Adjusted Funds Flow and Free Cash Flow Adjusted Funds Flow and Free Cash Flow are non-GAAP financial measures and are not intended to represent cash flow from operating activities, net earnings or other measures of financial performance calculated in accordance with IFRS. The Adjusted Funds Flow and Free Cash Flow measures allow management and others to evaluate the Company’s ability to fund its capital programs and meet its ongoing financial obligations using cash flow internally generated from ongoing operating related activities. Sustaining Capital Sustaining Capital is managements' assumption of the required capital to maintain the Company’s production base. Net Cash Net Cash is defined as the face value of term debt, plus accounts payable and accrued liabilities, plus current portion of provisions and other liabilities plus income tax payable less current assets, excluding risk management contracts. Production volumes details This News Release also makes reference to Athabasca's forecasted average daily Thermal Oil production of 33,500 ‐ 35,500 bbl/d for 2025. Athabasca expects that 100% of that production will be comprised of bitumen. Duvernay Energy’s forecasted total average daily production of ~4,000 boe/d for 2025 is expected to be comprised of approximately 68% tight oil, 23% shale gas and 9% NGLs. Liquids is defined as bitumen, tight oil, light crude oil, medium crude oil and natural gas liquids. Break Even is an operating metric that calculates the US$WTI oil price required to fund operating costs (Operating Break-even), sustaining capital (Sustaining Break-even), or growth capital (Total Capital) within Adjusted Funds Flow. Enterprise Value to Debt Adjusted Cash Flow is a valuation metric calculated by dividing Enterprise Value (Market Capitalization plus Net Debt) divided by Cash Flow before interest costs.RICHMOND, Ky. (AP) — Matt Morrissey threw a 67-yard touchdown pass to Marcus Calwise Jr. that ended the scoring midway through the fourth quarter and Eastern Kentucky beat North Alabama 21-15 on Saturday for its fifth straight win. TJ Smith drove North Alabama to the EKU 45-yard line before he threw an interception to Mike Smith Jr. to end the game. Smith threw a 24-yard touchdown pass to Dakota Warfield to give North Alabama a 15-14 lead with 10:37 to play. Morrissey completed 9 of 15 passes for 154 yards and added 60 yards on the ground with a touchdown run. Brayden Latham added 103 yards rushing on 19 carries that included a 2-yard score for Eastern Kentucky (8-4, 6-2 United Athletic Conference). Smith was 23-of-39 passing for 325 yards with a touchdown and two interceptions for North Alabama (3-9, 2-5). Tanaka Scott had 109 yards receiving and a touchdown catch. ___ Get alerts on the latest AP Top 25 poll throughout the season. ___ AP college football: andAnother point of contention is how the new rule may affect user privacy and data security. Some users worry that Tencent Video's monitoring of device usage could lead to potential privacy breaches or data leakage. However, the company has reassured users that the device monitoring is solely for the purpose of enforcing the new rule and ensuring compliance.D.R. Horton director Barbara Allen sells $921,515 in stock
It is essential to highlight the fact that self-prescribing and self-medicating with supplements can have serious consequences. While supplements can play a valuable role in supporting health and well-being when taken appropriately, excessive intake or inappropriate combinations can lead to harmful outcomes, as tragically demonstrated in this case.Title: Woman Cheated of 80,000 RMB by Chasing High Rebates Through Borrowed Money, Police Officer and Scammer Stage Intriguing Tactical Game to Minimize Losses
21.0 EH/s and 967 MW 1,2 under management in mining with path to ~35 EH/s MIAMI, Dec. 05, 2024 (GLOBE NEWSWIRE) — Hut 8 Corp. (Nasdaq | TSX: HUT) (“Hut 8” or the “Company”), a leading, vertically integrated operator of large-scale energy infrastructure and one of North America’s largest Bitcoin miners, today released its operations update for November 2024. “We achieved net increases in deployed self-mining hashrate and efficiency in November by bringing inefficient miners offline in preparation for our initial fleet upgrade and completing the development of our R&D facility at Salt Creek,” said Asher Genoot, CEO of Hut 8. “These measures partially offset the impact of rising network difficulty on Bitcoin production, and we expect further performance gains in Q1 2025 as our initial fleet upgrade is expected to drive an improvement in average fleet efficiency to 19.9 joules per terahash.” “We remain intently focused on growing our proprietary operations and have advanced the buildout of our Vega site on schedule for energization in Q2 2025. Accounting for our fleet upgrade and assuming we fully exercise our purchase option for the miners we expect to host at the Vega site, we have a path to approximately 24 exahash per second of self-mining hashrate with an average fleet efficiency of 15.7 joules per terahash as early as Q2 2025. In parallel, we continue to progress AI data center development opportunities across our development pipeline.” Highlights Operating Metrics Energy Infrastructure Platform 3 Upcoming Conferences & Events: Notes : About Hut 8 Hut 8 Corp. is an energy infrastructure operator and Bitcoin miner with self-mining, hosting, managed services, and traditional data center