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ORVANA REPORTS Q3 FY2025 PRODUCTION AND EXPLORATION RESULTS FROM OROVALLE, SPAIN

ORVANA REPORTS Q3 FY2025 PRODUCTION AND EXPLORATION RESULTS FROM OROVALLE, SPAIN

TSX: ORV
TORONTO, July 16, 2025 /CNW/ – Orvana Minerals Corp. (TSX: ORV) (the 'Company' or 'Orvana') is pleased to report production and exploration updates for the third quarter of fiscal year 2025 ('Q3 FY2025) ending June 30, 2025 from Orovalle (Spain).
Juan Gavidia, CEO of Orvana, commented, 'We are pleased with the increased gold production levels during the third quarter. In addition, and in line with our plan, we have initiated preparatory and development activities at the Carlés mine, where skarn extraction is scheduled to begin in August. This will mark the start of a planned production ramp-up, with increasing tonnage from Carlés expected over the coming months'.
'Encouraging results have been obtained from the greenfield drilling program at Ortosa-Godán. Work continues with the aim of confirming a potential connection between the Godán mineralization and our Carlés deposit', he added.
Orovalle – Q3 FY2025 Production Results
The mill processed approximately 116,626 tonnes, 5% higher than the prior quarter.
8,536 gold ounces produced in Q3 FY2025, 26% higher than the previous quarter. Current production estimates are tracking moderately below the lower end of the guidance range of 37,000 to 41,000 ounces. The final production level will depend on the ramp-up pace of production at Carlés starting in August. Updated estimates will be released with the third quarter financials, expected mid-August 2025.
0.9 million copper pounds produced in Q3 FY2025, in line with the previous quarter. As of the end of the third quarter, copper production has already exceeded the higher end of the 2025 production guidance of 2,400 to 2,700 K lbs.
Q3 FY2025
Q2 FY2025
Q3 FY2024
YTD Q3 FY2025
FY 2025
Guidance
Ore milled (tonnes)
116,626
111,272
150,843
346,547
Gold equivalent (oz)(1)
10,008
8,416
13,078
28,118
Gold
Grade (g/t)
2.43
2.06
2.37
2.22
Recovery (%)
93.6
92.0
94.1
92.8
Production (oz)
8,536
6,792
10,832
22,960
37,000 – 41,000
Copper
Grade (%)
0.42
0.43
0.39
0.44
Recovery (%)
82.0
84.0
76.3
83.9
Production (K lbs)
886
885
986
2,839
2,400 – 2,700
Silver
Grade (g/t)
9.86
9.81
8.30
10.16
Recovery (%)
80.4
80.1
76.7
80.5
Production (oz)
29,752
28,129
30,872
91,187
(1) Gold Equivalent Ounces ('GEO') is a Non-GAAP Financial Performance Measure. For further information and detailed reconciliations, please see the 'Non-GAAP Financial Performance Measures' section of the Company's latest MD&A. GEO were calculated using the following average market prices:
Q3 FY2025: $3,279.16/oz Au, $33.64/oz Ag, $4.32/lb CuQ2 FY2025: $2,862.56/oz Au, $31.91/oz Ag, $4.24/lb CuQ3 FY2024: $2,337.99/oz Au, $28.86/oz Ag, $4.42/lb Cu
Orovalle – Q3 FY2025 Drilling Update
Drilled Meters
Infill
Brownfield
Greenfield
TOTAL
El Valle Boinás
Boinás East (BE)
1,561


1,561
Boinás South (SB)
1,192


1,192
Area 208 (A2)
103
123

226
Ortosa-Godán


575
575
TOTAL
2,856
123
575
3,554
El Valle Boinás
The Q3 FY2025 drilling program focused on skarn areas, aiming to convert inferred resources into measured and indicated resources. In Boinás East, 1,561 meters of drilling defined narrow skarn mineralization in the western part of the orebody, between levels 100 and 200, which will be incorporated into the mine plan. In Boinás South, 1,192 meters were drilled to complete mineral definition around stope designs and confirm orebody geometry. A minor drilling program was also carried out in Area 208 and will continue during the fourth quarter.
The drilling program in the fourth quarter of fiscal 2025 is focused on defining new resources in oxides areas and converting inferred resources in the same areas (mainly Area 208 and E2).
Ortosa-Godán
The Ortosa-Godan Project is located three kilometers northwest of our Carlés mine, within the same gold belt. The exploration program is currently focused on the Godán area, where FY2024 drilling proved mineralization at the contact between the intrusive and sedimentary rocks, with calcic skarn bands dipping 60-70° ESE over 200 meters of strike potential.
The FY2025 drilling program is currently underway, aiming to extend the definition of skarn mineralization at depth. Based on the interpreted dip of the formation, there is potential for the Godán mineralization to connect with the Carlés skarn system, and ongoing exploration is focused on testing this possibility.
Drill Hole
Comments
24GOD07
Drill hole targeted skarn mineralization at the intrusive–limestone contact. While the intrusive was intersected, no skarn was encountered.
25GOD08
Continuing with the objective of drill hole 24GOD07, this hole targeted skarn mineralization 200 meters deeper. A 10.8 m interval of calcic skarn was intersected, proving the skarn continuity down to level -400. No gold grades were detected.
25GO09
A fault was intersected at 375 m depth, preventing further drilling.
25GOD09R
The target of this drill hole is to evaluate the potential extension of the skarn 150 meters to the north. Drilling reached 575 meters by the end of June and is expected to be completed by the end of July.
Quality Control
Greenfield drill hole samples were sent to an external laboratory (ALS Laboratory) for analyses. Infill and brownfield drill holes samples were analyzed in Orovalle's Laboratory.
Sample preparation was carried out at the El Valle facility. All diamond core samples have been prepared using the following procedure, once split:
The core samples are dried at a temperature of 105°C and then crushed through a jaw crusher to 70%<6 mm. The coarse-crushed sample is further reduced to 70%<425 microns using an LM5 bowl-and-puck pulverizer. An Essa rotary splitter is used to take a 450 g to 550 g sub-sample of each split for pulverizing. The remaining reject portion is bagged and stored. The sample is reduced by 85% to a nominal -200 mesh using an LM2 bowl-and-puck pulverizer. 150 g sub-samples are split using a special vertical-sided scoop to cut channels through the sample which has been spread into a pancake on a sampling mat. Samples are then sent to the laboratory for gold and base metal analysis. Leftover pulp is bagged and stored.
After sample preparation, 30g samples are analyzed for Au by fire assay with an atomic absorption spectroscopy (AAS) finish and one-gram samples for Ag, As, Bi, Cu, Hg, Pb, Sb, Se, and Zn by ICP-optical emission spectroscopy (ICP-OES) after an aqua regia digestion.
