International Petroleum Corporation (IPC or the Corporation) (TSX, Nasdaq Stockholm: IPCO) today released its financial and operational results and related management’s discussion and analysis (MD&A) for the three and six months ended June 30, 2026. IPC also released its annual Sustainability Report detailing IPC’s sustainability approach and initiatives.

William Lundin, IPC's President and Chief Executive Officer, comments: “We were very pleased to announce in the second quarter that first oil was achieved in May 2026 at the transformational Blackrod Phase 1 development in Canada, ahead of schedule and on budget. The Phase 1 project production continues to progressively ramp up with the forecast plateau production rate of 30,000 barrels of oil per day (bopd) expected to be achieved by late 2027, a quarter earlier than originally guided at the time of project sanction. Throughout the rest of the business, IPC maintained strong operational and financial performance, as the second quarter saw substantial increases in average international commodity prices. In response to these improved commodity prices, IPC increased our capital expenditure program to add incremental short-cycle investment opportunities at our producing assets.”

Q2 2026 Business Highlights

Average net production of approximately 42,200 barrels of oil equivalent per day (boepd) for the second quarter of 2026, in line with guidance for the period (53% heavy crude oil, 13% light and medium crude oil and 34% natural gas).⁽¹⁾
Blackrod Phase 1 first oil achieved in May 2026, ahead of schedule and on budget.
Following the increase in commodity prices, oil drilling in France commenced in the second quarter, with the first well online and delivering initial results ahead of expectations.

Q2 2026 Financial Highlights

Operating costs per boe of USD 19.1 for Q2 2026, in line with guidance.⁽³⁾
Operating cash flow (OCF) generation of MUSD 67 for Q2 2026.⁽³⁾
Capital and decommissioning expenditures of MUSD 49 for Q2 2026, in line with guidance.
Free cash flow (FCF) generation for Q2 2026 amounted to MUSD 4.⁽³⁾
Net result of MUSD 10 for Q2 2026.
Increased the Canadian revolving credit facility to MCAD 348.5 (approximately MUSD 250), and extended the maturity to May 2028.

Reserves and Resources

Total 2P reserves as at December 31, 2025 of 521 MMboe, with a reserve life index (RLI) of 31 years.⁽¹⁾⁽²⁾
Contingent resources (best estimate, unrisked) as at December 31, 2025 of 1,224 MMboe.⁽¹⁾⁽²⁾

2026 Annual Guidance

Full year 2026 average net production guidance range maintained at 44,000 to 47,000 boepd.⁽¹⁾
Full year 2026 operating costs guidance range maintained at USD 18 to 20 per boe.⁽³⁾
Full year 2026 OCF revised guidance estimated at between MUSD 230 and 330 (assuming Brent USD 70 to 90 per barrel for the remainder of 2026) from previous guidance of between MUSD 220 and 340 (assuming Brent USD 70 to 90 per barrel).⁽³⁾⁽⁴⁾
Full year 2026 capital and decommissioning expenditures guidance forecast maintained at MUSD 163.
Full year 2026 FCF revised guidance estimated at between MUSD 10 and 110 (assuming Brent USD 70 to 90 per barrel for the remainder of 2026) from previous guidance of between MUSD 0 and 120 (assuming Brent USD 70 to 90 per barrel).⁽³⁾⁽⁴⁾

	Three months ended June 30		Six months ended June 30
USD Thousands	2026	2025	2026	2025
Revenue	185,738	158,892	358,748	337,384
Gross profit	38,094	23,663	75,269	67,812
Net result	9,917	13,850	22,679	30,081
Operating cash flow ⁽³⁾	66,518	54,873	134,253	129,663
Free cash flow ⁽³⁾	3,895	(58,252)	(13,191)	(101,424)
EBITDA ⁽³⁾	63,856	51,519	128,145	122,465
Net cash/(debt) ⁽³⁾	(508,999)	(374,977)	(508,999)	(374,977)

