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Canada Goose posts wider loss despite new clothing lines resonating with consumers

Canada Goose posts wider loss despite new clothing lines resonating with consumers

TORONTO - Canada Goose Holdings Inc. says its new lines of spring and summer clothing appear to be resonating with consumers, though the company posted a wider net loss in its latest quarter.
Chief executive Dani Reiss said apparel such as T-shirts and polos have been some of the company's best sellers in recent months, helping the company change its perception that it's a winter-only brand.
'The spring summer campaign brought a fresh energy to the brand, playful and relevant with a clear message: We do summer too,' Reiss told analysts on a conference call Thursday.
Rising temperatures and milder winters have pushed some retailers, including Canada Goose, to rethink their product mix. As a result, the company has been expanding its offerings to include lightweight puffers, sweaters, wind and rain wear, shoes and even eyewear in recent years.
Despite the optimism from executives over its new product lines, the luxury parka maker reported a wider net loss of $125.5 million during its fiscal first-quarter, compared with a loss of $74 million during the same quarter last year. The loss was driven partly by higher spending on marketing campaigns and expanding its retail footprint.
On an adjusted basis, the Toronto-based company said it lost $1.29 per diluted share in the quarter, compared with an adjusted loss of 80 cents per diluted share last year.
While its bottom line took a hit, sales were higher.
Revenue for the quarter totalled $107.8 million, up from $88.1 million a year ago.
Direct-to-consumer revenue totalled $78.1 million, up 22.8 per cent from a year ago, while wholesale revenue rose 11.9 per cent to $17.9 million.
Chief financial officer Neil Bowden said expanding the company's offerings over the last 12-15 months has borne fruit.
'Things are working here,' he told analysts. 'That's why we've got confidence around the sustainability of it in spite of what is still a pretty choppy, tough consumer market.'
Consumer confidence has been hampered this year amid ongoing tariff threats from the U.S. and an economic slowdown, leading many shoppers to rein in their spending.
Bowden said 75 per cent of the company's products are made in Canada and nearly all comply with the Canada-U.S.-Mexico Agreement, making them exempt from U.S. tariffs. But it is paying a 'modestly higher tariff' on its European products.
'We continue to monitor the ongoing developments as it relates to potential new U.S. tariffs on Canadian goods as well as potential second-order impacts on the consumer,' Bowden said.
Canada Goose shares were trading nearly nine per cent lower at $16.17 on the Toronto Stock Exchange as of midday Thursday.
This report by The Canadian Press was first published July 31, 2025.
Companies in this story: (TSX: GOOS)
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Greenfire Resources Reports Second Quarter 2025 Results and Provides an Operational Update
Greenfire Resources Reports Second Quarter 2025 Results and Provides an Operational Update

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Greenfire Resources Reports Second Quarter 2025 Results and Provides an Operational Update

Readers are advised to review the "Non-GAAP and Other Financial Measures" section of this press release for information regarding the presentation of financial measures that do not have standardized meaning under IFRS® Accounting Standards. Readers are also advised to review the "Forward-Looking Information" section in this press release for information regarding certain forward-looking information and forward-looking statements contained in this press release. All amounts in this press release are stated in Canadian dollars unless otherwise specified. The Company holds a 75% working interest in the Hangingstone Expansion Facility (the "Expansion Asset") and a 100% working interest in the Hangingstone Demonstration Facility (the "Demo Asset" and, together with the Expansion Asset, the "Hangingstone Facilities"). Unless indicated otherwise, production volumes and per unit statistics are presented throughout this press release on a "gross" basis as determined in accordance with National Instrument 51-101 - Standards for Disclosure for Oil and Gas Activities, which is the Company's gross working interest basis before deduction of royalties. Calgary, Alberta--(Newsfile Corp. - August 6, 2025) - Greenfire Resources Ltd. (NYSE: GFR) (TSX: GFR) ("Greenfire" or the "Company"), today reported its operating and financial results thereto for the quarter ended June 30, 2025 ("Q2 2025"). The unaudited condensed interim consolidated financial statements and notes for the three and six months ended June 30, 2025 and 2024, as well as the related Management's Discussion and Analysis ("MD&A"), will be available on SEDAR+ at on EDGAR at and on Greenfire's website at Q2 2025 Highlights Bitumen production of 15,748 bbls/d Cash provided by operating activities of $17.7 million and Adjusted funds flow(1) of $33.8 million Capital expenditures(2) of $10.8 million Adjusted free cash flow(1) of $23.0 million Financial & Operating Highlights Three Months Ended ($ thousands, unless otherwise indicated)June 30,2025 June 30, 2024 March 31, 2025WTI (US$/bbl)63.74 80.57 71.42WCS differential to WTI (US$/bbl)(10.27 )(13.61 )(12.67 ) WCS Hardisty (US$/bbl)53.47 66.96 58.75Average FX Rate (C$/US$)1.3840 1.3684 1.4348Bitumen production (bbls/d)15,748 18,993 17,495Oil sales144,542 219,444 183,637Royalties(3,932 )(9,919 )(6,824 ) Realized gains (losses) on risk management contracts9,823 (13,798 )(1,101 ) Diluent expense(56,290 )(84,545 )(73,994 ) Transportation and marketing(12,415 )(13,313 )(14,185 ) Operating expenses(31,823 )(34,997 )(37,929 ) Operating netback(1)49,905 62,872 49,604Operating netback(1) ($/bbl)35.06 36.68 31.67Net income and comprehensive income48,730 30,848 16,163Cash provided by operating activities17,732 85,163 34,673Adjusted funds flow(1)33,843 47,207 31,444Capital expenditures(2)(10,840 )(23,009 )(26,299 ) Adjusted free cash flow(1)23,003 24,198 5,145Cash and cash equivalents69,980 159,977 72,238Available credit facilities(3)50,000 50,000 50,000Net debt(1)(216,001 )(283,025 )(253,111 ) Common shares ('000 of shares)70,252 69,276 69,922 (1) Non-GAAP measures without a standardized meaning under IFRS. Refer to the "Non-GAAP and Other Financial Measures" section in this press release.(2) Supplementary financial measure. Refer to the "Non-GAAP and Other Financial Measures" section of this press release.