For A208 core samples is used a 1000 g sub-sample of each split and 250 g sub-samples are split. 50 g samples are twice analyzed. In case of the twice analysis don´t match, a metalling screening method is used to confirm the grade.
In case of the samples sent to an external laboratory, 30 g samples are analyzed for Au by fire assay with an atomic absorption (Au AA-25) and 35 elements by ICP (ME-ICP41) after an aqua regia digestion. When Au and Ag values are >100 ppm and Cu and As values are >10,000 ppm, specific analysis methods are used to determinate the final grade.
The reported work has been completed using industry standard procedures, including a quality assurance/quality control ('QA/QC') program consisting of the insertion of certified reference material, blanks and duplicates samples into the sample stream.
The exploration update was prepared under the supervision of Guadalupe Collar Menéndez, a qualified person for the purposes of NI 43-101 and an employee of Orovalle Minerals S.L., a subsidiary of Orvana.
Consolidated Operational and Financial Performance:
Project updates for Bolivia and Argentina, and Q3 FY2025 consolidated operational and financial highlights will be released with the third quarter financials, expected mid-Aug, 2025.
ABOUT ORVANA – Orvana is a multi-mine gold-copper-silver company. Orvana's assets consist of the producing El Valle and Carlés gold-copper-silver mines in northern Spain, the Don Mario gold-silver property in Bolivia, and the Taguas property located in Argentina. Additional information is available at Orvana's website (www.orvana.com).
Cautionary Statements – Forward-Looking Information
Certain statements in this news release constitute forward-looking statements or forward-looking information within the meaning of applicable securities laws ('forward-looking statements'). Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, objectives, assumptions, potentials, future events or performance (often, but not always, using words or phrases such as 'believes', 'expects', 'plans', 'estimates' or 'intends' or stating that certain actions, events or results 'may', 'could', 'would', 'might', 'will', 'are projected to' or 'confident of' be taken or achieved) are not statements of historical fact, but are forward-looking statements.
The forward-looking statements herein relate to, among other things, Orvana's ability to achieve improvement in free cash flow; the ability to maintain expected mining rates and expected throughput rates at El Valle Plant; the potential to extend the mine life of El Valle and Don Mario beyond their current life-of-mine estimates including specifically, but not limited to, Orvana's ability to optimize its assets to deliver shareholder value; estimates of future production (including without limitation, production guidance), operating costs and capital expenditures; mineral resource and reserve estimates; statements and information regarding future feasibility studies and their results; future transactions; future metal prices; the ability to achieve additional growth and geographic diversification; and future financial performance, including the ability to increase cash flow and profits; future financing requirements; mine development plans; the possibility of the conversion of inferred mineral resources to mineral reserves.
Forward-looking statements are necessarily based upon a number of estimates and assumptions that, while considered reasonable by the Company as of the date of such statements, are inherently subject to significant business, economic and competitive uncertainties and contingencies, which includes, without limitation, as particularly set out in the notes accompanying the Company's most recently filed financial statements. The estimates and assumptions of the Company contained or incorporated by reference in this news release, which may prove to be incorrect, include, but are not limited to the various assumptions set forth herein and in Orvana's most recently filed Management's Discussion & Analysis and Annual Information Form in respect of the Company's most recently completed fiscal year (the 'Company Disclosures') or as otherwise expressly incorporated herein by reference as well as: there being no significant disruptions affecting operations, whether due to labour disruptions, supply disruptions, power disruptions, damage to equipment or otherwise; permitting, development, operations, expansion and acquisitions at El Valle, Don Mario and Taguas being consistent with the Company's current expectations; political developments in any jurisdiction in which the Company operates being consistent with its current expectations; certain price assumptions for gold, copper and silver; prices for key supplies being approximately consistent with current levels; production and cost of sales forecasts meeting expectations; the accuracy of the Company's current mineral reserve and mineral resource estimates; labour and materials costs increasing on a basis consistent with Orvana's current expectations; and the availability of necessary funds to execute the Company's plan. Without limiting the generality of the foregoing, this news release also contains certain 'forward-looking statements' within the meaning of applicable securities legislation, including, without limitation, references to the results of the Company's exploration activities, including but not limited to, drilling results and analyses, mineral resource estimation, conceptual mine plan and operations, internal rate of return, sensitivities, taxes, net present value, potential recoveries, design parameters, operating costs, capital costs, production data and economic potential; the timing and costs for production decisions; permitting timelines and requirements; exploration and planned exploration programs; and the Company's general objectives and strategies.
A variety of inherent risks, uncertainties and factors, many of which are beyond the Company's control, affect the operations, performance and results of the Company and its business, and could cause actual events or results to differ materially from estimated or anticipated events or results expressed or implied by forward looking statements. Some of these risks, uncertainties and factors include: the potential impact of global health and global economic conditions on the Company's business and operations, including: our ability to continue operations; and our ability to manage challenges presented by such conditions; the general economic, political and social impacts of the continuing conflict between Russia and Ukraine, our ability to support the sustainability of our business including through the development of crisis management plans, increasing stock levels for key supplies, monitoring of guidance from the medical community, and engagement with local communities and authorities; fluctuations in the price of gold, silver and copper; the need to recalculate estimates of resources based on actual production experience; the failure to achieve production estimates; variations in the grade of ore mined; variations in the cost of operations; the availability of qualified personnel; the Company's ability to obtain and maintain all necessary regulatory approvals and licenses; Orovalle's ability to complete the permitting process of the El Valle Tailings Storage Facility increasing the storage capacity; Orovalle's ability to complete the stabilization project of the legacy open pit wall; the Company's ability to use cyanide in its mining operations; risks generally associated with mineral exploration and development, including the Company's ability to continue to operate the El Valle and/or ability to resume operations at the Carlés Mine; the Company's ability to successfully implement an acid leaching circuit and ancillary facilities to process the current oxides stockpiles at Don Mario; the Company's ability to successfully carry out development plans at Taguas; sufficient funding to carry out exploration and development plans at Taguas and to process the oxides stockpiles at Don Mario; EMIPA's ability to finalize the OSP financial model and subsequently complete the required funding for the OSP; the Company's ability to acquire and develop mineral properties and to successfully integrate such acquisitions; the Company's ability to execute on its strategy; the Company's ability to obtain financing when required on terms that are acceptable to the Company; challenges to the Company's interests in its property and mineral rights; current, pending and proposed legislative or regulatory developments or changes in political, social or economic conditions in the countries in which the Company operates; general economic conditions worldwide; the challenges presented by global health conditions; fluctuating operational costs such as, but not limited to, power supply costs; current and future environmental matters; and the risks identified in the Company's disclosures. This list is not exhaustive of the factors that may affect any of the Company's forward-looking statements and reference should also be made to the Company's Disclosures for a description of additional risk factors.