Oil prices continued to strengthen through the second quarter of 2026 due to the on-going geopolitical tensions and constrained product flows through the Strait of Hormuz. Market volatility remains high in anticipation of a lasting ceasefire and resolution of the conflict in Iran ahead of the US mid-term elections. The International Energy Agency member countries’ strategic reserves release (SPR) is progressing as planned to combat the unprecedented supply disruption, with nearly 75% of the targeted 400 million barrel release complete. In addition to the global storage release, China has reduced petroleum imports by one-third, or by approximately 4 million barrels per day, with reduced refinery runs. Market commentators question how long these reduced runs can be sustained. In combination with depleting spare capacity, the physical backdrop for the crude market remains tight and supported by the enhanced importance of energy security. As at the end of the second quarter, IPC’s West Texas Intermediate (WTI) and Brent hedges have rolled off, and IPC is now fully exposed to these benchmark oil prices for the second half of 2026 and onward.

The second quarter 2026 WTI to Western Canadian Select (WCS) price differential averaged approximately USD 15 per barrel. The differential remains sensitive to refinery demand for heavy crude on the US Gulf Coast and the availability of competing heavy crude supplies, which also is partially impacted in the short term by US SPR releases. IPC is well-positioned to mitigate the partial differential increase with 2026 full year WTI to WCS differential hedges for 5,000 barrels per day at USD -12.50 per barrel. In addition, IPC has hedged from July 2026 to December 2027, 5,000 barrels per day and from January 2027 to December 2027, a further 5,000 barrels per day of the differential between the WCS price in Hardisty, Canada and the WCS price in Houston, USA, effectively hedging the transportation cost between the locations, at USD -7.55 per barrel and USD -7.50 per barrel, respectively. In addition, 2,000 barrels per day of quality differential between the WCS in Houston and the WTI are hedged from July to December 2026 at USD -3.65 per barrel.

The average Canadian gas benchmark price, AECO, was CAD 1.61 per Mcf for the second quarter of 2026, with Western Canadian Sedimentary Basin (WCSB) natural gas inventory levels remaining above historical averages. Market sentiment improved during the quarter as LNG Canada ramped up and Alberta data centre plans were announced which should increase regional demand and provide support for Canadian gas prices in the future. IPC has implemented hedges for 15,000 GJ (approximately 14,500 Mcf) per day at CAD 2.73 per GJ (approximately CAD 2.84 per Mcf) for 2026 from April to October 2026.

Second Quarter 2026 Highlights and Full Year 2026 Guidance

During the second quarter of 2026, IPC’s portfolio delivered average net production of 42,200 boepd, in line with the guidance for the quarter. Operational performance from the producing assets was strong as high facility and well uptimes were achieved. IPC maintains the full year 2026 average net production guidance range of 44,000 to 47,000 boepd.⁽¹⁾

IPC’s operating costs per boe for the second quarter of 2026 were USD 19.1, in line with guidance. Full year 2026 operating expenditure guidance of USD 18.0 to 20.0 per boe remains unchanged.⁽³⁾

Operating cash flow (OCF) generation for the second quarter of 2026 was USD 67 million. Full year 2026 OCF guidance is tightened to USD 230 to 330 million (assuming Brent USD 70 to 90 per barrel for the remainder of 2026).⁽³⁾⁽⁴⁾

Capital and decommissioning expenditure for the second quarter of 2026 was USD 49 million in line with guidance. Full year 2026 capital and decommissioning expenditure is maintained at USD 163 million.

Free cash flow (FCF) generation was USD 4 million during the second quarter of 2026. Full year 2026 FCF guidance is tightened to USD 10 to 110 million (assuming Brent USD 70 to 90 per barrel for the remainder of 2026).⁽³⁾⁽⁴⁾

As at June 30, 2026, IPC’s net debt position was USD 509 million, from a net debt position of USD 513 million as at March 31, 2026.

As previously announced, in April 2026, IPC increased the facility size of its Canadian credit facility to CAD 348.5 million (approximately USD 250 million) and extended the maturity of the facility to May 2028. IPC also previously announced the 2025 refinancing of its USD 450 million of unsecured bonds, with maturity in October 2030. This strong liquidity position, combined with the better than forecast cash flow generation to date and forecast for 2026, supports IPC in following through on its key strategic objectives to maximize stakeholder value.