(3) The Company had $50.0 million available under the Senior Credit Facility, with no amounts drawn as at June 30, 2025, June 30, 2024, or March 31, 2025. Q2 2025 Review Greenfire's average production for Q2 2025 was 15,748 bbls/d, representing a 10% decrease from Q1 2025 and below 18,993 bbls/d reported in Q2 2024. Expansion Asset: Production in Q2 2025 was 10,105 bbls/d, reflecting a 20% decrease from the previous quarter. This reduction was primarily attributed to downtime associated with the previously disclosed failure of one of the four steam generators at the Expansion Asset. Demo Asset: Production in Q2 2025 was 5,643 bbls/d, representing a 16% increase from the previous quarter. This growth was driven by the optimization of base well performance. Hangingstone Facilities: Bitumen Production Results (bbls/d)Q2 2025 Q2 2024 Q1 2025Expansion Asset10,105 15,824 12,613Demo Asset5,643 3,169 4,882Consolidated15,748 18,993 17,495 Capital expenditures for Q2 2025 totaled $10.8 million, compared to $23.0 million in the same period of the prior year. Adjusted free cash flow was $23.0 million for Q2 2025, compared to $24.2 million in Q2 2024. Operational Update Production and Steam Generation Updates Greenfire's July 2025 corporate production was approximately 16,000 bbls/d. The Company's production continues to be affected by the previously disclosed failure of one of the four steam generators at the Expansion Asset, resulting in an estimated production impact of 1,500 to 2,250 bbls/d. Full steam capacity is expected to be restored by year-end 2025. Regulatory Engagement and Installation of Sulphur Removal Facilities Greenfire continues to engage with the Alberta Energy Regulator (the "AER") regarding previously disclosed sulphur dioxide emissions that exceed regulatory limits at the Expansion Asset. To support a timely return to compliance, Greenfire has ordered sulphur removal facilities, which are scheduled for installation and commissioning in Q4 2025. Management expects these facilities will restore emissions compliance at a total estimated cost of $11.3 million (previously $15.0 million). Progress Update on Future Development Plans During the second quarter of 2025, Greenfire refined its proposed development plan and operational strategies at the Hangingstone Facilities. The proposed development plan includes a new SAGD well pad ("Pad 7"), consisting of 13 well-pairs, located northeast of the Expansion Asset's Central Processing Facility (the "Expansion CPF") and directly adjacent to existing production (see Exhibit 1). Greenfire has secured a drilling rig, with drilling operations expected to begin in Q4 2025 and first oil production anticipated in Q4 2026. Exhibit 1: Expansion Asset - Pad 7 Development Plan- Pad 7 surface facility (orange), drainage boxes and horizonal well locations (purple) Exhibit 1 To view an enhanced version of this graphic, please visit: Greenfire continues to evaluate further development opportunities at the Hangingstone Facilities, including drilling additional well pairs southeast of the Expansion CPF and optimization opportunities at the Demo Asset to sustain current production rates. 2025 Outlook Greenfire's board of directors has approved a 2025 capital budget of $130 million, with an anticipated 2025 annual production range of 15,000 to 16,000 bbls/d. The budget is evenly allocated between sustaining and growth initiatives. Sustaining initiatives include the restoration of the steam generator and the installation of sulphur removal facilities at the Expansion Asset. Growth initiatives are focused on the development of Pad 7, with drilling operations scheduled to commence in the fourth quarter of 2025. Hedges Greenfire has WTI hedges in place for 9,450 bbls/d at approximately $100.90 per barrel through 2025. For the WCS Hardisty differential, the Company has secured hedges for 12,600 bbl/d for Q3 2025 at US$10.90/bbl and 12,600 bbl/d for Q4 2025 at US$13.50/bbl. The Company will continue to assess market conditions to identify potential additional hedging opportunities. Conference Call Details Greenfire plans to host a conference call on Thursday, August 7, 2025 at 7:00 a.m. Mountain Time (9:00 a.m. Eastern Time), during which members of the Company's executive team will discuss its Q2 2025 results as well as host a question-and-answer session with research analysts. Date: Thursday, August 7, 2025 Time: 7:00 a.m. Mountain Time (9:00 a.m. Eastern Time) Webcast Link: Dial In: 1-833-752-3499 or 1-647-846-7280 Participant instructions: Please ask the operator to join the Greenfire Resources Ltd. call. About Greenfire Greenfire is an oil sands producer actively developing its long-life and low-decline thermal oil assets in the Athabasca region of Alberta, Canada, with its registered offices in Calgary, Alberta. The Company plans to leverage its large resource base and significant infrastructure in place to drive meaningful, capital-efficient production growth. As part of the Company's commitment to operational excellence, safe and reliable operations remain a top priority for Greenfire. Greenfire common shares are listed on the New York Stock Exchange and Toronto Stock Exchange under the trading symbol "GFR". For more information, visit or find Greenfire on LinkedIn and X. Non-GAAP and Other Financial Measures Certain financial measures in this press release are non-GAAP financial measures or ratios. These measures do not have a standardized meaning under IFRS Accounting Standards and therefore may not be comparable to similar measures provided by other companies. These non-GAAP measures should not be considered in isolation or as an alternative for measures of performance prepared in accordance with IFRS Accounting Standards. This press release also contains supplementary financial measures. Non-GAAP financial measures and ratios include operating netback, adjusted funds flow, adjusted free cash flow, net debt and per barrel figures associated with such non-GAAP financial measures. Supplementary financial measures and ratios include gross profit, capital expenditures, and depletion. Non-GAAP Financial Measures Operating Netback (including per barrel ($/bbl)) Gross profit (loss) is the most directly comparable GAAP measure to operating netback which is a non-GAAP measure. Operating netback is further adjusted for realized gain (loss) on risk management contracts, as appropriate. Operating netback per barrel ($/bbl) is calculated by dividing operating netback by the Company's total bitumen sales volume in a specified period. When Operating netback is expressed on a per barrel basis, it is a non-GAAP ratio. Operating netback is a financial measure widely used in the oil and gas industry as a supplementary measure of a company's efficiency and ability to generate cash flow for debt repayments, capital expenditures, or other uses. The following table is a reconciliation of gross profit (loss) to operating netback: Three Months EndedJune 30, June 30, March 31, ($ thousands, unless otherwise noted)2025 2024 2025Gross profit (loss)(1)55,829 58,581 34,392Depletion(1)19,915 17,130 21,561Gain (loss) on risk management contracts(35,662 )959 (5,248 ) Operating netback, excluding realized gain (loss) on risk management contracts40,082 76,670 50,705Realized gain (loss) on risk management contracts(9,823 )(13,798 )(1,101 ) Operating netback49,905 62,872 49,604Operating netback ($/bbl)35.06 36.68 31.67 (1) Supplementary financial measure. Adjusted Funds Flow and Adjusted Free Cash Flow Cash provided by operating activities is the most directly comparable GAAP measure for adjusted funds flow, which is a non-GAAP measure. This measure is not intended to represent cash provided by operating activities calculated in accordance with IFRS Accounting Standards. The adjusted funds flow measure allows management and others to evaluate the Company's ability to fund its capital programs and meet its ongoing financial obligations using cash flow internally generated from ongoing operating related activities. We compute adjusted funds flow as cash provided by operating activities, excluding the impact of changes in non-cash working capital, less transaction costs and transactions considered non-recurring in nature or outside of normal business operations. Cash provided by operating activities is the most directly comparable GAAP measure for adjusted free cash flow, which is a non-GAAP measure. Management uses adjusted free cash flow as an indicator of the efficiency and liquidity of its business, measuring its funds after