Any forward-looking statements made herein with respect to the anticipated development and exploration of the Company's mineral projects are intended to provide an overview of management's expectations with respect to certain future activities of the Company and may not be appropriate for other purposes. Forward-looking statements are based on management's current plans, estimates, projections, beliefs and opinions and, except as required by law, the Company does not undertake any obligation to update forward-looking statements should assumptions related to these plans, estimates, projections, beliefs and opinions change. Readers are cautioned not to put undue reliance on forward-looking statements. The forward-looking statements made in this information are intended to provide an overview of management's expectations with respect to certain future operating activities of the Company and may not be appropriate for other purposes.
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Revenue in Africa and Europe grew by 47%, supported by the start of contracts that are significant for the region. Overall, rig utilization rate in Q2 2025 was 35% compared to 40% in Q2 2024. H1 2025 H1 2025 revenue totaled US$124.1 million, down from US$155 million in H1 2024. In Asia Pacific, the Company's first-largest revenue contributor, H1 2025 revenue amounted to US$45.0 million, marking the best first half ever with a 22% increase compared to H1 2024. This growth is primarily attributable to successful operations and the commissioning of new proprietary rigs. North America, the Company's second revenue contributor region, declined by 27%, The decrease was primarily due to the discontinuation of certain client programs and delays in starting new contracts. Revenue in South America totaled US$21.4 million in H1 2025, down 51% from US$43.8 million in H1 2024. In Chile and Argentina, the Company started new long-term contracts during the period, which are currently in the mobilization and learning curve phases, impacting both revenue and margins. In Brazil, the Company was impacted by disruption in the mobilization process due to client-driven delays. In the EMEA region, revenue slightly decreased by US$0.9 million compared to H1 2024. Excluding the exit from CIS and certain West African countries, the revenue increased by US$4.1 million (41%). Gross profit (In thousands of US$) – (unaudited) Q2 2025 % change Q2 2024 H1 2025 % change H1 2024 Reporting segment Mining 10,336 -33 % 15,396 14,376 -53 % 30,842 Water 3,790 50 % 2,520 7,479 92 % 3,886 Total gross profit / (loss) 14,126 -21 % 17,916 21,855 -37 % 34,728 Q2 2025 The Q2 2025 gross margin, including depreciation within cost of sales, was US$14.1 million (20.5% of revenue), or US$15.1 million (21.9% of revenue) when excluding one-off costs, compared to US$17.9 million (23.0% of revenue) in Q2 2024. The decline in the mining segment's gross margin was primarily due to the phasing and ramp-up of new contracts, which are typically associated with lower initial margins. In contrast, gross profit in the water segment was supported by the deployment of new proprietary rigs on long-term contracts. H1 2025 The H1 2025 gross margin including depreciation within cost of sales was US$21.9 million (or 17.6% of revenue) compared to US$34.7million (or 22.4% of revenue) in H1 2024. Selling, General and Administrative Expenses (In thousands of US$) – (unaudited) Q2 2025 % change Q2 2024 H1 2025 % change H1 2024 Selling, general and administrative expenses 4,726 -19 % 5,800 9,561 -21 % 12,099 Q2 2025 SG&A expenses were reduced by 19% versus the prior-year quarter. As a percentage of revenue, SG&A improved to 6.8% from 7.4% in Q2 2024. H1 2025 SG&A decreased 21% compared to last year. As a percentage of revenue, SG&A remained stable at approximately 7.8% of revenue. Operating result (In thousands of US$) – (unaudited) Q2 2025 % change Q2 2024 H1 2025 % change H1 2024 Reporting segment Mining 6,692 -35 % 10,234 6,887 -69 % 22,149 Water 2,997 59 % 1,882 5,696 120 % 2,591 Total operating profit / (loss) 9,689 -20 % 12,116 12,583 -49 % 24,740 Q2 2025 The operating profit was US$9.7 million compared to US$12.1 million in the same quarter last year. Foraco sold its 50% stake in its Kazakh subsidiary, Eastern Drilling Company LLP, generating a net gain of US$289 thousand, which was recorded under 'Other Operating Income' in the Company's consolidated financial statements for Q2 2025. H1 2025 The H1 2025 operating profit was US$12.6 million compared to US$24.7 million in H1 2024. Financial position The following table provides a summary of the Company's cash flows for H1 2025 and H1 2024: (In thousands of US$) H1 2025 H1 2024 Cash generated by operations before working capital requirements 21,032 33,964 Working capital requirements (7,893) (23,497) Income tax paid (7,565) (6,264) Purchase of equipment in cash (9,777) (9,978) Free Cash Flow before debt servicing (4,203) (5,775) Proceeds from / (repayment of) debt 2,894 1,796 Interests paid (2,877) (3,931) Acquisition of treasury shares (721) (556) Deconsolidation of EDC Russia & Kazakhstan Dividends paid to non-controlling interests (5) – (2,076) (330) Net cash generated / (used in) financing activities (709) (5,097) Net cash variation (4,912) (10,872) Foreign exchange differences 1,325 (1,458) Variation in cash and cash equivalents (3,588) (12,330) Cash and cash equivalents at the end of the period 20,775 21,959 In H1 2025, the cash generated from operations before working capital requirements amounted to US$21.0 million compared to US$33.9 million in H1 2024. During the same period, working capital requirements were US$7.9 million, a decrease compared to the same period last year, primarily driven by tightened control on working capital management and the reduction in activity. During the period, Capex totaled US$9.8 million in cash compared to US$10.0 million in H1 2024. Capex primarily relates to new rigs, and the acquisition of ancillary equipment and rods to support new contracts. Strategy The Company's strategy is to assist its customers in exploring or managing their deposits throughout the entire cycle, with a special focus on the life of mine activity. The Company intends to continue developing and growing its services across the world with a focus on stable jurisdictions, high tech drilling services, optimal commodities mix including battery metals and gold – with a significant presence in water related drilling services – and a gradual implementation of remote-controlled rigs and other advanced digital applications. The Company expects to execute its strategy primarily through organic growth and targeted acquisitions. The Company addressed the environmental, social and governance (ESG) requirements, and implemented a pragmatic and measurable approach to ESG with quantitative KPIs to maximize improvement and efficiencies. Currency exchange rates. The exchange rates for the periods under review are provided in the Management's Discussion and Analysis of Q2 2025. Non-IFRS measures EBITDA represents Net income before interest expense, income taxes, depreciation, amortization and non-cash share based compensation expenses. EBITDA is a non-IFRS quantitative measure used to assist in the assessment of the Company's ability to generate cash from its operations. The Company believes that the presentation of EBITDA is useful to investors because it is frequently used by securities analysts, investors and other interested parties in the evaluation of companies in the drilling industry. EBITDA is not defined in IFRS and should not be considered to be an alternative to Profit for the period or Operating profit or any other financial metric required by such accounting principles. Net debt corresponds to the current and non-current portions of borrowings and the consideration of payables related to acquisitions, net of cash and cash equivalents. The Company's lease obligations are included