Strathcona Announces Sale Of Montney Business For $2.84B And Acquisition Of Hardisty Rail Terminal

Strathcona Resources Ltd. (“Strathcona” or the “Company”) is pleased to announce that it has entered into definitive agreements to sell substantially all of its Montney assets for approximately $2.84B, pursuant to three separate transactions:

1. The sale of its Kakwa asset (the “Kakwa Sale”) to ARC Resources Ltd. for approximately $1,695M in total value ($1,650M in cash and approximately $45M in assumed lease obligations)
2. The sale of its Grande Prairie asset (the “Grande Prairie Sale”) for approximately $850M in total value ($750M in cash and approximately $100M in assumed lease obligations)
3. The sale of its Groundbirch asset (the “Groundbirch Sale”) to Tourmaline Oil Corp. (“Tourmaline”) for $291.5M in common shares of Tourmaline

Taken together, the disposed assets generated $149M of operating earnings in 2024 (12% of total Strathcona YE 2024 operating earnings, excluding interest and other corporate items) and had a YE 2024 proved PV-10 before-tax of approximately $2.3B (15% of total Strathcona YE 2024 proved PV-10), while the combined sale price represents approximately 33% of Strathcona’s current enterprise value. The table below shows Strathcona’s consolidated results for the year ended December 31, 2024, less the Montney dispositions.

The Kakwa Sale is expected to occur early in the third quarter of 2025, subject to receipt of regulatory approvals and the satisfaction of other customary closing conditions.

The Grande Prairie Sale is expected to occur early in the third quarter of 2025, subject to receipt of regulatory approvals and the satisfaction of other customary closing conditions.

The Groundbirch sale is expected to occur in the second quarter of 2025, subject to receipt of regulatory approvals and the satisfaction of other customary closing conditions. The share consideration is not subject to any lock-up periods beyond a four-month statutory hold period. Strathcona is delighted to be a shareholder of Tourmaline and has no plans to dispose of the shares at this time.

Strathcona has $5.5B of tax pools at March 31, 2025 and does not expect any cash taxes to result from the Montney dispositions.

Strathcona would like to thank its entire Montney team, led by President Al Grabas, for their invaluable contributions in growing the Montney business from just 5 Mboe / d in January 2017 to 72 Mboe / d in 2024. Strathcona would also like to congratulate each of the purchasers, each of whom are well positioned to maximize value for the assets going forward given the hand-in-glove fit with each of their existing operations and their long track records of first-class operations in the surrounding areas.

Updated Guidance and Long-Range Plan
Upon completion of the Montney dispositions, Strathcona will be a pure-play heavy oil company producing approximately 120 Mbbls / d (100% oil, 95 Mbbls / d thermal, 25 Mbbls / d conventional) with a 50-year 2P reserve life index and positive net cash (including marketable securities).

Updated 2025 Guidance
Strathcona expects Q2 2025 production of 180 Mboe / d, which includes an approximately 7 Mbbls / d impact from a major turnaround (5-year cycle) at Tucker. Full year 2025 production is expected to average 150 – 160 Mboe / d, with 120 to 125 Mbbls / d expected in the third and fourth quarters post the Montney dispositions.

The full year range includes an approximately 5 Mbbls / d increase compared to original 2025 guidance, normalized for the Montney dispositions, driven by outperformance at Cold Lake.

Full year capital expenditures are estimated at $1.2B (from $1.35B previously), which reflects the removal of Montney capital from the second half of 2025.

Updated Long-Range Plan
Pro forma for the Montney dispositions, Strathcona's current long-range plans sees growth to 195 Mbbls / d by 2031, reflecting an 8% 7-year CAGR versus 2024. Upon reaching this plateau level, Strathcona's 2P Reserve Life Index is expected to still be approximately 25 years based on current 2P reserves (assuming no reserve additions between year-end 2024 and 2031).

Substantially all production growth is expected to come from Strathcona's thermal properties, with thermal production in Cold Lake and Lloydminster reaching approximately 170 Mbbls / d in 2031. Strathcona's current long-range plan only reflects the development of existing projects and brownfield expansions, and does not include greenfield projects.

Capital expenditures are expected to average $0.9 - $1.0B in 2026 and $1.1 - $1.2B in 2027 – 2029, before returning to sustaining expected capital of $0.8 and $0.85B in 2030 and 2031. In light of low current oil prices, Strathcona's updated long-range plan reflects a deferral of the sanction of the Lindbergh Phase 2 expansion project from 2026 to 2027 to prioritize near-term free cash flow generation.

Strathcona will remain nimble in allocating capital and will update its plans over time based on its view of risk-adjusted returns, bearing in mind commodity prices and capital market dynamics. A full reconciliation of Strathcona's current long-range plan to the plan presented by the Company at its 2024 Investor Day is shown below.

Production (Full-Year Annualized) (Mboe / d)

Capital Expenditures (Full-Year Annualized) (C$mm)

Hardisty Rail Terminal Acquisition
Also in the first quarter of 2025, Strathcona signed a definitive agreement to acquire the Hardisty Rail Terminal ("HRT") for cash consideration of approximately $45M and closed on the acquisition early in the second quarter. HRT, located in Hardisty, Alberta, is the largest crude-by-rail terminal in Western Canada with capacity of 262 Mbbls / d and year-to-date throughput of approximately 50 Mbbls / d. HRT is directly connected to the Hardisty Diluent Recovery Unit, an innovative facility which separates diluent from raw bitumen prior to rail transportation, allowing for a competitive netback for upstream producers versus pipeline alternatives.