capital investment that are available to manage debt levels and return capital to shareholders. By removing the impact of current period property, plant and equipment expenditures from adjusted free cash flow, management monitors its adjusted free cash flow to inform its capital allocation decisions. We compute adjusted free cash flow as cash provided by operating activities, excluding the impact of changes in non-cash working capital, less transaction costs, transactions considered non-recurring in nature or outside of normal business operations, property, plant and equipment expenditures and acquisition costs. The following table is a reconciliation of cash provided by operating activities to adjusted funds flow and adjusted free cashflow: Three Months EndedJune 30, June 30, March 31, ($ thousands)2025 2024 2025Cash provided by operating activities17,732 85,163 34,673Non-recurring transactions(1)- - 1,853Changes in non-cash working capital16,111 (37,956 )(5,082 ) Adjusted funds flow33,843 47,207 31,444Property, plant and equipment expenditures(10,840 )(21,824 )(26,299 ) Acquisitions- (1,185 )-Adjusted free cash flow23,003 24,198 5,145 (1) Non-recurring transactions relate to a terminated shareholder rights plan and the evaluation of strategic alternatives. Net Debt The table below reconciles long-term debt to net debt. As atJune 30, June 30, March 31,($ thousands)2025 2024 2025Long-term debt(309,641 )(275,452 )(317,432 ) Current assets187,689 204,785 153,150Current liabilities(66,565 )(264,365 )(93,036 ) Current portion of risk management contracts(31,940 )26,315 (6,101 ) Current portion of warrant liability4,456 25,692 10,308Net debt(216,001 )(283,025 )(253,111 ) Net debt is a non-GAAP measure. Long-term debt is a GAAP measure that is the most directly comparable financial statement measure to net debt. Net debt is comprised of long-term debt, adjusted for current assets and current liabilities on the Company's balance sheet, and excludes the current portions of risk management contracts and warranty liability. Management uses net debt to monitor the Company's current financial position and to evaluate existing sources of liquidity. Net debt is used to estimate future liquidity and whether additional sources of capital are required to fund planned operations. Supplementary Financial Measures Depletion The term "depletion" or "depletion expense" is the portion of depletion and depreciation expense reflecting the cost of development and extraction of the Company's bitumen reserves. Gross Profit (Loss) Gross profit (loss) is a supplementary financial measure prepared on a consistent basis with IFRS Accounting Standards. Greenfire uses gross profit (loss) to assess its core operating performance before considering other expenses such as general and administrative costs, financing costs, and income taxes. Gross profit (loss) is calculated as oil sales, net of royalties, plus gains on risk management contracts, less losses on risk management contracts, diluent expense, operating expense, depletion expense on the Company's operating assets, transportation expenses and marketing expenses. Management believes that gross profit (loss) provides investors, analysts, and other stakeholders with useful insight into the Company's ability to generate profitability from its core operations before non-operating expenses. Three Months EndedJune 30, June 30, March 31, ($ thousands)2025 2024 2025Oil sales, net of royalties140,610 209,525 176,813Gain (loss) on risk management contracts35,662 (959 )5,248176,272 208,566 182,061Diluent expense(56,290 )(84,545 )(73,994 ) Transportation and marketing(12,415 )(13,313 )(14,185 ) Operating expenses(31,823 )(34,997 )(37,929 ) Depletion(19,915 )(17,130 )(21,561 ) Gross profit (loss)55,829 58,581 34,392 Capital Expenditures Capital expenditures is a supplementary financial measure prepared on a consistent basis with IFRS Accounting Standards. Greenfire uses capital expenditures to monitor the cash flows it invests into property, plant and equipment. Capital expenditures is derived from the statement of cash flows and includes property, plant and equipment expenditures and acquisitions. Management believes that capital expenditures provides investors, analysts and other stakeholders with a useful insight into the Company's investments into property, plant and equipment. Three Months EndedJune 30, June 30, March 31, ($ thousands)2025 2024 2025Property, plant and equipment expenditures10,840 28,124 26,299Acquisitions- 1,185 -Capital expenditures10,840 23,009 26,299 Forward-Looking Information This press release contains forward-looking information and forward-looking statements (collectively, "forward-looking information") within the meaning of applicable securities laws. The forward-looking information in this press release is based on Greenfire's current internal expectations, estimates, projections, assumptions, and beliefs. Such forward-looking information is not a guarantee of future performance and 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. The Company believes the material factors, expectations and assumptions reflected in the forward-looking information are reasonable as of the time of such information, but no assurance can be given that these factors, expectations and assumptions will prove to be correct, and such forward-looking information included in this press release should not be unduly relied upon. The use of any of the words "expect", "target", "anticipate", "intend", "estimate", "objective", "ongoing", "may", "will", "project", "believe", "depends", "could" and similar expressions are intended to identify forward-looking information. In particular, but without limiting the generality of the foregoing, this press release contains forward-looking information pertaining to the following: the expected timing for the restoration of full steam capacity at the Expansion Asset; Greenfire's discussions with the AER regarding previously disclosed sulphur dioxide emissions exceedance, including the expected timing of installation and commissioning of a sulphur recovery unit and that this initiative will effectively restore compliance with sulphur dioxide emissions requirements at the Expansion Asset; Greenfire's plans including development and construction around the Expansion CPF and the anticipated timing and costs thereof; the 2025 Outlook, including the Company's capital budget and the anticipated allocation thereof, and the Company's production guidance; development plans for a new SAGD pad; development plans, capital expenditures and operational strategies for the Expansion Asset and the Demo Asset; that the Company will continue to assess market conditions to identify potential additional hedging opportunities; and statements relating to the business and future activities of the Company after the date of this press release. Management approved the capital budget and production guidance contained herein as of the date of this press release. The purpose of the capital budget and production guidance is to assist readers in understanding the Company's expected and targeted financial position and performance, and this information may not be appropriate for other purposes. Forward-looking information in this press release relating to oil and gas exploration, development and production, and management's general expectations relating to the oil and gas industry are based on estimates prepared by management using data from publicly available industry sources as well as from market research and industry analysis and on assumptions based on data and knowledge of the industry