in the net debt calculation. Reconciliation of the EBITDA is as follows: (In thousands of US$) (unaudited) Q2 2025 Q2 2024 H1 2025 H1 2024 Operating profit / (loss) 9,689 12,116 12,583 24,740 Depreciation expense 4,154 4,173 8,137 9,020 Non-cash employee share-based compensation 162 102 312 204 EBITDA 14,005 16,391 21,031 33,964 Conference call and webcast On July 31, 2025, Company Management will conduct a conference call at 10:00 am Eastern Time to review the financial results. The call will be hosted by Tim Bremner, CEO, and Fabien Sevestre, CFO. You can join the call by dialing 1-888-836-8184 or 1-289-819-1350. You will be put on hold until the conference call begins. A live audio webcast of the Conference Call will also be available An archived replay of the webcast will be available for 90 days. About Foraco International SA Foraco International SA (TSX: FAR) is a leading global mineral drilling services company that provides a comprehensive and reliable service offering in mining and water projects. Supported by its founding values of integrity, innovation and involvement, Foraco has grown into the third largest global drilling enterprise with a presence in 16 countries across five continents. For more information about Foraco, visit 'Neither TSX Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Exchange) accepts responsibility for the adequacy or accuracy of this release.' Caution concerning forward-looking statements This document may contain 'forward-looking statements' and 'forward-looking information' within the meaning of applicable securities laws. These statements and information include estimates, forecasts, information and statements as to Management's expectations with respect to, among other things, the future financial or operating performance of the Company and capital and operating expenditures. Often, but not always, forward-looking statements and information can be identified by the use of words such as 'may', 'will', 'should', 'plans', 'expects', 'intends', 'anticipates', 'believes', 'budget', and 'scheduled' or the negative thereof or variations thereon or similar terminology. Forward-looking statements and information are necessarily based upon a number of estimates and assumptions that, while considered reasonable by Management, are inherently subject to significant business, economic and competitive uncertainties and contingencies. Readers are cautioned that any such forward-looking statements and information are not guarantees and there can be no assurance that such statements and information will prove to be accurate and actual results and future events could differ materially from those anticipated in such statements. Important factors that could cause actual results to differ materially from the Company's expectations are disclosed under the heading 'Risk Factors' in the Company's Annual Information Form dated March 2, 2025, which is filed with Canadian regulators on SEDAR ( The Company expressly disclaims any intention or obligation to update or revise any forward-looking statements and information whether as a result of new information, future events or otherwise. All written and oral forward-looking statements and information attributable to Foraco or persons acting on our behalf are expressly qualified in their entirety by the foregoing cautionary statements.

Kiwetinohk reports second quarter 2025 results, demonstrating continued operational strength and free funds flow generation, leading to positive revisions to annual guidance
Kiwetinohk reports second quarter 2025 results, demonstrating continued operational strength and free funds flow generation, leading to positive revisions to annual guidance

Malaysian Reserve

time30-07-2025

  • Malaysian Reserve

Kiwetinohk reports second quarter 2025 results, demonstrating continued operational strength and free funds flow generation, leading to positive revisions to annual guidance

CALGARY, AB, July 30, 2025 /CNW/ – Kiwetinohk Energy Corp. ('Kiwetinohk' or, the 'Company') (TSX: KEC) today reported its second quarter 2025 results and updated annual guidance. As companion documents to this news release, please review Kiwetinohk's management discussion and analysis (MD&A) and condensed consolidated interim financial statements for the second quarter of 2025 (available on or for additional details. Second quarter 2025 highlights include: Record production of 33,217 boe/d; low end of annual guidance raised by 1,000 boe/d. Operating costs of $6.02/boe; annual guidance lowered by $0.50/boe. Transportation expenses of $5.73/boe; annual guidance lowered by $0.25/boe. Upstream capital of $51.1 million; high end of annual guidance reduced by $10 million. Chicago gas sales priced at 164% premium to AECO for the six month period ending June 30, 2025; 23% toll reduction on Alliance effective Nov 1, 2025. Continued Montney outperformance confirms turbidite deposit overlying Simonette Duvernay with 69 high return locations mapped. New pacesetting drill and completion costs executed in Tony Creek Duvernay and Placid Montney. Adjusted funds flow from operations of $88.4 million, targeting a full-year 2025 range of $380 – $405 million at current strip pricing. Free free funds flow from operations of $37.2 million, targeting a full-year 2025 range of $80 – $110 million at current strip pricing. Restarted NCIB program. 'It has been a very strong first half of the year with the business performance at or ahead of budget on almost all fronts. Our Duvernay and Montney platform is delivering exciting results with strong production, lowering operating and capital costs, peer leading product realizations with critical contracted access to key markets and significant free funds flow generation. These results have supported our decision to begin buying Kiwetinohk shares as our debt reduction is ahead of schedule. We look forward to a more fulsome return of capital framework in the coming quarters,' said Pat Carlson, Chief Executive Officer. Kiwetinohk's previously announced launch of a formal business strategy review to evaluate a range of potential value enhancing opportunities with a focus on its upstream assets and an orderly exit from its power business continues with no developments to report at this time. Financial and operating results For the three months endedJune 30, For the six months ended June 30, 2025 2024 2025 2024 Production Oil & condensate (bbl/d) 10,462 7,598 10,546 8,025 NGLs (bbl/d) 4,477 3,817 4,458 3,922 Natural gas (Mcf/d) 109,667 89,259 107,472 89,859 Total (boe/d) 33,217 26,292 32,916 26,924 Oil and condensate % of production 32 % 29 % 32 % 30 % NGL % of production 13 % 15 % 14 % 15 % Natural gas % of production 55 % 56 % 54 % 55 % Realized prices Oil & condensate ($/bbl) 84.98 102.71 90.95 97.25 NGLs ($/bbl) 36.60 42.21 42.62 44.49 Natural gas ($/Mcf) 4.27 2.39 5.08 3.11 Total ($/boe) 45.79 43.91 51.50 45.86 Royalty expense ($/boe) (2.10) (3.96) (2.81) (3.78) Operating expenses ($/boe) (6.02) (6.17) (5.61) (6.61) Transportation expenses ($/boe) (5.73) (5.97) (5.44) (5.27) Operating netback ($/boe) 1 31.94 27.81 37.64 30.20 Realized gain (loss) on risk management ($/boe) 2 0.59 0.70 (0.44) 0.76 Realized gain (loss) on risk management – purchases ($/boe) 2 (0.28) 0.79 (0.73) 0.61 Net commodity sales from purchases ($/boe) 1 0.67 0.03 1.40 0.12 Adjusted operating netback ($/boe) 1 32.92 29.33 37.87 31.69 Financial results ($000s, except per share amounts) Commodity sales from production 138,419 105,049 306,811 224,711 Net commodity sales from purchases 1 2,033 87 8,360 597 Cash flow from operating activities 79,839 61,232 190,156 136,415 Adjusted funds flow from operations 1 88,378 60,637 204,260 135,661 Per share basic 2.02 1.39 4.66 3.11 Per share diluted 1.97 1.37 4.55 3.08 Net debt to trailing 12-month adjusted funds flow from operations 1 0.60 0.81 0.60 0.81 Free funds flow (deficiency) from operations (excluding acquisitions/dispositions) 1 37,150 (9,802) 66,656 (10,567) Net income (loss) 59,300 (26,538) 114,219 (15,446) Per share basic 1.35 (0.61) 2.61 (0.35) Per share diluted 1.32 (0.61) 2.55 (0.35) Capital expenditures prior to acquisitions (dispositions) 1 51,228 70,439 137,604 146,228 Net acquisitions (dispositions) — — (21,050) (21) Capital expenditures and net acquisitions (dispositions) 1 51,228 70,439 116,554 146,207 June 30, 2025 December 31, 2024 Balance sheet ($000s, except share amounts) Total assets 1,264,028 1,215,575 Long-term liabilities 353,325 388,452 Net debt 1 205,142 272,764 Adjusted working capital deficit 1 (2,089) (22,862) Weighted average shares outstanding Basic 43,823,351 43,690,640 Diluted 44,868,490 44,571,772 Shares outstanding end of period 43,879,190 43,781,748 1 – Non-GAAP and other financial measures that do not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other entities. See Non-GAAP and Other Financial Measures section herein. 