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    Earnings call· Jun 2025(Q2 FY25)

    SUNCOR ENERGY Q2 FY25 earnings call SU

    Aug 6, 2025 Source

    Executive summary

    Suncor Energy Q2 FY25 — Record Production & Refining Throughput, Capital Reduction

    Suncor delivered a strong second quarter, marked by record operational performance across upstream and downstream segments, despite significant turnaround activity and commodity price volatility. The company successfully executed major capital projects ahead of schedule and under budget, leading to a structural reduction in capital expenditure guidance. This operational excellence and capital discipline are driving consistent shareholder returns and positioning the company for future value growth.

    Highlights

    5

    • Achieved highest Q2 and H1 upstream production in company history, with H1 FY25 production at 831,000 bbl/d, beating previous best by 28,000 bbl/d.

    • Set highest Q2 and H1 refining throughput in company history, with H1 FY25 throughput at 462,000 bbl/d, beating previous best by 20,000 bbl/d.

    • Reduced annual turnaround capital target by $100 million, from $250 million to $350 million per year.

    • Completed Base Plant U1 Coke drum replacement project 24 days ahead of schedule and $165 million (14%) under budget.

    • Completed Syncrude Mildred Lake West mine extension 6 months ahead of schedule and $100 million under budget.

    Concerns

    2

    • Q2 AFFO was impacted by approximately $0.5 billion due to an $8/bbl drop in WTI and a 2-point strengthening of the Canadian dollar.

    • Crude oil price volatility continued in Q2, with WTI ranging from high $50s to mid-$70s, averaging $63.70/bbl.

    Guidance & targets

    9
    CategoryTargetConfidence
    Full-year 2025 Capital Expenditure
    $5.7 billion to $5.9 billion
    high materiality
    High
    Annual Turnaround Capital Reduction
    $350 million per year
    medium materiality
    High
    Full-year Upstream Production Volume
    high end of guidance ranges
    high materiality
    High
    U2 Coker Furnace Outage Intervals
    extended by a year
    medium materiality
    High
    U2 Major Turnaround Intervals
    from 5-year to 6-year intervals
    medium materiality
    High
    Upgrader 1 Turnaround Interval
    from 5 to 6 years
    medium materiality
    High
    Fort Hills Primary Separation Cell Outages
    from every 6 months to once annually
    medium materiality
    High
    Syncrude Autonomous Haulage Implementation
    implement autonomous haulage into Syncrude in 2026
    medium materiality
    High
    Base Plant Autonomous Haulage Trucks
    150 or more by the end of the year
    medium materiality
    High

    Operational metrics

    36
    Upstream Production
    831,000up 28,000 bbl/d vs. H1 FY24
    H1 FY25

    Highest first half in company history.

    Upstream Production
    808,000
    Q2 FY25

    Highest second quarter in company history.

    Oil Sands Production
    748,000
    Q2 FY25

    Reflecting impact of turnaround and Coke drum replacement at Base Plant Upgrader 1.

    E&P Production
    60,000in line with Q1 production
    Q2 FY25
    Upgrader Utilization
    94%
    H1 FY25

    Despite major base plant turnaround activity.

    Refining Throughput
    462,000up 20,000 bbl/d vs. H1 FY24
    H1 FY25

    Highest first half in company history.

    Refining Throughput
    442,000
    Q2 FY25

    Highest second quarter in company history.

    Refining Utilization
    99%
    H1 FY25

    Despite major turnaround activity.

    Refining Utilization
    95%
    Q2 FY25

    Despite significant planned maintenance.

    Product Sales
    603,000up 15,000 bbl/d vs. H1 FY24
    H1 FY25

    Highest first half in company history.

    Product Sales
    600,000
    Q2 FY25

    Consistently strong.

    Operating, Selling & General (OS&G) Expense
    $6.46 billiondown $135 million vs. H1 FY24
    H1 FY25

    Despite higher production, refining throughput, and product sales.

    Operating, Selling & General (OS&G) Expense
    down $765 million
    H1 FY25 vs H1 FY23

    Despite 89,000 bbl/d higher production, 81,000 bbl/d higher refining throughput, and 72,000 bbl/d higher product sales.

    Annual Turnaround Capital
    $1.25 billion
    Annual

    Historically, greater than 20% of capital spent on turnarounds.