which management believes to be reasonable. Although generally indicative of relative market positions, market shares and performance characteristics, this data is inherently imprecise. Management is not aware of any misstatements regarding any industry data presented in press release. All forward-looking information reflects Greenfire's beliefs and assumptions based on information available at the time the applicable forward-looking information is disclosed and in light of the Company's current expectations with respect to such matters as: the success of Greenfire's operations and growth and expansion projects; expectations regarding production growth, future well production rates and reserves volumes; expectations regarding Greenfire's capital program; the outlook for general economic trends, industry trends, prevailing and future commodity prices, foreign exchange rates and interest rates; prevailing and future royalty regimes and tax laws; expectations regarding differentials and realized prices; future well production rates and reserves volumes; fluctuations in energy prices based on worldwide demand and geopolitical events; the impact of inflation; the integrity and reliability of Greenfire's assets; decommissioning obligations; Greenfire's ability to comply with its financial covenants; Greenfire's ability to comply with applicable regulations, including those related to various emissions; Greenfire's ability to obtain all applicable regulatory approvals in connection with the operation of its business; and the governmental, regulatory and legal environment. Management believes that its assumptions and expectations reflected in the forward-looking information contained herein are reasonable based on the information available on the date such information is provided and the process used to prepare the information. However, Greenfire cannot assure readers that these expectations will prove to be correct. The forward-looking information included in this press release is not a guarantee of future performance and 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, including, without limitation: changes in oil and gas prices and differentials; changes in the demand for or supply of Greenfire's products; the continued impact, or further deterioration, in global economic and market conditions, including from inflation and/or certain geopolitical conflicts, such as the ongoing war in Eastern Europe and the conflict in the Middle East, and other heightened geopolitical risks, including imposition of tariffs or other trade barriers, and the ability of the Company to carry on operations as contemplated in light of the foregoing; determinations by OPEC and other countries as to production levels; unanticipated operating results or production declines; changes in tax or environmental laws, climate change regulations, royalty rates or other regulatory matters; changes in Greenfire's operating and development plans; reliability of Company owned and third party facilities, infrastructure and pipelines required for Greenfire's operations and production; competition for, among other things, capital, acquisitions of reserves and resources, undeveloped lands, access to services, third party processing capacity and skilled personnel; inability to retain drilling rigs and other services; severe weather conditions, including wildfires, impacting Greenfire's operations and third party infrastructure; availability of diluent, natural gas and power to operate Greenfire's facilities; failure to realize the anticipated benefits of the Company's acquisitions; incorrect assessment of the value of acquisitions; delays resulting from or inability to obtain required regulatory approvals; increased debt levels or debt service requirements; inflation; changes in foreign exchange rates; inaccurate estimation of Greenfire's bitumen reserves volumes; limited, unfavourable or a lack of access to capital markets or other sources of capital; increased costs; failure to comply with applicable regulations, including relating to the Company's air emissions, and potentially significant penalties and orders associated therewith and associated significant effect on the Company's business, operations, production, reserves estimates and financial condition; a lack of adequate insurance coverage; and other factors discussed under the "Risk Factors" section in Greenfire's Management's Discussion & Analysis for the interim period ended June 30, 2025 and Annual Information Form dated March 17, 2025, and from time to time in Greenfire's public disclosure documents, which are available on the Company's SEDAR+ profile at and in the Company's annual report on Form 40-F filed with the SEC, which is available on the Company's EDGAR profile at The foregoing risks should not be construed as exhaustive. The forward-looking information contained in this press release speaks only as of the date of this press release and Greenfire does not assume any obligation to publicly update or revise such forward-looking information to reflect new events or circumstances, except as may be required pursuant to applicable laws. Any forward-looking information contained herein is expressly qualified by this cautionary statement. Contact Information Greenfire Resources Ltd.205 5th Avenue SWSuite 1900Calgary, AB T2P 2V7 investors@ To view the source version of this press release, please visit Error in retrieving data Sign in to access your portfolio Error in retrieving data Error in retrieving data Error in retrieving data Error in retrieving data

SPARTAN DELTA CORP. ANNOUNCES SECOND QUARTER 2025 RESULTS AND OPERATIONS UPDATE
SPARTAN DELTA CORP. ANNOUNCES SECOND QUARTER 2025 RESULTS AND OPERATIONS UPDATE

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SPARTAN DELTA CORP. ANNOUNCES SECOND QUARTER 2025 RESULTS AND OPERATIONS UPDATE

CALGARY, AB, Aug. 6, 2025 /CNW/ - Spartan Delta Corp. ("Spartan" or the "Company") (TSX: SDE) is pleased to report its unaudited financial and operating results for the three and six months ended June 30, 2025. Selected financial and operational information is set out below and should be read in conjunction with Spartan's unaudited interim financial statements and related management's discussion and analysis ("MD&A") for the three and six months ended June 30, 2025, and 2024, which are filed on SEDAR+ at and are available on the Company's website at The highlights reported in this press release include certain non-GAAP financial measures and ratios which have been identified using capital letters. The reader is cautioned that these measures may not be directly comparable to other issuers; please refer to additional information under the heading "Reader Advisories – Non-GAAP Measures and Ratios". OPERATIONS UPDATE Spartan successfully completed its first half 2025 capital program, highlighting strong execution and operational discipline across its West Shale Basin Duvernay (the "Duvernay") and Deep Basin assets. In H1 2025, Spartan ran a four rig capital program, drilling 21.0 (17.1 net) wells, completing 15.0 (11.4 net) wells, and bringing on-stream 11.0 (8.6 net) wells. During the second quarter, the Company drilled 8.0 (7.3 net) wells, completed 10.0 (7.5 net) wells, and brought on-stream 6.0 (4.7 net) wells. Spartan is on course to meet its 2025 guidance of 40,000 BOE/d and is well-positioned for continued operational momentum entering the second half of 2025. With a strong balance sheet, disciplined capital allocation, significant liquids growth, and a deep inventory of locations, Spartan is committed to delivering significant value for shareholders while maintaining a responsible and sustainable development strategy. DUVERNAY In the Duvernay, the Company contracted two rigs and drilled 12.0 (9.6 net) wells, completed 7.0 (4.9 net wells), and brought on-stream 3.0 (2.1 net) wells during H1 2025. In Q2 2025, Spartan drilled 6.0 (5.4 net) wells, completed 7.0 (4.9 net) wells, and brought on-stream 3.0 (2.1 net) wells, wine-racking in both the upper and lower Duvernay benches. The utilization of wine-racking well designs has the potential to significantly increase recoveries on the Company's acreage. 