2 – Realized gain (loss) on risk management contracts includes settlement of financial hedges on production and foreign exchange, with gain (loss) on contracts associated with purchases presented separately. Second Quarter Performance and Operational Updates Record quarterly production of 33,217 boe/d (55% natural gas and 45% condensate and NGLs) with three new Duvernay wells brought on stream. Kiwetinohk has increased the lower end of annual guidance to a range of 32.0 – 34.0 Mboe/d. Average peak 30-day production rates from new wells are summarized below: Pad On-stream # wells Natural gas +associated liquids (MMcf/d) Condensate (bbl/d) Averageproductionper well (boe/d) %Condensate 09-11 (Simonette) Dec/Jan1 3 Duvernay 7.5 1,600 2,850 56 % 14-29 (Simonette) Feb 2 Duvernay 6.8 1,100 2,230 49 % 14-29 (Simonette) Feb 1 Montney 7.3 700 1,920 36 % 09-33 (Simonette) May 3 Duvernay 2.1 970 1,320 73 % _____________________________________ 1 Two wells were brought on-stream in December 2024, with the third well on the pad brought on-stream in January 2025. Operating netback of $31.94/boe drove strong adjusted funds flow from operations of $88.4 million and demonstrated the value of Kiwetinohk's high-liquid content production and access to historically higher priced Chicago natural gas markets. During the first quarter of 2025, Kiwetinohk's market access generated a significant premium to Alberta-based AECO benchmark pricing, realizing an average of $4.27/Mcf on its natural gas production during the quarter. Operating expenses of $6.02/boe continue to outperform expectations, highlighting exceptional asset execution and the value gained from Kiwetinohk's owned and operated infrastructure. Kiwetinohk has reduced full-year operating cost guidance range to $6.25 – $6.75/boe. Generated $37.2 million in free funds flow after capital expenditures (prior to acquisitions/dispositions) of $51.2 million, bringing 2025 first-half free funds flow to a total of $66.7 million. Reduced net debt by $67.6 million from year end 2024 levels, exiting the second quarter of 2025 with a net debt to trailing 12-month adjusted funds flow from operations ratio of 0.60x. Production growth and reliability was driven by a number of factors: Continued success in the Simonette Montney delineation program, with the first turbidite well delivering flat production over its first 10 months. The second turbidite well, brought on-stream in the first quarter of 2025, has similar inflow characteristics and is expected to provide stable volumes through its first year of production. These well results, in combination with updated mapping, have validated a lower turbidite target in the region. Kiwetinohk has identified 69 locations in the turbidite and expects this new inventory to compete for capital against its existing development plans. In Placid, the third-party party K3 facility's planned turnaround was extended and has further constrained our base volumes into the third quarter of 2025. The 1-18 Placid Montney development pad was recently completed and included three development wells. The first two wells are expected to be on-stream by early September when the K3 turnaround is completed. The third well encountered a leak in a tool string component and will require remediation at a later date. This well remains as drilled and uncompleted at this time. Neither of these delays in Placid will have an impact on annualized production guidance due to strong performance across the remainder of the asset base and the development portfolio. Additional development, including the recent 9-33 Tony Creek Duvernay development pad, remains on-track for the year. Lower drill and completion ('D&C') cost execution in Placid and Tony Creek. In Tony Creek, the 9-33 Duvernay pad's D&C cost averaged $13.7 million, approximately 12% lower than its 2024 activity on a length normalized basis. In Placid, the two fully completed Montney wells have a forecasted average D&C cost of $9.6 million, approximately 25% lower than the last area activity in 2023. These improved well costs support the company's decision to lower the upper end of its capital guidance range. Pembina Pipeline reaches settlement with shippers on Alliance Pipeline: Greater cost certainty resulting from the recently announced settlement reached with shippers on the Alliance Pipeline. To capture the maximum benefit, the Company anticipates extending its commitment for the Canadian portion of the pipeline effective November 1, 2025, with the expectation of aligning the term already committed to on the U.S. portion of the pipeline, pending the review and approval of the settlement by the Canadian Energy Regulator. Settlement benefits on the Canadian portion of the pipeline include: toll reduction of $0.11/mcf based on extending our contract to a 10-year term; one time refund for recoverable cost variance of approximately $8 million, based on internal estimates and Kiwetinohk's proportionate capacity. Payment anticipated around March 31, 2026; and, sharing of revenue from biddable transportation services (seasonal and interruptible) for volumes above long-term firm capacity of 1,325 MMcf/d. Combined with the previously announced reduction in the U.S. tolls, effective November 1, 2025, the new Alliance toll will be $0.98/mcf based an exchange rate of 0.73 USD/CAD, before any contribution from revenue sharing. Continued success in the Simonette Montney delineation program, with the first turbidite well delivering flat production over its first 10 months. The second turbidite well, brought on-stream in the first quarter of 2025, has similar inflow characteristics and is expected to provide stable volumes through its first year of production. These well results, in combination with updated mapping, have validated a lower turbidite target in the region. Kiwetinohk has identified 69 locations in the turbidite and expects this new inventory to compete for capital against its existing development plans. In Placid, the third-party party K3 facility's planned turnaround was extended and has further constrained our base volumes into the third quarter of 2025. The 1-18 Placid Montney development pad was recently completed and included three development wells. The first two wells are expected to be on-stream by early September when the K3 turnaround is completed. The third well encountered a leak in a tool string component and will require remediation at a later date. This well remains as drilled and uncompleted at this time. Neither of these delays in Placid will have an impact on annualized production guidance due to strong performance across the remainder of the asset base and the development portfolio. Additional development, including the recent 9-33 Tony Creek Duvernay development pad, remains on-track for the year. Greater cost certainty resulting from the recently announced settlement reached with shippers on the Alliance Pipeline. To capture the maximum benefit, the Company anticipates extending its commitment for the Canadian portion of