IPC maintains the ability to repurchase up to approximately 6.5 million common shares up to early December 2026 under the renewed normal course issuer bid (NCIB) announced in Q4 2025. IPC has not purchased any common shares under the 2025/2026 NCIB to date. As at June 30, 2026 and August 4, 2026, IPC had a total of 112,826,752 common shares issued and outstanding and IPC held no common shares in treasury.

Blackrod

The Blackrod asset is 100% owned by IPC and hosts the largest booked reserves and contingent resources within the IPC portfolio. After more than a decade of pilot operations, subsurface delineation and commercial engineering studies, IPC sanctioned the Phase 1 steam-assisted gravity drainage (SAGD) development in the first quarter of 2023. The Phase 1 development targets 311 MMboe of 2P reserves. As previously announced, first oil at the Blackrod Phase 1 project was achieved at the end of May 2026, ahead of schedule and on budget. The production ramp up continues in Q3 2026 and is expected to build inventories at the central processing facility (CPF) and at the batching station where oil will subsequently be shipped on the Grand Rapids Pipeline to be sold at Edmonton. More significant production and sales volumes from Blackrod Phase 1 are expected in Q4 2026, in line with IPC’s annual production guidance. The forecast plateau production of 30,000 bopd is still expected to be achieved by the end of 2027.⁽¹⁾⁽²⁾

By the end of the second quarter of 2026, the final cumulative growth capital of approximately USD 855 million has been spent on the Blackrod Phase 1 development since sanction. Construction at the CPF and well pad facilities were completed, commissioning activities are substantially complete in line with schedule, and drilling plus completions have been completed in line with plan. Site health and safety control has been excellent with no lost time incidents since commercial development activities commenced.

The total growth capital expenditure of USD 855 million comprises the total installed costs for the facilities and associated 40 well pairs needed to fill the plant capacity of 30,000 bopd and has remained unchanged since the time of sanction in 2023.⁽¹⁾

Blackrod is a multi-generational asset that is being unlocked through the first phase of commercial development. More than 1.45 billion barrels of recoverable resource lies within the contiguous reservoir wholly owned by IPC. Future facilities expansion and phase development concepts continue to be matured by IPC. Blackrod has regulatory approval for up to 80,000 bopd.⁽¹⁾⁽²⁾

Environmental, Social and Governance (ESG) Performance

Alongside the publication of the second quarter 2026 financial report, IPC releases its annual Sustainability Report. The Sustainability Report provides details on IPC’s approach to sustainability and material sustainability topics highlighting specific initiatives and progress. The Sustainability Report is available on IPC’s website at www.international-petroleum.com.

During the second quarter of 2026, IPC recorded no material safety or environmental incidents. IPC sadly reports that a tragic incident occurred at end July 2026 at one of IPC’s operational sites in France where a contractor lost his life. The causes of the accident remain under investigation. IPC’s sincere condolences are to the deceased individual’s family and to all those affected by this accident. IPC confirms its ongoing commitment to the health and safety of all personnel.

Notes:

See “Supplemental Information regarding Product Types” in “Reserves and Resources Advisory” below. See also the annual information form for the year ended December 31, 2025 (AIF) available on IPC’s website at www.international-petroleum.com and under IPC’s profile on SEDAR+ at www.sedarplus.ca.
See “Reserves and Resources Advisory“ below. Further information with respect to IPC’s reserves, contingent resources and estimates of future net revenue are described in the AIF.
Non-IFRS measures, see “Non-IFRS Measures” below and in the MD&A.
OCF and FCF forecasts at Brent USD 70 to 90 per barrel assume Brent to WTI differential of USD 5 per barrel and WTI to WCS differential of USD 14 per barrel for the remainder of 2026. OCF and FCF forecasts assume gas price on average of approximately CAD 1.88 per Mcf for the remainder of 2026.

International Petroleum Corp. (IPC) is an international oil and gas exploration and production company with a high quality portfolio of assets located in Canada, Malaysia and France, providing a solid foundation for organic and inorganic growth. IPC is a member of the Lundin Group of Companies. IPC is incorporated in Canada and IPC’s shares are listed on the Toronto Stock Exchange (TSX) and the Nasdaq Stockholm exchange under the symbol "IPCO".