06-04-043-03W5 Pad Initial production results from 3.0 (2.1 net) wells have averaged IP30 rates of 1,261 BOE/d and 86% liquids per well (1,042 BBL/d of crude oil, 49 BBL/d of NGLs, and 1.0 MMcf/d of natural gas). 02-22-042-03W5 Pad Initial results from the Company's most recent 4.0 (2.8 net) wells are encouraging as production rates exceed internal expectations. Current field production estimates for the first 15 days are averaging greater than 1,600 BOE/d with more than 1,300 BBL/d of crude oil and NGLs per well. 07-15-044-03W5 Pad Spartan has commenced completions on 4.0 (4.0 net) wells. 04-20-041-03W5 Pad Spartan has begun drilling operations. In the second half of 2025, the Company anticipates drilling 5.0 (5.0 net) wells, completing 10.0 (10.0 net) wells, and bringing on-stream 14.0 (12.8 net) wells. Spartan's 2025 Duvernay program has benefited from a strong focus on reducing costs. These improvements stem from decreasing drilling and completion times, consistent frac placements, optimizing proppant tonnage, and reducing water usage. The Company is motivated to further reduce drilling and completion costs as it continues to build scale. Spartan's Duvernay results have exceeded internal expectations to date, underscoring the productivity and consistency of its acreage. Current Duvernay field production estimates are greater than 9,000 BOE/d (77% liquids), a 400% increase in production in twelve months. DEEP BASIN In the Deep Basin, the Company drilled 9.0 (7.5 net) wells and completed and brought on-stream 8.0 (6.5 net) wells during H1 2025. In Q2 2025, Spartan drilled 2.0 (1.9 net) wells and completed and brought on-stream 3.0 (2.6 net) wells. 08-21-045-11W5 & 10-20-043-09W5 Initial Spirit River production results averaged IP30 rates of 1,657 BOE/d and 25% liquids per well and IP90 rates of 1,254 BOE/d and 24% liquids per well. 03-07-045-09W5 Pad Initial production results from 3.0 (3.0 net) Cardium wells averaged IP30 rates of 482 BOE/d and 43% liquids per well and IP90 rates of 566 BOE/d and 42% liquids per well. 14-08-044-08W5 Pad Initial production results from 3.0 (3.0 net) Cardium wells are exceeding internal expectations, averaging IP30 rates of 1,203 BOE/d and 40% liquids per well. 15-25-044-09W5 Spirit River well is significantly exceeding internal expectations, with the well onstream for less than 30 days. In the second half of 2025, the Company anticipates drilling 10.0 (9.2 net) wells and completing and bringing on-stream 9.0 (8.2 net) wells, focusing on drilling liquid-rich targets in the Cardium, Spirit River, Rock Creek, Viking, Belly River, and Wilrich formations. The Deep Basin maintains the optionality to increase capital and accelerate drilling to capture the contango forward curve in natural gas prices as the asset benefits from reduced cycle times. SECOND QUARTER 2025 HIGHLIGHTS Spartan reported production of 38,513 BOE/d (36% liquids) during the second quarter of 2025. Spartan achieved a 151% increase in crude oil production as compared to the second quarter of 2024 and a 12% increase as compared to the first quarter of 2025. The Company's operations generated oil and gas sales of $81.0 million and Adjusted Funds Flow of $47.9 million ($0.23 per share, diluted) in the second quarter of 2025, a 29% increase from the second quarter of 2024, and a 5% increase from the first quarter of 2025. The Company successfully executed a capital program of $83.5 million in the second quarter of 2025, of which approximately 85% was spent on drilling, completing, equipping, and tie-ins. In the Duvernay, Spartan drilled 6.0 (5.4 net) wells, completed 7.0 (4.9 net) wells, and brought on-stream 3.0 (2.1 net) wells. In the Deep Basin, Spartan drilled 2.0 (1.9 net) wells and completed and brought on-stream 3.0 (2.6 net) wells. Spartan has accumulated approximately 365,000 net acres (570 net sections) in the Duvernay, a 52% increase from the second quarter of 2024 and a 14% increase from the first quarter of 2025. Spartan continues to maintain a strong statement of financial position with Net Debt of $123.7 million resulting in a 0.7X Net Debt to Annualized Adjusted Funds Flow ratio. Despite volatile commodity prices, Spartan has hedges in place for the remainder of 2025 greater than current strip. As at June 30, 2025, the Company has hedged 91,065 GJ/d of its natural gas production at an average price of $2.25/GJ and has hedged 2,700 bbl/d of its crude oil and condensate production at an average price of $99.75/bbl. The following table summarizes the Company's financial and operating results for the three and six months ended June 30, 2025, and June 30, months ended June 30 Six months ended June 30 (CA$ thousands, unless otherwise indicated) 2025 2024 % 2025 2024 % FINANCIAL HIGHLIGHTS Oil and gas sales 81,004 73,451 10 172,245 157,599 9 Net income and comprehensive income 33,531 14,371 133 28,362 25,566 11 $ per share, basic (1) 0.17 0.09 89 0.14 0.15 (7) $ per share, diluted (1) 0.17 0.09 89 0.14 0.15 (7) Cash provided by operating activities 43,627 44,674 (2) 99,895 92,825 8 Adjusted Funds Flow (2) 47,949 37,177 29 93,514 82,850 13 $ per share, basic (1)(2) 0.24 0.22 9 0.48 0.48 - $ per share, diluted (1)(2) 0.23 0.21 10 0.46 0.47 (2) Free Funds Flow (deficit) (2) (35,581) 14,623 nm (62,769) 15,261 nm Cash used in investing activities 84,393 101,377 (17) 134,576 152,513 (12) Capital Expenditures before A&D (2) 83,530 22,554 270 156,283 67,589 131 Adjusted Net Capital A&D (2) 6,067 54,401 (89) 6,020 72,468 (92) Total assets 1,037,524 884,244 17 1,037,524 884,244 17 Debt 66,476 109,040 (39) 66,476 109,040 (39) Net Debt (2) 123,739 132,449 (7) 123,739 132,449 (7) Shareholders' equity 600,077 458,802 31 600,077 458,802 31 Common shares outstanding, end of period (000s) (1) 200,060 173,201 16 200,060 173,201 16 OPERATING HIGHLIGHTS Average daily production Crude oil (bbls/d) 2,485 992 151 2,349 870 170 Condensate (bbls/d) (3) 2,056 2,198 (6) 2,021 2,154 (6) NGLs (bbls/d) (3) 9,304 9,084 2 9,460 9,263 2 Natural gas (mcf/d) 148,010 157,853 (6) 147,549 157,623 (6) BOE/d 38,513 38,583 (0) 38,422 38,558 (0) Average realized prices, before financial instruments Crude oil ($/bbl) 87.33 102.04 (14) 90.63 97.85 (7) Condensate ($/bbl) (3) 86.61 100.29 (14) 92.31 98.23 (6) NGLs ($/bbl) (3) 23.78 29.96 (21) 27.17 30.51 (11) Natural gas ($/mcf) 1.85 1.35 37 2.00 1.82 10 Combined average ($/BOE) 23.11 20.92 10 24.77 22.46 10 Operating Netbacks ($/BOE) (2) Oil and gas sales 23.11 20.92 10 24.77 22.46 10 Processing and other revenue 1.19 0.52 129 0.77 0.48 60 Net commodities purchased margin 0.09 - - 0.04 - - Royalties (2.98) (2.89) 3 (3.38) (3.09) 9 Operating expenses (6.02) (6.38) (6) (6.26) (6.01) 4 Transportation expenses (1.73) (1.50) 15 (1.73) (1.54) 12 Operating Netback, before hedging ($/BOE) (2) 13.66 10.67 28 14.21 12.30 16 Operating Netback, after hedging ($/BOE) (2) 14.70 12.91 14 15.14 13.64 11 Adjusted Funds Flow Netback ($/BOE) (2) 13.68 10.59 29 13.45 11.81 14 (1) Refer to "Share Capital" section of this press release. (2) "Adjusted Funds