    Edmonton Refinery Turnaround Cost
    $142 milliondown $17 million (11%) vs. previous
    Q2 FY25

    Previous cost was $159 million. Completed in 36 days vs. 41-day plan and 44-day previous, improving from fourth to second quartile.

    Sarnia Refinery Turnaround Cost
    $94 milliondown $14 million (13%) vs. previous
    Q2 FY25

    Previous cost was $108 million. Completed in 28 days vs. 40-day plan and 44-day previous, improving from fourth to first quartile.

    Base Plant Upgrader 1 Turnaround Cost
    $231 milliondown $28 million (11%) vs. planned
    Q2 FY25

    Planned cost was $259 million. Completed in 67 days vs. 91-day plan, improving from fourth to second quartile.

    Turnaround Performance Quartile
    approaching industry second quartile
    FY25

    Second quartile in North America represents best-in-class in Canada.

    WTI Crude Oil Price
    $63.70down almost $8/bbl from Q1
    Q2 FY25

    Range from high $50s to mid-$70s in Q2.

    Light-Heavy Differential
    $2.45tightened vs. Q1
    Q2 FY25

    Averaging $10.00/bbl discount relative to WTI.

    Synthetic Crude Premium
    $1improved by $3/bbl vs. Q1
    Q2 FY25

    Premium versus WTI.

    2-1-1 Cracking Margins
    improved
    Q2 FY25

    Driven by improving gasoline and distillate cracks.

    5-2-2-1 Refining Index
    $27.85grew
    Q2 FY25
    CAD to USD Exchange Rate
    $0.72strengthened from $0.70
    Q2 FY25
    Adjusted Funds From Operations (AFFO) Impact
    $0.5 billion
    Q2 FY25

    Potential impact from $8/bbl WTI drop and 2-point CAD strengthening, mitigated by integrated model.

    Downstream Margin Capture
    96%
    Q2 FY25

    Relative to 5-2-2-1 index, despite planned maintenance.

    Adjusted Funds From Operations (AFFO)
    $2.7 billion
    Q2 FY25
    Adjusted Operating Earnings
    $873 million
    Q2 FY25
    Total Operating, Selling & General (OS&G) Expense
    $3.2 billiondown over $130 million vs. Q1
    Q2 FY25
    Capital Expenditures
    $1.65 billion
    Q2 FY25

    Includes economic investments and sustaining/maintenance capital.

    Net Debt
    $7.7 billion
    Q2 FY25

    At quarter end.

    Net Debt to AFFO
    well below 1x
    Trailing 12-month
    Working Capital Release
    $269 million
    Q2 FY25

    Due to drawdown in inventories following Q1 build for turnarounds.

    Fort Hills Stream Day Capacity
    in excess of 220,000
    Current

    Demonstrated capacity, team working to ensure reliable operation at these rates.

    Autonomous Haulage Trucks
    120up from 20 in May 2024
    May 2025

    Scaling up deployment, seeing real efficiency gains and productivity.

    Retail Sales Growth
    8%
    YoY

    Strong local environment for downstream business.

    Industry KPIs

    2
    MetricValueDetails
    Realized price differential$10.00USD/bbl
    FCF shareholder distributions$1.5 billionCAD

    Orderbook & backlog

    1
    Share Buyback Authorization2.3% of equity floatYTD FY25

    nearly 1.2% per quarter

    Repurchased so far this year, supporting future dividend and free funds flow per share growth.

    Capital programs

    2
    Base Plant U1 Coke Drum Replacementcompleted$1.2 billion

    Benefit: Modernized design, upgraded metallurgy, automated controls, enhanced safety systems, lower maintenance costs, higher reliability, extended turnaround interval from 5 to 6 years.

    Completed in 67 days, 24 days ahead of 91-day guidance, and $165 million (14%) below funding. Most extensive Coke drum replacement project in industry history.

    Syncrude Mildred Lake West Mine Extensioncompleted$1.5 billion gross

    Benefit: Develop 730 million barrels of bitumen, replacing North mine. Developed without new tailings pond or processing plant.

    Achieved first ore in April, 6 months ahead of schedule and $100 million below funding. Project involved new mine, haul roads, transport bridge, power lines, and pipeline.