For further information, please contact:

Rebecca Gordon
SVP Corporate Planning and Investor Relations
rebecca.gordon@international-petroleum.com
Tel: +41 22 595 10 50

Robert Eriksson
Media Manager
reriksson@rive6.ch
Tel: +46 701 11 26 15

This information is information that International Petroleum Corporation is required to make public pursuant to the EU Market Abuse Regulation and the Securities Markets Act. The information was submitted for publication, through the contact persons set out above, at 07:30 CEST on August 4, 2026. The Corporation's unaudited interim condensed consolidated financial statements (Financial Statements) and management's discussion and analysis (MD&A) for the three and six months ended June 30, 2026 have been filed on SEDAR+ (www.sedarplus.ca) and are also available on the Corporation's website (www.international-petroleum.com).

Forward-Looking Statements
This press release contains statements and information which constitute "forward-looking statements" or "forward-looking information" (within the meaning of applicable securities legislation). Such statements and information (together, "forward-looking statements") relate to future events, including the Corporation's future performance, business prospects or opportunities. Actual results may differ materially from those expressed or implied by forward-looking statements. The forward-looking statements contained in this press release are expressly qualified by this cautionary statement. Forward-looking statements speak only as of the date of this press release, unless otherwise indicated. IPC does not intend, and does not assume any obligation, to update these forward-looking statements, except as required by applicable laws.

All statements other than statements of historical fact may be forward-looking statements. Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, forecasts, guidance, budgets, objectives, assumptions or future events or performance (often, but not always, using words or phrases such as "seek", "anticipate", "plan", "continue", "estimate", "expect", "may", "will", "project", “forecast”, "predict", "potential", "targeting", "intend", "could", "might", "should", "believe", "budget" and similar expressions) are not statements of historical fact and may be "forward-looking statements".

Forward-looking statements include, but are not limited to, statements with respect to:

2026 production ranges (including total daily average production), production composition, cash flows, operating costs and capital and decommissioning expenditure estimates;
Estimates of future production, cash flows, operating costs and capital expenditures that are based on IPC’s current business plans and assumptions regarding the business environment, which are subject to change;
IPC’s financial and operational flexibility to navigate the Corporation through periods of volatile commodity prices;
The ability to fully fund IPC’s future expenditures from cash flows and current borrowing capacity;
IPC’s intention and ability to continue to implement its strategies to build long-term shareholder value;
The ability of IPC’s portfolio of assets to provide a solid foundation for organic and inorganic growth;
The continued facility uptime and reservoir performance in IPC’s areas of operation;
Development of the Blackrod project in Canada, including estimates of resource volumes, future production, timing, regulatory approvals, third party commercial arrangements, breakeven oil prices, net present values and future phase developments;
Current and future production performance, operations and development potential of the Onion Lake Thermal, Suffield, Brooks, Ferguson and Mooney operations, including the timing and success of future oil and gas drilling and optimization programs;
The potential improvement in the Canadian oil egress situation and IPC’s ability to benefit from any such improvements;
The ability of IPC to maintain current and forecast production in France and Malaysia;
The intention and ability of IPC to acquire common shares under the NCIB, including the timing of any such purchases;
The return of value to IPC’s shareholders as a result of the NCIB;
IPC’s ability to implement its greenhouse gas (GHG) emissions intensity and climate strategies and to achieve its net GHG emissions intensity reduction targets;
IPC's ability to implement projects to reduce net GHG emissions intensity, including potential carbon capture and storage;
Estimates of reserves and contingent resources;
The ability to generate free cash flows and use that cash to repay debt;
IPC’s continued access to its existing credit facilities, including current financial headroom, on terms acceptable to the Corporation;
IPC’s ability to identify and complete future acquisitions;
Expectations regarding the oil and gas industry in Canada, Malaysia and France, including assumptions regarding future royalty rates, regulatory approvals, legislative changes, tariffs, and ongoing projects and their expected completion; and
Future drilling and other exploration and development activities.