Flow", "Free Funds Flow", "Capital Expenditures before A&D", "Adjusted Net Capital A&D", "Net Debt" and "Operating Netbacks" do not have standardized meanings under IFRS Accounting Standards, refer to "Non-GAAP Measures and Ratios" section of this press release. (3) Condensate is a natural gas liquid as defined by NI 51-101. See "Other Measurements". ABOUT SPARTAN DELTA CORP. Spartan is committed to creating value for its shareholders, focused on sustainability in both operations and financial performance. The Company's culture is centered on generating Free Funds Flow through responsible oil and gas exploration and development. The Company has established a portfolio of high-quality production and development opportunities in the Deep Basin and the Duvernay. Spartan will continue to focus on the execution of the Company's organic drilling program across its portfolio, delivering operational synergies in a respectful and responsible manner in relation to the environment and communities it operates in. The Company is well positioned to continue pursuing optimization in the Deep Basin, participate in the consolidation of the Deep Basin fairway, and continue growing and developing its Duvernay asset. Spartan's corporate presentation, as of August 6, 2025, can be accessed on the Company's website at READER ADVISORIES Non-GAAP Measures and Ratios This press release contains certain financial measures and ratios which do not have standardized meanings prescribed by International Financial Reporting Standards ("IFRS Accounting Standards") or Generally Accepted Accounting Principles ("GAAP"). As these non-GAAP financial measures and ratios are commonly used in the oil and gas industry, Spartan believes that their inclusion is useful to investors. The reader is cautioned that these amounts may not be directly comparable to measures for other companies where similar terminology is used. The non-GAAP measures and ratios used in this press release, represented by the capitalized and defined terms outlined below, are used by Spartan as key measures of financial performance, and are not intended to represent operating profits nor should they be viewed as an alternative to cash provided by operating activities, net income or other measures of financial performance calculated in accordance with IFRS Accounting Standards. The definitions below should be read in conjunction with the "Non-GAAP Measures and Ratios" section of the Company's MD&A dated August 6, 2025, which includes discussion of the purpose and composition of the specified financial measures and detailed reconciliations to the most directly comparable GAAP financial measures. Operating Income and Operating Netback Operating Income, a non-GAAP financial measure, is a useful supplemental measure that provides an indication of the Company's ability to generate cash from field operations, prior to administrative overhead, financing, and other business expenses. "Operating Income, before hedging" is calculated by Spartan as oil and gas sales, net of royalties, plus processing and other revenue and net commodities purchased margin, less operating and transportation expenses. "Operating Income, after hedging" is calculated by adjusting Operating Income for realized gains or losses on derivative financial instruments. The Company refers to Operating Income expressed per unit of production as an "Operating Netback" and reports the Operating Netback before and after hedging, both of which are non-GAAP financial ratios. Spartan considers Operating Netback an important measure to evaluate its operational performance as it demonstrates its field level profitability relative to current commodity prices. Adjusted Funds Flow and Free Funds Flow Cash provided by operating activities is the most directly comparable measure to Adjusted Funds Flow. "Adjusted Funds Flow" is a non-GAAP financial measure reconciled to cash provided by operating activities by excluding changes in non-cash working capital, adding back transaction costs on acquisitions and dispositions, and deducting the principal portion of lease payments. Spartan utilizes Adjusted Funds Flow as a key performance measure in the Company's annual financial forecasts and public guidance. Transaction costs, which primarily include legal and financial advisory fees, regulatory and other expenses directly attributable to execution of acquisitions and dispositions, are added back because the Company's definition of Free Funds Flow excludes capital expenditures related to acquisitions and dispositions. For greater clarity, incremental overhead expenses related to restructuring following significant acquisition or divestitures are included in Spartan's general and administrative expenses. Lease liabilities are not included in Spartan's definition of Net Debt therefore lease payments are deducted in the period incurred to determine Adjusted Funds Flow. The Company refers to Adjusted Funds Flow expressed per unit of production as an "Adjusted Funds Flow Netback". "Free Funds Flow" is a non-GAAP financial measure calculated by Spartan as Adjusted Funds Flow less Capital Expenditures before A&D. Spartan believes Free Funds Flow provides an indication of the amount of funds the Company has available for future capital allocation decisions such as to repay current and long-term debt, reinvest in the business or return capital to shareholders. Adjusted Funds Flow per share Adjusted Funds Flow ("AFF") per share is a non-GAAP financial ratio used by the Company as a key performance indicator. AFF per share is calculated using the same methodology as net income per share ("EPS"), however the diluted weighted average common shares ("WA Shares") outstanding for AFF may differ from the diluted weighted average determined in accordance with IFRS Accounting Standards for purposes of calculating EPS due to non-cash items that impact net income only. The impact of stock options and share awards is more dilutive to AFF than EPS because the number of shares deemed to be repurchased under the treasury stock method is not adjusted for unrecognized share-based compensation expense as it is non-cash (see also, "Share Capital"). Capital Expenditures before A&D "Capital Expenditures before A&D" is a non-GAAP financial measure used by Spartan to measure its capital investment level compared to the Company's annual budgeted capital expenditures for its organic drilling program. It includes capital expenditures on exploration and evaluation assets and property, plant and equipment, before acquisitions and dispositions. The directly comparable GAAP measure to Capital Expenditures before A&D is cash used in investing activities. Adjusted Net Capital A&D "Adjusted Net Capital A&D" is a supplemental measure disclosed by Spartan which aggregates the total amount of cash, debt, and share consideration used to acquire crude oil and natural gas assets during the period, net of cash proceeds received on dispositions. The Company believes this is useful information because it is more representative of the total transaction value than the cash acquisition costs or total cash used in investing activities, determined in accordance with IFRS Accounting Standards. The most directly comparable GAAP measures are acquisition costs and disposition proceeds included as components of cash used in investing activities. Net Debt and Adjusted Working Capital References to "Net Debt" includes long-term debt under Spartan's revolving credit facility, net of Adjusted Working Capital. Net Debt and Adjusted Working Capital are both non-GAAP financial measures. "Adjusted Working