operations across North America. Headquartered in Miami, Florida, Hut 8 Corp. has a portfolio comprising twenty sites: ten Bitcoin mining, hosting, and Managed Services sites in Alberta, New York, and Texas, five high performance computing data centers in British Columbia and Ontario, four power generation assets in Ontario, and one non-operational site in Alberta. For more information, visit www.hut8.com and follow us on X (formerly known as Twitter) at @Hut8Corp. Cautionary Note Regarding Forward–Looking Information This press release includes “forward-looking information” and “forward-looking statements” within the meaning of Canadian securities laws and United States securities laws, respectively (collectively, “forward-looking information”). All information, other than statements of historical facts, included in this press release that address activities, events or developments that Hut 8 expects or anticipates will or may occur in the future, including such things as future business strategy, competitive strengths, goals, expansion and growth of the business, operations, plans and other such matters is forward-looking information. Forward-looking information is often identified by the words “may”, “would”, “could”, “should”, “will”, “intend”, “plan”, “anticipate”, “allow”, “believe”, “estimate”, “expect”, “predict”, “can”, “might”, “potential”, “predict”, “is designed to”, “likely” or similar expressions. Specifically, such forward-looking information included in this press release includes statements relating to the Company’s planned initial fleet upgrade and the expected resulting performance gains, including expected improvement in average fleet efficiency, its focus on growing its proprietary operations, its buildout and energization of the Vega site, including the expected timing and resulting performance gains, its continuing progress with respect to AI data center development opportunities across its development pipeline and the impact of Ionic’s termination of the managed services agreement. Statements containing forward-looking information are not historical facts, but instead represent management’s expectations, estimates and projections regarding future events based on certain material factors and assumptions at the time the statement was made. While considered reasonable by Hut 8 as of the date of this press release, such statements are subject to known and unknown risks, uncertainties, assumptions and other factors that may cause the actual results, level of activity, performance or achievements to be materially different from those expressed or implied by such forward-looking information, including but not limited to, security and cybersecurity threats and hacks; malicious actors or botnet obtaining control of processing power on the Bitcoin network; further development and acceptance of the Bitcoin network; changes to Bitcoin mining difficulty; loss or destruction of private keys; increases in fees for recording transactions in the Blockchain; erroneous transactions; reliance on a limited number of key employees; reliance on third party mining pool service providers; regulatory changes; classification and tax changes; momentum pricing risk; fraud and failure related to digital asset exchanges; difficulty in obtaining banking services and financing; difficulty in obtaining insurance, permits and licenses; internet and power disruptions; geopolitical events; uncertainty in the development of cryptographic and algorithmic protocols; uncertainty about the acceptance or widespread use of digital assets; failure to anticipate technology innovations; the COVID19 pandemic, climate change; currency risk; lending risk and recovery of potential losses; litigation risk; business integration risk; changes in market demand; changes in network and infrastructure; system interruption; changes in leasing arrangements; failure to achieve intended benefits of power purchase agreements; potential for interrupted delivery, or suspension of the delivery, of energy to mining sites and other risks related to the digital asset mining and data center business. For a complete list of the factors that could affect Hut 8, please see the “Risk Factors” section of Hut 8’s Transition Report on Form 10-K, available under the Company’s EDGAR profile at www.sec.gov , and Hut 8’s other continuous disclosure documents which are available under the Company’s SEDAR+ profile at www.sedarplus.ca and EDGAR profile at www.sec.gov . Hut 8 Corp. Investor Relations Sue Ennis ir@hut8.com Hut 8 Corp. Media Relations media@hut8.com A photo accompanying this announcement is available at https://www.globenewswire.com/NewsRoom/AttachmentNg/c9236ca1-6918-4b97-b9aa-530c73b90a67BOZEMAN, Mont. (AP) — Adam Jones ran for 197 yards and two touchdowns and Montana State ran over Montana 34-11 on Saturday to reclaim the Brawl of the Wild trophy. The Bobcats (12-0, 8-0 Big Sky Conference) wrapped up the 123rd meeting in this rivalry with 420 yards, 326 on the ground. Montana State capped its first unbeaten season and can match the school record for consecutive wins with a playoff win in two weeks. The Bobcats, ranked second in the FCS coaches poll, should be the top seed in the playoffs after top-ranked North Dakota State lost its finale to fifth-ranked South Dakota. Montana (8-4, 5-3), ranked 10th, is expected to add to its record 27 FCS playoff appearances but will not have a first-round bye in the 24-team