Statements relating to "reserves" and "contingent resources" are also deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and that the reserves and resources can be profitably produced in the future. Ultimate recovery of reserves or resources is based on forecasts of future results, estimates of amounts not yet determinable and assumptions of management. See also “Reserves and Resources Advisory”.

The forward-looking statements are based on certain key expectations and assumptions made by IPC, including expectations and assumptions concerning: the duration and impact of tariffs that are currently in effect on goods exported from or imported into Canada, and that other than the tariffs that are currently in effect, neither the U.S. nor Canada (i) increases the rate or scope of such tariffs, reenacts tariffs that are currently suspended, or imposes new tariffs, on the import of goods from one country to the other, including on oil and natural gas, and/or (ii) imposes any other form of tax, restriction or prohibition on the import or export of products from one country to the other, including on oil and natural gas; prevailing commodity prices and currency exchange rates; applicable royalty rates and tax laws; interest rates; future well production rates and reserve and contingent resource volumes; operating costs; IPC's ability to maintain its existing credit ratings; IPC's ability to achieve its performance targets; the timing of receipt of regulatory approvals; the performance of existing wells; the success obtained in drilling new wells; anticipated timing and results of capital expenditures; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the successful completion of acquisitions and dispositions and that IPC will be able to implement its standards, controls, procedures and policies in respect of any acquisitions and realize the expected synergies on the anticipated timeline or at all; the benefits of acquisitions; the state of the economy and the exploration and production business in the jurisdictions in which IPC operates and globally; the availability and cost of financing, labour and services; IPC's intention to complete share repurchases under the normal course issuer bid program, including the funding of such share repurchases, existing and future market conditions, including with respect to the price of IPC's common shares, and compliance with respect to applicable limitations under securities laws and regulations and stock exchange policies; and the ability to market crude oil, natural gas and natural gas liquids successfully.

Although IPC believes that the expectations and assumptions on which such forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because IPC can give no assurances that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks.

These include, but are not limited to: general global economic, market and business conditions; the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of estimates and projections relating to reserves, resources, production, revenues, costs and expenses; health, safety and environmental risks; commodity price fluctuations; interest rate and exchange rate fluctuations; marketing and transportation; loss of markets; environmental and climate-related risks; competition; innovation and cybersecurity risks related to IPC’s systems, including costs of addressing or mitigating such risks; the ability to attract, engage and retain skilled employees; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; the ability to access sufficient capital from internal and external sources; failure to obtain required regulatory and other approvals; geopolitical conflicts, including current and potential future conflicts in Ukraine, the Middle East, South America and elsewhere, and their potential impact on, among other things, global market conditions; political or economic developments, including, without limitation, the risk that (i) the tariffs that are currently in effect on goods exported from or imported into Canada continue in effect for an extended period of time, the tariffs that have been threatened are implemented, that tariffs that are currently suspended are reactivated, the rate or scope of tariffs are increased, or new tariffs are imposed, including on oil and natural gas, (ii) 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 on oil and natural gas, and (iii) the tariffs imposed or threatened to be imposed by the U.S. on other countries and retaliatory tariffs imposed or threatened to be imposed by other countries on the U.S. will trigger a broader global trade war which could have a material adverse effect on the Canadian, U.S. and global economies, and by extension the Canadian oil and natural gas industry and the Corporation, including by decreasing demand for, and the price of oil, and natural gas, disrupting supply chains, increasing costs, causing volatility in the global financial markets, and limiting access to financing; and changes in legislation, including but not limited to tax laws, royalties, environmental and abandonment regulations. Readers are cautioned that the foregoing list of factors is not exhaustive.

Additional information on these and other factors that could affect IPC, or its operations or financial results, are included in the MD&A (See “Risk Factors”, "Cautionary Statement Regarding Forward-Looking Information" and “Reserves and Resources Advisory”), the Corporation’s Annual Information Form (AIF) for the year ended December 31, 2025, (See “Cautionary Statement Regarding Forward-Looking Information”, “Reserves and Resources Advisory” and “Risk Factors”) and other reports on file with applicable securities regulatory authorities, including previous financial reports, management’s discussion and analysis and material change reports, which may be accessed through the SEDAR+ website (www.sedarplus.ca) or IPC's website (www.international-petroleum.com).