Capital" is calculated as current assets less current liabilities, excluding derivative financial instrument assets and liabilities, lease liabilities, and current debt (if applicable). The Adjusted Working Capital deficit includes cash and cash equivalents, restricted cash, accounts receivable, prepaid expenses and deposits, accounts payable and accrued liabilities, dividends payable, and the current portion of decommissioning obligations. Spartan uses Net Debt as a key performance measure to manage the Company's targeted debt levels. The Company believes its presentation of Adjusted Working Capital and Net Debt are useful as supplemental measures because lease liabilities and derivative financial instrument assets and liabilities relate to contractual obligations for future production periods. Lease payments and cash receipts or settlements on derivative financial instruments are included in Spartan's reported Adjusted Funds Flow in the production month to which the obligation relates. Net Debt to Adjusted Funds Flow Ratio The Company monitors its capital structure using a "Net Debt to Adjusted Funds Flow Ratio", which is a non-GAAP financial ratio calculated as the ratio of the Company's Net Debt to its "Annualized Adjusted Funds Flow". Annualized Adjusted Funds Flow is calculated by multiplying Adjusted Funds Flow for the most recently completed quarter, normalized for significant non-recurring items, by a factor of four. OTHER MEASUREMENTS All dollar figures included herein are presented in Canadian dollars, unless otherwise noted. This press release contains various references to the abbreviation "BOE" which means barrels of oil equivalent. Where amounts are expressed on a BOE basis, natural gas volumes have been converted to oil equivalence at six thousand cubic feet (mcf) per barrel (bbl). The term BOE may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet per barrel is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead and is significantly different than the value ratio based on the current price of crude oil and natural gas. This conversion factor is an industry accepted norm and is not based on either energy content or current prices. References to "oil" in this press release include light crude oil and medium crude oil, combined. National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (NI 51-101) includes condensate within the product type of "natural gas liquids". References to "natural gas liquids" or "NGLs" include pentane, butane, propane, and ethane. References to "gas" or "natural gas" relates to conventional natural gas. References to "liquids" includes crude oil, condensate and NGLs. The Company has disclosed condensate as combined with crude oil and/or separately from other natural gas liquids in this press release since the price of condensate as compared to other natural gas liquids is currently significantly higher and the Company believes that this crude oil and condensate presentation provides a more accurate description of its operations and results. SHARE CAPITAL Spartan's common shares are listed on the Toronto Stock Exchange ("TSX") and trade under the symbol "SDE". The volume weighted average trading price of Spartan's common shares on the TSX was $3.12 for the three months ended June 30, 2025. Spartan's closing share price was $3.81 on June 30, 2025, compared to $3.45 on December 31, 2024. As of June 30, 2025, there were 200.1 million common shares outstanding. There are no preferred shares or special preferred shares outstanding. The table below summarizes the weighted average number of common shares outstanding (000s) used in the calculation of diluted EPS and diluted AFF per share:Three months ended June 30 Six months ended June 30 (000s) 2025 2024 % 2025 2024 % WA Shares outstanding, basic 200,052 173,201 16 195,669 173,201 13 Dilutive effect of outstanding securities 2,064 1,765 17 2,358 1,537 53 WA Shares, diluted – for EPS 202,116 174,966 16 198,027 174,738 13 Incremental dilution for AFF (1) 3,949 2,339 69 3,744 2,465 52 WA Shares, diluted – for AFF (1) 206,065 177,305 16 201,771 177,203 14 (1) AFF per share does not have a standardized meaning under IFRS Accounting Standards, refer to "Non-GAAP Measures and Ratios". FORWARD-LOOKING AND CAUTIONARY STATEMENTS Certain statements contained within this press release constitute forward-looking statements within the meaning of applicable Canadian securities legislation. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "outlook", "anticipate", "budget", "plan", "endeavor", "continue", "estimate", "evaluate", "expect", "forecast", "monitor", "may", "will", "can", "able", "potential", "target", "intend", "consider", "focus", "identify", "use", "utilize", "manage", "maintain", "remain", "result", "cultivate", "could", "should", "believe" and similar expressions (or grammatical variations or negatives thereof). Spartan believes that the expectations reflected in such forward-looking statements are reasonable as of the date hereof, but no assurance can be given that such expectations will prove to be correct and such forward-looking statements should not be unduly relied upon. Without limitation, this press release contains forward-looking statements pertaining to: the business plan, objectives, strategy of Spartan; continued optimization of its Deep Basin asset, participation in the consolidation of the Deep Basin fairway and advancing and accelerating its Duvernay strategy; the Company's drilling strategy in the Deep Basin; expected drilling and completions in the Duvernay; expectations that the utilization of wine-racking well designs will significantly increase recoveries on the Company's acreage; further reductions to drilling and completion costs as Spartan continues to build scale; Spartan's strategies to deliver strong, repeatable and economic operational performance and to generate significant shareholder returns; the ability of the Company to achieve drilling success consistent with management's expectations; being well positioned to take advantage of opportunities in the current business environment; risk management activities, including hedging; continuing to pursue immediate production optimization and responsible future growth with organic drilling, and continuing to execute on building an extensive position in the Duvernay. The forward-looking statements and information are based on certain key expectations and assumptions made by Spartan, including, but not limited to, expectations and assumptions concerning the business plan of Spartan, the timing of and success of future drilling, development and completion activities, the growth opportunities of Spartan's Duvernay acreage, the performance of existing wells, the performance of new wells, the availability and performance of facilities and pipelines, the geological characteristics of Spartan's properties, the successful application of drilling, completion and seismic technology, the Company's ability to secure sufficient amounts of water, prevailing weather conditions, prevailing legislation affecting the oil and gas industry, prevailing commodity prices, price volatility, future commodity prices, price differentials and the actual prices received for the Company's products (including pursuant to hedging arrangements), anticipated fluctuations in foreign exchange and interest rates, impact of inflation on costs, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the availability of capital, labour and services, the creditworthiness of industry partners, general economic conditions, and the ability to source and complete acquisitions. Although