the pipeline effective November 1, 2025, with the expectation of aligning the term already committed to on the U.S. portion of the pipeline, pending the review and approval of the settlement by the Canadian Energy Regulator. Settlement benefits on the Canadian portion of the pipeline include: toll reduction of $0.11/mcf based on extending our contract to a 10-year term; one time refund for recoverable cost variance of approximately $8 million, based on internal estimates and Kiwetinohk's proportionate capacity. Payment anticipated around March 31, 2026; and, sharing of revenue from biddable transportation services (seasonal and interruptible) for volumes above long-term firm capacity of 1,325 MMcf/d. Combined with the previously announced reduction in the U.S. tolls, effective November 1, 2025, the new Alliance toll will be $0.98/mcf based an exchange rate of 0.73 USD/CAD, before any contribution from revenue sharing. toll reduction of $0.11/mcf based on extending our contract to a 10-year term; one time refund for recoverable cost variance of approximately $8 million, based on internal estimates and Kiwetinohk's proportionate capacity. Payment anticipated around March 31, 2026; and, sharing of revenue from biddable transportation services (seasonal and interruptible) for volumes above long-term firm capacity of 1,325 MMcf/d. Guidance update Following robust operational and financial results in the first half of 2025, Kiwetinohk has made the following positive revisions to its annual guidance: The low-end of the annual production guidance range has been increased to account for a strong first half of the year and the confidence we have in our remaining development program. The projected royalty rate has been decreased, in response to lower commodity prices than initially budgeted, particularly AECO natural gas prices. Kiwetinohk continues to benefit from higher Chicago pricing, while natural gas royalties are determined with reference to AECO. Projected operating expenses have been decreased, reflecting strong operational performance and continued asset reliability. Projected transportation expenses have been decreased, supported by lower costs to transport Placid NGLs in the second quarter of 2025 and an expected reduction in Alliance tolls effective November 2025. The high-end of the annual upstream capital guidance range has been decreased, driven by efficient drilling and completion execution and improved cost certainty. Updated guidance is summarized in the table below. These updates reflect actual year-to-date realized commodity pricing, Kiwetinohk's hedging program and estimated forward strip pricing. 2025 Financial & Operational Guidance Current July 30, 2025 Previous May 6, 2025 8 Production (2025 average) Mboe/d 32.0 – 34.0 31.0 – 34.0 Oil & liquids % 45% – 49% Natural gas 1 % 51% – 55% Financial Royalty rate % 5% – 7% 6% – 8% Operating costs $/boe $6.25 – $6.75 $6.75 – $7.25 Transportation $/boe $5.50 – $5.75 $5.75 – $6.00 Corporate G&A expense 2 $/boe $1.95 – $2.15 Cash taxes 3 $MM $— Upstream Capital 4 $MM $290 – $305 $290 – $315 DCET 5 $MM $270 – $285 $270 – $290 Plant expansion, production maintenance and other $MM $20 $20 – $25 2025 Guidance Sensitivities Current July 30, 2025 2025 Adjusted Funds Flow from Operations commodity pricing 4, 6 Strip (July 28) US$66/bbl WTI & US$3.36/MMBtu HH $MM $380 – $405 US$60/bbl WTI & US$3.50/MMBtu HH & $0.73 USD/CAD $MM $365 – $395 US$70/bbl WTI & US$4.50/MMBtu HH & $0.73 USD/CAD $MM $405 – $435 US$ WTI +/- $1.00/bbl 7 $MM +/- $2.0 US$ Chicago +/- $0.10/MMBtu 7 $MM +/- $2.1 CAD$ AECO 5A +/- $0.10/GJ 7 $MM +/- $0.1 Exchange Rate (USD/CAD) +/- $0.01 7 $MM +/- $1.8 2025 Net debt to Adjusted Funds Flow from Operations 4, 6 Strip (July 28) US$66/bbl WTI & US$3.36/MMBtu HH X 0.4x – 0.5x US$60/bbl WTI & US$3.50/MMBtu HH & $0.73 USD/CAD X 0.5x – 0.6x US$70/bbl WTI & US$4.50/MMBtu HH & $0.73 USD/CAD X 0.4x – 0.5x 1 – ~90% is expected to be sold into the Chicago market in 2025. 2 – Includes G&A expenses for all divisions of Kiwetinohk – corporate, upstream, power and business development. 3 – Kiwetinohk expects to pay immaterial cash taxes on its U.S. subsidiary annually. No Canadian taxes are anticipated in 2025. 4 – Non-GAAP and other financial measures that do not have any standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other entities. Please refer to the section 'Non-GAAP Measures' herein. 5 – Approximately 5% of DCET relates to technology initiatives aimed at reducing per well capital costs and optimizing well design for improved productivity. 6 – Previously disclosed sensitivities utilized pricing levels prevailing at the time and have been revised to reflect current market data. As the previously disclosed sensitivities are no longer based on current information, they have been withdrawn. 7 – Assumes US$65/bbl WTI, US$4.00/mmbtu HH, US$2.50/mmbtu HH – AECO basis diff, 0.725 USD/CAD. 8 – Previously presented financial and operational guidance is shown only for balances that have been revised. While U.S. trade policy changes may affect economic conditions, their impact on Kiwetinohk remains uncertain. Kiwetinohk's natural gas exports to the United States are CUSMA-compliant and currently exempt from tariffs. Given ongoing uncertainty, no tariff impacts are included in revised guidance. If future tariffs affect operations, guidance will be updated. A detailed breakdown of current full-year guidance can also be found in the MD&A for this quarter available on SEDAR+ at The revised sensitivities incorporate updated information relevant to expectations for financial and operational results. This corporate guidance is based on commodity price assumptions and economic conditions and readers are cautioned that guidance estimates may fluctuate and are subject to numerous risks and uncertainties. Kiwetinohk will update guidance if and as required throughout the year. Conference call and third quarter 2025 reporting date Kiwetinohk management will host a conference call on July 31, 2025, at 8:00 AM MT (10:00 AM ET) to discuss results and answer questions. Participants can listen to the conference call by dialing 1-888-510-2154 (North America toll free) or 437-900-0527 (Toronto and area). A replay of the call will be available until August 7, 2025, at 1-888-660-6345 (North America toll free) or 646-517-4150 (Toronto and area) by using the code 92805. Kiwetinohk plans to release its results for the third quarter of 2025 after the close of trading on the TSX on November 5, 2025. About Kiwetinohk Kiwetinohk produces natural gas, natural gas liquids, oil and condensate from profitable early to mid-life liquids-rich natural gas properties focused in the Montney and Duvernay formations in Alberta, Canada. Kiwetinohk's common shares trade on the Toronto Stock Exchange under the symbol KEC. Additional details are available within the year-end documents available on Kiwetinohk's website at and SEDAR+ at Oil and gas advisories For the purpose of calculating unit costs, natural gas is converted to a barrel of oil equivalent using six thousand cubic feet of natural gas equal to one barrel of oil unless otherwise stated. The term barrel of oil equivalent (boe) may be misleading, particularly if used in isolation. A boe conversion ratio for gas of 6 Mcf:1 boe is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from an energy equivalency of 6:1, utilizing a conversion ratio of 6:1 may be misleading as an indication of value. This news release includes references to sales volumes of 'crude oil', 'oil and condensate', 'NGLs' and 'natural gas' and revenues therefrom. National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities, includes condensate within the NGLs product type. Kiwetinohk has disclosed condensate as combined with crude oil and separately from other NGLs since the price of condensate as compared to other NGLs is currently significantly higher, and Kiwetinohk believes that this crude oil and