Management of IPC approved the production, operating costs, operating cash flow, capital and decommissioning expenditures and free cash flow guidance and estimates contained herein as of the date of this press release. The purpose of these guidance and estimates is to assist readers in understanding IPC’s expected and targeted financial results, and this information may not be appropriate for other purposes.

Estimated production and FCF generation are based on IPC’s current business plans over the periods of 2026 to 2030 and 2031 to 2035, less net debt of USD 484 million as at December 31, 2025, with assumptions based on the reports of IPC’s independent reserves evaluator and auditor, and including certain corporate adjustments relating to estimated general and administrative costs and hedging, and excluding shareholder distributions and certain refinancing costs. Assumptions include average net production of approximately 62 Mboepd over the period of 2026 to 2030, average capital expenditures of approximately USD 5 per boe, average operating costs of approximately USD 18 to 20 per boe, average Brent oil prices of USD 65 to 95 per bbl escalating by 2% per year, and average Brent to Western Canadian Select differentials and average gas prices as estimated by IPC’s independent reserves evaluator and auditor and as further described in the AIF. IPC’s current business plans and assumptions, and the business environment, are subject to change. Actual results may differ materially from forward-looking estimates and forecasts.

Non-IFRS Measures
References are made in this press release to "operating cash flow" (OCF), “free cash flow” (FCF), "Earnings Before Interest, Tax, Depreciation and Amortization" (EBITDA), "operating costs" and "net debt"/”net cash”, which are not generally accepted accounting measures under International Financial Reporting Standards (IFRS) and do not have any standardized meaning prescribed by IFRS and, therefore, may not be comparable with similar measures presented by other public companies. Non-IFRS measures should not be considered in isolation or as a substitute for measures prepared in accordance with IFRS.

The definition of each non-IFRS measure is presented in IPC's MD&A (See "Non-IFRS Measures" therein).

Operating cash flow
The following table sets out how operating cash flow is calculated from figures shown in the Financial Statements:

	Three months ended June 30		Six months ended June 30
USD Thousands	2026	2025	2026	2025
Revenue	185,738	158,892	358,748	337,384
Production costs and net sales of diluent to third party¹	(118,008)	(103,682)	(222,827)	(206,870)
Current tax	(1,212)	(337)	(1,668)	(851)
Operating cash flow	66,518	54,873	134,253	129,663

¹ Includes net sales of diluent to third party amounting to USD 345 thousand for the first six months of 2026.

Free cash flow
The following table sets out how free cash flow is calculated from figures shown in the Financial Statements:

	Three months ended June 30		Six months ended June 30
USD Thousands	2026	2025	2026	2025
Operating cash flow - see above	66,518	54,873	134,253	129,663
Capital expenditures	(47,998)	(97,925)	(118,659)	(196,811)
Abandonment and farm-in expenditures¹	(576)	(2,097)	(1,048)	(2,418)
General and administrative expenses before depreciation²	(3,874)	(3,691)	(7,776)	(8,049)
Cash financial items³	(10,175)	(9,412)	(19,961)	(23,809)
Free cash flow	3,895	(58,252)	(13,191)	(101,424)

¹See note 15 to the Financial Statements.
²Depreciation is not specifically disclosed in the Financial Statements.
³See note 4 to the Financial Statements.

EBITDA
The following table sets out the reconciliation from net result from the consolidated statement of operations to EBITDA:

	Three months ended June 30		Six months ended June 30
USD Thousands	2026	2025	2026	2025
Net result	9,917	13,850	22,679	30,081
Net financial items	22,385	(159)	43,122	18,696
Income tax	4,145	6,167	7,531	10,846
Depletion and decommissioning costs	28,802	29,321	58,733	58,337
Depreciation of other tangible fixed assets	--	1,461	--	3,378
Exploration and business development costs	671	537	1,574	568
Sale of assets¹	(2,428)	(10)	(6,221)	(104)
Depreciation included in general and administrative expenses²	364	352	727	663
EBITDA	63,856	51,519	128,145	122,465

¹ Sale of assets is included under “Other income/(expense)” but not specifically disclosed in the Financial Statements.
² Item is not shown in the Financial Statements.