    Risks & headwinds

    2
    Crude Oil Price VolatilityQ2 FY25, expected to continue in H2 FY25

    WTI ranged from high $50s to mid-$70s in Q2, averaging $63.70/bbl. An $8/bbl drop in WTI and a 2-point strengthening of CAD would have a $0.5 billion impact on quarterly AFFO.

    Mitigation: Integrated business model, stronger refining margins, improved synthetic pricing, and strong operational performance mitigated over half the potential impact.

    Global Trade and TariffsH2 FY25

    Unquantified.

    Mitigation: Management expects continued commodity market volatility, including ongoing concerns around global trade and tariffs. No specific mitigation strategy was detailed beyond the resilience of the integrated model.

    What to watch in Q3 FY25

    5

    Full-year Upstream Production Volume

    Next quarter (Q3 FY25 results)
    Current808,000 bbl/d (Q2 FY25), 831,000 bbl/d (H1 FY25)
    TargetHigh end or above 810,000-840,000 bbl/d

    Why it matters

    Verifies the impact of early turnaround completions and continuous operational improvements on full-year production, a key driver of cash flow.

    And although it's too early in the year to update volumes, year-to-date performance points to the high end of all guidance ranges.

    Q&A highlights

    6

    Has U1 stream day capacity increased after the project? And given improved cash flow and lower CapEx, is the $8 billion net debt target still appropriate, or would a higher allowable debt number enable a larger buyback (e.g., SIB)?

    U1 stream day capacity remains around 140,000 bbl/d; the benefit is extended turnaround intervals and improved reliability. The $8 billion net debt target was based on 1x coverage in a $50/bbl WTI world. While the company is ahead of schedule on its 3-year plan and generating significant cash, they are not moving off the target today but will examine it in the future. They are focused on maximizing excess free funds flow to shareholders and are pleased with the consistent $250 million/month buybacks.

    “The $8 billion was determined by kind of 1x coverage in a $50 a barrel WTI world. And as we put that 3-year plan together, it was as we execute and deliver on that 3-year plan, there's no doubt about it. We are ahead of schedule on delivering on that plan and in a number of areas exceeding it. We -- I think that's something that we will need to examine and as the business performance continues to achieve, it's natural to look at that.”

    asked by Greg Pardy (RBC) · answered by Richard Kruger

    2 min read5 chapters

    Detailed Narrative

    01

    Operational Excellence & Safety

    Suncor reported its safest first half ever in 2025, building on record safety performance in 2023 and 2024. The company has fully converted all sites to a new operational excellence system based on 21 work processes, designed to ensure clarity, consistency, and quality in operations, reducing site-by-site variation and elevating overall performance. This system is described as a "game changer" for institutionalizing operational excellence.

    02

    Turnaround Performance Improvement

    The company has significantly improved turnaround performance, exceeding initial targets for duration and cost reduction. Examples include the Edmonton refinery turnaround completed in 36 days ($142M cost vs. $159M previous), Sarnia refinery in 28 days ($94M cost vs. $108M previous), and Base Plant Upgrader 1 in 67 days ($231M cost vs. $259M planned). These improvements are moving Suncor's performance from fourth quartile to second or first quartile in North America.

    03

    Capital Project Execution

    Suncor successfully completed two major capital projects ahead of schedule and under budget. The Base Plant U1 Coke drum replacement, a $1.2 billion project, was completed in 67 days (24 days ahead of guidance) and $165 million (14%) under funding. The Syncrude Mildred Lake West mine extension, a $1.5 billion gross project, achieved first ore in April, 6 months ahead of schedule and $100 million below funding.

    04

    Integrated Business Model Resilience

    Despite significant crude oil price volatility (WTI averaging $63.70/bbl in Q2) and a strengthening Canadian dollar, Suncor's integrated business model mitigated over half of the potential $0.5 billion impact on quarterly AFFO. Stronger refining margins and improved synthetic pricing, coupled with robust operational performance, contributed to this resilience, demonstrating the value of integration in a commodity business.

    05

    Long-Term Growth & Credibility

    Management indicated that while the focus has been on executing the current 3-year plan, they are actively developing longer-term plans and options for value growth. The intent is to re-earn credibility to discuss long-term outlooks in the first half of 2026, emphasizing internal opportunities for value creation over mere size or difference.

    AI-generated summary of the company’s earnings call. Not investment advice.