condensate presentation provides a more accurate description of its operations and results therefrom. Crude oil therefore refers to light oil, medium oil, tight oil, and condensate. Notwithstanding the foregoing, the Company's amount of crude oil that constitutes light oil, medium oil and tight oil is immaterial, and the majority of KEC's crude oil is comprised of condensate. NGLs refers to ethane, propane, butane, and pentane combined. Natural gas refers to conventional natural gas and shale gas combined. References to '30-day 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 therefore not indicative of long term performance or recovery. Investors are encouraged not to place reliance on such rates when assessing Kiwetinohk's aggregate production. Forward looking information Certain information set forth in this news release contains forward-looking information and statements including, without limitation, management's business strategy, management's assessment of future plans and operations. Such forward-looking statements or information are provided for the purpose of providing information about management's current expectations and plans relating to the future. Forward-looking statements or information typically contain statements with words such as 'anticipate', 'believe', 'expect', 'plan', 'estimate', 'project', 'potential', 'may', 'will' or similar words suggesting future outcomes or statements regarding future performance and outlook. Readers are cautioned that assumptions used in the preparation of such information may prove to be incorrect. Events or circumstances may cause actual results to differ materially from those predicted as a result of numerous known and unknown risks, uncertainties and other factors, many of which are beyond the control of Kiwetinohk. In particular, this news release contains forward-looking statements pertaining to the following: expectations of achieving 2025 budget objectives of optimizing multi-year growth, unlocking the free funds flow potential of our asset, enhancing operational flexibility, and divesting the power development portfolio; expectations regarding Kiwetinohk's formal business strategy review and the associated timelines to complete the process; drilling and completion activities on certain wells and pads and the expected timing for certain pads to be brought on-stream; Kiwetinohk's revised 2025 financial and operational guidance and adjustments to the previously communicated 2025 guidance, including revised annual production range, reduced royalty rate, reduced operating costs, decreased transportation expenses, revised upstream capital spend range, and revised operations sensitivities; Kiwetinohk's ability to continue to access the Chicago market; the timing and amount of cash taxes for the Company's US subsidiary and Kiwetinohk's expectations regarding being taxable in Canada and the timing thereof; Kiwetinohk's ability to use technology to reduce well capital costs, optimize well design and improve productivity; expectations of continued premiums in the Chicago natural gas benchmark pricing when compared to Alberta markets; estimated impact of United States import tariffs; Kiwetinohk's operational and financial strategies and plans; Kiwetinohk's business strategies, objectives, focuses and goals and expected or targeted performance and results; the ability to generate free funds flows and reduce debt levels in the future; and the timing of the release of Kiwetinohk's third quarter of 2025 results. Statements relating to reserves are also deemed to be forward looking information, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described exist in the quantities predicted or estimated and that the reserves can be profitably produced in the future. In addition to other factors and assumptions that may be identified in this news release, assumptions have been made regarding, among other things: the expectation of ~90% of natural gas sales being directed to the Chicago market during 2025 Kiwetinohk's ability to execute on its revised 2025 budget priorities; the timing and costs of Kiwetinohk's capital projects, including drilling and completion of certain wells; the impact of the federal government's draft clean electricity regulations on the portfolio and uncertainties regarding same; the impact of the provincial government's restructured energy market on the portfolio and uncertainties regarding same; Kiwetinohk's ability to exit the power business and negotiate deal structures and terms on Kiwetinohk's power projects; the impact of increasing competition; the general stability of the economic and political environment in which Kiwetinohk operates; general business, economic and market conditions; the ability of Kiwetinohk to obtain qualified staff, equipment and services in a timely and cost efficient manner; future commodity and power prices; currency, royalty, exchange and interest rates; near and long-term impacts of tariffs or other changes in trade policies in North America, as well as globally; the regulatory framework regarding royalties, taxes, power, renewable and environmental matters in the jurisdictions in which Kiwetinohk operates; the ability of Kiwetinohk to obtain the required capital to finance its exploration, development and other operations and meet its commitments and financial obligations; the ability of Kiwetinohk to secure adequate product processing, transportation, fractionation and storage capacity on acceptable terms and the capacity and reliability of facilities; the impact of war, hostilities, civil insurrection, pandemics, instability and political and economic conditions (including the ongoing Russian-Ukrainian conflict and conflict in the Middle East) on the Company; the ability of Kiwetinohk to successfully market its products; the ability to fund power projects through third parties; expectations regarding access of oil and gas leases in light of caribou range planning; and Kiwetinohk's operational success and results being consistent with current expectations. Readers are cautioned that the foregoing list is not exhaustive of all factors and assumptions that have been used. Although Kiwetinohk believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements as Kiwetinohk can give no assurance that such expectations will prove to be correct. Forward-looking statements or information involve a number of risks and uncertainties that could cause actual results to differ materially from those anticipated by Kiwetinohk and described in the forward-looking statements or information. These risks and uncertainties include, among other things: those risks set out in the Annual Information Form (AIF) under 'Risk Factors'; the ability of management to execute its business plan; general economic and business conditions; the ability of Kiwetinohk to proceed with the power generation projects as described, or at all; global economic, financial and political conditions, including the results of ongoing trade negotiations in North America, as well as globally; risks of war, hostilities, civil insurrection, pandemics, instability and political and economic conditions (including the ongoing Russian-Ukrainian conflict and conflict in the Middle East) in or affecting jurisdictions in which Kiwetinohk operates; the risks of the power and renewable industries; operational and construction risks associated with certain projects; the possibility that government policies or laws may change or governmental approvals may be delayed or withheld; risks relating to regulatory approvals and financing; the ability to market in Alberta for power projects; uncertainty involving the forces that power certain renewable projects; Kiwetinohk's ability to enter into or renew leases; potential delays or changes in plans with respect to power and solar projects or capital expenditures; risks associated with rising capital costs and timing of project completion; fluctuations in commodity