Operating costs
The following table sets out how operating costs is calculated:

	Three months ended June 30		Six months ended June 30
USD Thousands	2026	2025	2026	2025
Production costs	118,171	103,910	223,172	207,289
Cost of blending	(47,564)	(33,269)	(86,455)	(70,995)
Change in inventory position	2,831	(119)	4,960	3,381
Operating costs	73,438	70,522	141,677	139,675

Net cash/(debt)
The following table sets out how net cash / (debt) is calculated from figures shown in the Financial Statements:

USD Thousands	June 30, 2026	December 31, 2025
Bank loans	(70,247)	(40,652)
Bonds¹	(450,000)	(450,000)
Cash and cash equivalents	11,248	7,037
Net cash/(debt)	(508,999)	(483,615)

Reserves and Resources Advisory
This press release contains references to estimates of gross and net reserves and resources attributed to the Corporation's oil and gas assets. For additional information with respect to such reserves and resources, refer to “Reserves and Resources Advisory” in the MD&A. Light, medium and heavy crude oil reserves/resources disclosed in this press release include solution gas and other by-products. Also see “Supplemental Information regarding Product Types” below.

Reserve estimates, contingent resource estimates and estimates of future net revenue in respect of IPC’s oil and gas assets in Canada and France/Malaysia are effective as of December 31, 2025, and are included in the reports prepared by Sproule International Limited and ERC Equipoise Ltd., respectively (collectively, Sproule ERCE), an independent qualified reserves evaluator and auditor, in accordance with National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (NI 51-101) and the Canadian Oil and Gas Evaluation Handbook (the COGE Handbook) and using Sproule ERCE’s December 31, 2025 price forecasts.

The price forecasts used in the Sproule ERCE reports are available on the website of Sproule ERCE (sproule-erce.com) and are contained in the AIF. These price forecasts are as at December 31, 2025 and may not be reflective of current and future forecast commodity prices.

The reserve life index (RLI) is calculated by dividing the 2P reserves of 521 MMboe as at December 31, 2025 by the mid-point of the 2026 CMD production guidance of 44,000 to 47,000 boepd.

IPC uses the industry-accepted standard conversion of six thousand cubic feet of natural gas to one barrel of oil (6 Mcf = 1 bbl). A BOE conversion ratio of 6:1 is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. As the value ratio between natural gas and crude oil based on the current prices of natural gas and crude oil is significantly different from the energy equivalency of 6:1, utilizing a 6:1 conversion basis may be misleading as an indication of value.

Supplemental Information regarding Product Types

The following table is intended to provide supplemental information about the product type composition of IPC’s net average daily production figures provided in this press release:

	Heavy Crude Oil (Mbopd)	Light and Medium Crude Oil (Mbopd)	Conventional Natural Gas (per day)	Total (Mboepd)
Three months ended
June 30, 2026	22.4	5.7	84.8 MMcf (14.1 Mboe)	42.2
June 30, 2025	22.7	5.9	89.8 MMcf (15.0 Mboe)	43.6
Six months ended
June 30, 2026	22.4	6.0	85.2 MMcf (14.2 Mboe)	42.6
June 30, 2025	23.0	6.2	89.0 MMcf (14.8 Mboe)	44.0
Year ended
December 31, 2025	23.6	6.4	89.6 MMcf (14.9 Mboe)	44.9

This press release also makes reference to IPC’s forecast total average daily production of 44,000 to 47,000 boepd for 2026. IPC estimates that approximately 57% of that production will be comprised of heavy crude oil, approximately 12% will be comprised of light and medium crude oil and approximately 31% will be comprised of conventional natural gas.

Currency
All dollar amounts in this press release are expressed in United States dollars, except where otherwise noted. References herein to USD mean United States dollars and to MUSD mean millions of United States dollars. References herein to CAD mean Canadian dollars.

Attachment

IPC_qr_2_2026_FSandMDA

International Petroleum Corporation Announces Second Quarter 2026 Financial and Operational Results and Releases Sustainability Report