bracket. Montana State quarterback Tommy Mellott was 6-of-12 passing for 94 yards with a touchdown in poor conditions and added 50 yards and a touchdown on the ground. He has helped the Bobcats score at least 30 points in every game this season Mellott had a 5-yard touchdown run on MSU's first possession and Mellott found Jones for a 35-yard touchdown early in the second quarter for a 14-3 lead. Myles Sansted had two field goals in the final two minutes, including a 49-yarder as time expired for a 20-3 halftime lead. Jones dominated the second half and scored two short touchdowns. Eli Gillman scored on a 1-yard run for Montana's touchdown between the Jones' touchdowns. The Grizzlies had just 234 yards and went 2 of 12 on third down. AP college football: https://apnews.com/hub/ap-top-25-college-football-poll and https://apnews.com/hub/college-football . Sign up for the AP’s college football newsletter: https://apnews.com/cfbtop25
KANSAS CITY, Mo. (AP) — There seemed to be little joy in another last-second win for the Kansas City Chiefs on Sunday. Patrick Mahomes looked stoic after fill-in kicker Spencer Shrader's field goal beat Carolina 30-27 . Travis Kelce, Chris Jones and the rest of the Chiefs merely joined him in walking from the sideline to midfield for handshakes, then headed back to the locker room, a scene completely different from the jubilation they exhibited at the end of so many other nail-biters. Might be that they're getting sick of the stress at the end of games; Kansas City has won 12 straight games decided by seven points or fewer, the longest streak in NFL history, and has won five games decided on the final play this season. Then again, it might be that the Chiefs felt as if they should have beaten the Panthers by a much wider margin. They committed 10 penalties for 91 yards. Their secondary struggled against Carolina quarterback Bryce Young, a one-time bust who has started to play better of late. And their offensive tackles were routinely beaten with Mahomes sacked five times. “You always want to have some blowouts. You want to be a little calmer in the fourth quarter,” said Mahomes, who had one of his best games despite the protection problems, throwing for 269 yards and three touchdowns without an interception. “It can be a good thing as you get to the playoffs and later in the season,” Mahomes added, “just knowing you've been in those moments before, and knowing how to kind of attack it play by play — not making it too big of a moment. I will say this more than anybody, I would love to win a game not by the very last play.” The Chiefs (10-1) nevertheless remained a game ahead of Buffalo in the race for the No. 1 seed in the AFC heading into Friday's game against the Raiders. But there is no margin for error with the Bills now holding the tiebreaker over them. “It’s all about getting better. That’s the best thing about playing in the NFL,” Mahomes said. “We’ve got to just go back, learn from (Carolina), and know we have a short week against a hungry football team in the Raiders that’s coming to our house.” What’s working The Chiefs' tight ends have taken advantage of deep shell coverages played by opposing defenses by getting open underneath, especially Noah Gray , who had his second straight two-touchdown day against the Panthers. He finished with four catches for a team-best 66 yards, while Kelce was right behind with six catches for 62 yards. What needs help The Chiefs have had problems at tackle all season. Wanya Morris struggled again on the left side and veteran Jawaan Taylor was not much better on the right, and they're a big reason why Mahomes has been sacked 15 times over the past four games. Stock up Just a few weeks ago, Shrader was on the Jets practice squad, hoping for a chance to kick in another regular-season game. Now, with Harrison Butker on injured reserve, he is making the most of that chance in Kansas City. The undrafted rookie is 3 for 3 on field goals, including that 31-yard game-winner against Carolina, and perfect on six extra-point attempts. Stock down Just about everyone in the Kansas City secondary struggled against Carolina, whether it was cornerbacks Nazeeh Johnson and Chamarri Conner or safeties Bryan Cook and Justin Reid. Young shredded them for 263 yards passing and a touchdown. Injuries The Chiefs could have running back Isiah Pacheco and pass rusher Charles Omenihu back this week. Both have been practicing the past couple of weeks and were close to playing against Carolina. Pacheco is returning from an ankle injury sustained in Week 2 while Omenihu has not played since tearing his ACL in the playoffs last season. Key number 5 — Kansas City improved to 5-0 against the NFC this season, making it 26-6 against the AFC's rival conference since Mahomes became the franchise's regular starter for the 2018 season. Next steps The Chiefs have won seven of their past eight against Las Vegas heading into Friday's game, though they no doubt remember the Raiders' previous trip to Arrowhead Stadium. Las Vegas pulled the upset on Christmas Day last season. ___ AP NFL: https://apnews.com/hub/nfl Dave Skretta, The Associated PressA judge on Monday rejected a request to block a San Jose State women's volleyball team member from playing in a conference tournament on grounds that she is transgender. Monday's ruling by U.S. Magistrate Judge S. Kato Crews in Denver will allow the player, who has played all season, to compete in the Mountain