HRT has an estimated replacement cost of approximately $200M and free cash flow over the past twelve months of approximately $12M, 80% of which is underpinned by long-term take-or-pay contracts with an investment grade counterparty. Together with Strathcona's Hamlin Terminal, Strathcona now owns and operates rail terminals servicing approximately 80% of the total current crude-by-rail volumes in western Canada, allowing for meaningful economies of scale.

The HRT acquisition is a continuation of Strathcona's countercyclical acquisition strategy focused on core area consolidation. While HRT is only 19% utilized today, it has been up to 82% utilized historically during periods of tight pipeline egress, providing Strathcona with a natural hedge against future egress bottlenecks.

First Quarter Earnings Release and Conference Call
Strathcona will release its first quarter earnings after market on May 15, 2025, with a conference call to follow the morning of May 16, 2025.

Advisors
BMO Capital Markets acted as lead financial advisor, and CIBC Capital Markets and Jefferies acted as financial advisors to Strathcona on the Kakwa Sale.

BMO Capital Markets acted as exclusive financial advisor and RBC Capital Markets acted as strategic advisor to Strathcona on the Grande Prairie Sale.

Scotiabank acted as lead financial advisor and RBC Capital Markets and ATB Capital Markets acted as financial advisors on the Groundbirch Sale.

National Bank Financial acted as financial advisor to Strathcona on the Hardisty Rail Terminal acquisition.

About Strathcona
Strathcona is one of North America's fastest growing oil and gas producers with operations focused on thermal oil and enhanced oil recovery. Strathcona is built on an innovative approach to growth achieved through the consolidation and development of long-life oil and gas assets. Strathcona's common shares (symbol SCR) are listed on the Toronto Stock Exchange (TSX).

For more information, visit www.strathconaresources.com.

2024 Segment Information
The following table presents financial performance by reportable segment for the year ended December 31, 2024. Certain information related to general and administrative and finance costs has been represented to allocate by segment to conform with presentation as at March 31, 2025. Operating earnings is the metric used by the Company's Chief Operating Decision Makers to evaluate segment profit or loss.

Blake, Cassels & Graydon LLP acted as legal advisor to Strathcona in respect of each of the transactions.

(¹) A non-GAAP financial measure which does not have a standardized meaning under the Accounting Standards; see "Specified Financial Measures" section of this press release.

Specified Finanical Measures

Non-GAAP Financial Measures and Ratios
This press release makes reference to certain financial measures and ratios, including field operating income and oil and natural gas sales, net of blending, which are not standardized financial measures under IFRS® Accounting Standards (the "Accounting Standards") and might not be comparable to similar financial measures disclosed by other issuers. Non-GAAP financial measures and ratios are used internally by management to assess the performance of the Company. They also provide investors with meaningful metrics to assess the Company's performance compared to other companies in the same industry. Investors are cautioned that these measures should not be construed as an alternative to financial measures determined in accordance with generally accepted accounting principles ("GAAP") and these measures should not be considered to be more meaningful than GAAP measures in evaluating the Company's performance.

The term "Oil and natural gas sales, net of blending" is calculated by deducting purchased product and blending costs from oil and natural gas sales and sales of purchased product. Management uses this metric to isolate the revenue associated with the Company's production after accounting for the unavoidable cost of blending. A quantitative reconciliation of Oil and natural gas sales, net of blending to the most directly comparable GAAP financial measure, Oil and natural gas sales, is contained under the heading "2024 Segment Information" of this press release.

"Field Operating Income" is a common metric used in the oil and natural gas industry to assess the profitability and efficiency of the Company's field operations.

The following table reconciles "Field Operating Income" to the nearest GAAP measure.

Supplementary Financial Measures
"TEV" is an aggregation of the Company's market capitalization, debt and lease and other obligations. Market capitalization is determined by multiplying outstanding common shares by the common share price. Debt and other obligations are as derived under IFRS Accounting Standards.

Presentation of Oil and Gas Information
In respect of 2024 year-end reserves information contained in this press release, Strathcona’s reserves have been evaluated in accordance with Canadian reserve evaluation standards under National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”). McDaniel & Associates Consultants Ltd., an independent petroleum consulting firm based in Calgary, Alberta, has evaluated the petroleum and natural gas reserves associated with Strathcona’s interests in Alberta, British Columbia and Saskatchewan. Such estimates constitute forward-looking information, which are based on values that Strathcona’s management believes to be reasonable and are subject to the same limitations discussed under “Forward-Looking Information” below. A complete filing of our oil and gas reserves and other oil and gas information presented in accordance with NI 51-101 are included in Strathcona’s Annual Information Form for the year ended December 31, 2024, which can be found at www.sedarplus.ca and www.strathconaresources.com.

This press release contains various references to the abbreviation “boe” which means barrels of oil equivalent. All boe conversions in this press release are derived by converting gas to oil at the ratio of six thousand cubic feet (“mcf”) of natural gas to one barrel (“bbl”) of crude oil. Boe may be misleading, particularly if used in isolation. A boe conversion rate of 1 bbl : 6 mcf 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 of oil compared to natural gas based on currently prevailing prices is significantly different than the energy equivalency ratio of 1 bbl : 6 mcf, utilizing a conversion ratio of 1 bbl : 6 mcf may be misleading as an indication of value.

References in this press release to initial production rates and other short-term production rates and test results are useful in confirming the presence of hydrocarbons, however, such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long-term performance or of ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating aggregate production for the Company or the assets for which such rates are provided. A pressure transient analysis or well-test interpretation has not been carried out in respect of all wells. Accordingly, the test results should be considered to be preliminary.