and power prices, foreign currency exchange rates and interest rates; risks inherent in the Company's marketing operations, including credit risk; health, safety, environmental and construction risks; risks associated with existing and potential future lawsuits and regulatory actions against Kiwetinohk; uncertainties as to the availability and cost of financing; the ability to secure adequate processing, transportation, fractionation and storage capacity on acceptable terms; processing, pipeline and fractionation infrastructure outages, disruptions and constraints; financial risks affecting the value of Kiwetinohk's investments; risks related to the interpretation of, and/or potential claims made pursuant to, the Government of Canada amendments to the deceptive marketing practices provisions of the Competition Act (Canada) regarding greenwashing; and other risks and uncertainties described elsewhere in this document and in Kiwetinohk's other filings with Canadian securities authorities. Readers are cautioned that the foregoing list is not exhaustive of all possible risks and uncertainties. The forward-looking statements and information contained in this news release speak only as of the date of this news release and Kiwetinohk's undertakes no obligation to publicly update or revise any forward-looking statements or information, except as expressly required by applicable securities laws. Non-GAAP and other financial measures This news release uses various specified financial measures including 'non-GAAP financial measures', 'non-GAAP financial ratios', 'capital management measures' and 'supplementary financial measures', in each case, as defined in National Instrument 52-112 Non-GAAP and Other Financial Measures Disclosure and explained in further detail below. The non-GAAP and other financial measures presented in this news release should not be considered in isolation or as a substitute for performance measures prepared in accordance with IFRS and should be read in conjunction with the Financial Statements and MD&A. Readers are cautioned that these non-GAAP measures do not have any standardized meanings and should not be used to make comparisons between Kiwetinohk and other companies without also taking into account any differences in the method by which the calculations are prepared. Please refer to Kiwetinohk's MD&A as at and for the three and six months ended June 30, 2025, under the section 'Non-GAAP and other financial measures' for a description of these measures, the reason for their use and a reconciliation to their closest GAAP measure where applicable. Kiwetinohk's MD&A is available on Kiwetinohk's website at or its SEDAR+ profile at Non-GAAP Financial Measures Capital expenditures, capital expenditures and net acquisitions (dispositions), operating netback, adjusted operating netback, and net commodity sales from purchases (loss), are measures that are not standardized measures under IFRS and might not be comparable to similar financial measures presented by other companies. The most directly comparable GAAP measure to capital expenditures and capital expenditures and net acquisitions (dispositions) is cash flow used in investing activities. The most directly comparable GAAP measure to operating netback and adjusted operating netback is commodity sales from production. The most directly comparable GAAP measure to net commodity sales from purchases (loss) is commodity sales from purchases. Non-GAAP Financial Ratios Operating netback per boe and adjusted operating netback per boe are calculated as operating netback and adjusted operating netback, respectively, divided by total production for the period as measured by boe. Capital Management Measures Adjusted funds flow from operations, free funds flow (deficiency) from operations, adjusted working capital surplus (deficit), net debt, net debt to annualized adjusted funds flow from operations and net debt to adjusted funds flow from operations are capital management measures that may not be comparable to similar financial measures presented by other companies. These measures may include calculations that utilize non-GAAP financial measures and should not be considered in isolation or construed as alternatives to their most directly comparable measure disclosed in Kiwetinohk's primary financial statements or other measures of financial performance calculated in accordance with IFRS. Supplementary Financial Measures This news release contains supplementary financial measures expressed as: (i) cash flow from operating activities, adjusted funds flow on a per share – basic and per share – diluted basis, (ii) realized prices, petroleum and natural gas sales, adjusted funds flow, revenue, royalties, operating expenses, transportation, realized loss on risk management, and net commodity sales from purchases on a $/bbl, $/Mcf or $/boe basis and (iii) royalty rate. Cash flow from operating activities, adjusted funds flow and free cash flow on a per share – basic and diluted basis are calculated by dividing the cash flow from operating activities, adjusted funds flow or free cash flow, as applicable, over the referenced period by the weighted average basic or diluted shares outstanding during the period determined under IFRS. Metrics presented on a $/bbl, $/Mcf or $/boe basis are calculated by dividing the respective measure, as applicable, over the referenced period by the aggregate applicable units of production (bbl, Mcf or boe) during such period. Royalty rate is calculated by dividing royalties by petroleum and natural gas sales less royalty and other revenue. Future oriented financial information Financial outlook and future-oriented financial information referenced in this news release about prospective financial performance, financial position or cash flows is based on assumptions about future events, including economic conditions and proposed courses of action, based on management's assessment of the relevant information currently available. These projections contain forward-looking statements and are based on a number of material assumptions and factors set out above and are provided to give the reader a better understanding of the potential future performance of Kiwetinohk in certain areas. Actual results may differ significantly from the projections presented herein. These projections may also be considered to contain future oriented financial information or a financial outlook. The actual results of Kiwetinohk's operations for any period will likely vary from the amounts set forth in these projections, and such variations may be material. See 'Risk Factors' in Kiwetinohk's AIF published on Kiwetinohk's profile on SEDAR+ at for a further discussion of the risks that could cause actual results to vary. The future oriented financial information and financial outlooks contained in this news release have been approved by management as of the date of this news release. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein. Abbreviations $/bbl dollars per barrel $/boe dollars per barrel equivalent $/Mcf dollars per thousand cubic feet AIF Annual Information Form bbl/d barrels per day boe barrel of oil equivalent, including crude oil, condensate, natural gas liquids, and natural gas (converted on the basis of one boe per six Mcf of natural gas) CUSMA Canada-United States-Mexico Agreement Mboe thousand barrels of oil equivalent boe/d barrel of oil equivalent per day D&C Drill and completion DCET Drill, Complete, Equip and Tie-in Mcf thousand cubic feet Mcf/d thousand cubic standard feet per day MD&A Management Discussion & Analysis MMcf/d million cubic feet per day NGLs natural gas liquids, which includes butane, propane, and ethane RCV recoverable variance For more information on Kiwetinohk, please contact: Investor Relations email: IR@ phone: (587) 392-4395 Pat Carlson, Chief Executive Officer Jakub Brogowski, Chief Financial Officer

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