West Conference women's championship opening this week in Las Vegas. The ruling comes in a lawsuit filed by nine current players against the Mountain West Conference challenging the league's policies for allowing transgender players to participate. The players argued that letting her compete was a safety risk and unfair. While some media have reported those and other details, neither San Jose State nor the forfeiting teams have confirmed the school has a trans woman volleyball player. The Associated Press is withholding the player's name because she has not commented publicly on her gender identity. School officials also have declined an interview request with the player. Crews' ruling referred to the athlete as an "alleged transgender" player and noted that no defendant disputed that the San Jose State roster includes a transgender woman player. San Jose State will "continue to support its student-athletes and reject discrimination in all forms," the university said in a statement, confirming that all its student-athletes are eligible to participate under NCAA and conference rules. "We are gratified that the Court rejected an eleventh-hour attempt to change those rules. Our team looks forward to competing in the Mountain West volleyball tournament this week." The conference did not immediately respond to an email seeking comment. The players filed a notice for emergency appeal with the 10th U.S. Circuit Court of Appeals. Crews said the players who filed the complaint could have sought relief much earlier, noting the individual universities had acknowledged that not playing their games against San Jose State this season would result in a loss in league standings. He also refused a request to re-seed the tournament without the forfeited losses. The judge said injunctions are meant to preserve the status quo. The conference policy regarding forfeiting for refusing to play against a team with a transgender player had been in effect since 2022 and the San Jose State player has been on the roster since 2022 -– making that the status quo. The player competed at the college level three previous seasons, including two for San Jose State, drawing little attention. This season's awareness of her reported identity led to an uproar among some players, pundits, parents and politicians in a major election year. Crews' ruling also said injunctions are meant to prevent harm, but in this case, he argued, the harm has already occurred. The games have been forfeited, the tournament has been seeded, the teams have made travel plans and the participants have confirmed they're playing. The tournament starts Wednesday and continues Friday and Saturday. Colorado State is seeded first and San Jose State, second. The teams split their regular-season matches and both get byes into Friday's semifinals. The conference tournament winner gets an automatic bid to the NCAA tournament. San Jose State coach Todd Kress, whose team has not competed in the national tournament since 2001, has said his team has been getting "messages of hate" and that has taken a toll on his players. Several teams refused to play against San Jose State during the season , earning losses in the official conference standings. Boise State and Wyoming each had two forfeits while Utah State and Nevada both had one. Southern Utah, a member of the Western Athletic Conference, was first to cancel against San Jose State this year. Nevada's players stated they "refuse to participate in any match that advances injustice against female athletes," without elaborating. Nevada did not qualify for the conference tournament. The nine current players and others now suing the Mountain West Conference, the California State University Board of Trustees and others include San Jose State senior setter and co-captain Brooke Slusser. The teammate Slusser says is transgender hits the volleyball with more force than others on the team, raising fear during practices of suffering concussions from a head hit, the complaint says. The Independent Council on Women's Sports is funding a separate lawsuit against the NCAA for allowing transgender women to compete in women's sports. Both lawsuits claim the landmark 1972 federal antidiscrimination law known as Title IX prohibits transgender women in women's sports. Title IX prohibits sexual discrimination in federally funded education; Slusser is a plaintiff in both lawsuits. Several circuit courts have used a U.S. Supreme Court ruling to conclude that discriminating against someone based on their transgender status or sexual orientation is sex-based discrimination, Crews wrote. That means case law does not prove the "likelihood of success" needed to grant an injunction. An NCAA policy that subjects transgender participation to the rules of sports governing bodies took effect this academic year. USA Volleyball says a trans woman must suppress testosterone for 12 months before competing. The NCAA has not flagged any issues with San Jose State. The Republican governors of Idaho, Nevada, Utah and Wyoming have made public statements in support of the team cancellations, citing fairness in women's sports. President-elect Donald Trump likewise has spoken out against allowing transgender women to compete in women's sports. Crews was a magistrate judge in Colorado's U.S. District Court for more than five years before President Joe Biden appointed him as a federal judge in January.AP Business SummaryBrief at 4:36 p.m. EST