Spartan believes that the expectations and assumptions on which such forward-looking statements and information are based are reasonable, undue reliance should not be placed on the forward-looking statements and information because Spartan can give no assurance that they will prove to be correct. By its nature, such forward-looking information is subject to various risks and uncertainties, which could cause the actual results and expectations to differ materially from the anticipated results or expectations expressed. These risks and uncertainties include, but are not limited to, fluctuations and volatility in commodity prices; changes in industry regulations and legislation (including, but not limited to, tax laws, royalties, and environmental regulations); the risk that the U.S. administration (i) maintains tariffs on Canadian goods, including crude oil and natural gas, (ii) increases the rate or scope of previously announced tariffs, or (iii) imposes new tariffs on the import of goods from Canada; the risk that the U.S. and/or Canada imposes any other form of tax, restriction or prohibition on the import or export of products from one country to the other, including crude oil and natural gas, and that such tariffs or other measures (and/or the Canadian government's response to such tariffs or other measures) adversely affect the Canadian, U.S., and global economies, and by extension the Canadian oil and natural gas industry and the Company; demand and/or market price for the Company's products and/or otherwise adversely affects the Company; changes in the political landscape both domestically and abroad, wars (including ongoing military actions in the Middle East and between Russia and Ukraine), hostilities, civil insurrections, foreign exchange or interest rates, increased operating and capital costs due to inflationary pressures (actual and anticipated), risks associated with the oil and gas industry in general, stock market and financial system volatility, impacts of pandemics, the retention of key management and employees, risks with respect to unplanned third-party pipeline outages and risks relating to inclement and severe weather events and natural disasters, including fire, drought, and flooding, including in respect of safety, asset integrity and shutting-in production. Please refer to Spartan's MD&A for the period ended June 30, 2025, and annual information form for the year ended December 31, 2024, for discussion of additional risk factors relating to the Company, which can be accessed either on Spartan's website at or under Spartan's SEDAR+ profile on Readers are cautioned not to place undue reliance on this forward-looking information, which is given as of the date hereof, and to not use such forward-looking information for anything other than its intended purpose. Spartan undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, except as required by law. This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about Spartan's 2025 guidance, including prospective results of operations and production (including 2025 guidance of 40,000 BOE/d), operating costs, organic growth, capital efficiency improvements and components thereof, all of which are subject to the same assumptions, risk factors, limitations, and qualifications as set forth in the above paragraphs. FOFI contained in this document was approved by management as of the date of this document and was provided for the purpose of providing further information about Spartan's future business operations. Spartan and its management believe that FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments, and represent, to the best of management's knowledge and opinion, the Company's expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results. Spartan disclaims any intention or obligation to update or revise any FOFI contained in this document, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this document should not be used for purposes other than for which it is disclosed herein. Changes in forecast commodity prices, differences in the timing of capital expenditures, and variances in average production estimates can have a significant impact on the key performance measures included in Spartan's guidance. The Company's actual results may differ materially from these estimates. References in this press release to peak rates, peak sales production, initial production rates, IP30s, IP90s, test rates, and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long-term performance or of ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Spartan. The Company cautions that such results should be considered preliminary. Peak rates are the highest average daily sales production rate for each well excluding clean-up and downtime. ABBREVIATIONS A&D acquisitions and dispositions bbl barrel bbls/d barrels per day BOE/d barrels of oil equivalent per day CA$ or CAD Canadian dollar GJ gigajoule GJ/d gigajoule per day IP Initial production mcf thousand cubic feet mcf/d thousand cubic feet per day Mbbls thousand barrels MBOE thousand barrels of oil equivalent MMbtu million British thermal units MMcf million cubic feet MM millions $MM millions of dollars US$ or USD United States dollar WA Weighted average WI Working interest SOURCE Spartan Delta Corp. View original content to download multimedia: Error in retrieving data Sign in to access your portfolio Error in retrieving data Error in retrieving data Error in retrieving data Error in retrieving data

Ottawa upholds CRTC's wholesale internet rules, says they will foster competition
Ottawa upholds CRTC's wholesale internet rules, says they will foster competition

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time27 minutes ago

  • Yahoo

Ottawa upholds CRTC's wholesale internet rules, says they will foster competition

Ottawa says it will uphold a ruling by Canada's telecommunications regulator allowing the country's largest internet companies to provide service to customers using fibre networks built by their rivals — as long as they do so outside their core regions. Industry Minister Mélanie Joly says in a statement the CRTC's ruling "will immediately allow for more competition on existing networks for high-speed internet services across the country." In June, the regulator issued its final decision on the contentious matter, which has pitted Telus Corp. against rivals BCE Inc. and Rogers Communications Inc., and many smaller providers that opposed the framework. The federal government had previously asked the commission to reconsider whether the Big Three providers should be able to act as wholesalers under the rules, citing concern about the viability of smaller internet providers to act as alternatives. Ottawa had until Aug. 13 to overturn the CRTC's ruling, but Joly says she decided not to alter the CRTC's decision as it "was based on extensive consultation with experts, the Competition Bureau and over 300 public submissions." The CRTC has said the rules effectively balance the need for both competition and investment, while only having a "modest" near-term effect on the market share of regional carriers. This report by The Canadian Press was first published Aug. 6, 2025. Companies in this story: (TSX:T. TSX:BCE, TSX:RCI.B) Sammy Hudes, The Canadian Press Se produjo un error al recuperar la información Inicia sesión para acceder a tu portafolio Se produjo un error al recuperar la información Se produjo un error al recuperar la información Se produjo un error al recuperar la información Se produjo un error al recuperar la información

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