IMO

Business Context and Reporting Period

Company: Imperial Oil Limited
Filing Type: Form 10-Q (Quarterly Report)
Reporting Period: Quarter and nine months ended September 30, 2002
Business Overview: Imperial Oil operates in three primary segments: Natural Resources (upstream oil and gas), Petroleum Products (refining and marketing), and Chemicals. The company is incorporated in Canada, and all financial figures are presented in Canadian dollars unless otherwise noted.

Key Financial Metrics

Material Changes vs. Prior Period

• Quarterly Performance (Q3 2002 vs. Q3 2001): Net earnings increased by 45% to $344 million, driven by higher crude oil prices and improved heavy oil markets. This offset lower petroleum products margins. Total revenues rose 8% to $4.532 billion.
• Year-to-Date Performance (9 Months 2002 vs. 2001): Net earnings declined 28% to $756 million. The decrease was attributed to significantly lower natural gas prices, reduced crude oil production volumes, and weaker petroleum products markets. Revenues fell 11% to $12.212 billion.
• Segment Results:
  • Resources: Q3 earnings surged to $343 million (vs. $231 million prior year) due to better heavy oil markets. However, YTD earnings dropped to $730 million (vs. $821 million) due to lower natural gas prices.
  • Petroleum Products: Q3 earnings fell to $21 million (vs. $42 million). YTD results turned to a net loss of $1 million compared to record earnings of $278 million in the prior year, caused by reduced industry margins.
  • Chemicals: Earnings improved significantly in both Q3 ($22 million vs. $7 million) and YTD ($42 million vs. $14 million) due to lower feedstock costs and higher polyethylene sales.
• Production Volumes: Natural gas production declined due to natural reservoir decline (527 million cubic feet/day in Q3 vs. 550 million prior year). Conventional crude oil production also decreased (49,000 barrels/day in Q3 vs. 55,000 prior year). Syncrude production increased to 65,000 barrels/day in Q3.

Outlook, Risks, and Management Commentary

• Capital Projects: Construction at Cold Lake (phases 11-13) and Syncrude (Aurora site and upgrader expansion) remains on schedule. A new $120 million cogeneration facility at the Sarnia complex is planned for start-up in April 2004.
• Liquidity: Cash and marketable securities decreased to $453 million from $872 million at year-end 2001, reflecting higher capital expenditures ($1.015 billion YTD) and lower operating cash flows compared to the prior year.
• Debt and Financing: Long-term debt increased to $1.541 billion. Favorable foreign exchange effects on U.S.-dollar denominated debt contributed to improved corporate earnings.
• Risks and Contingencies:
  • Market Volatility: Results are heavily dependent on commodity prices (oil, gas, chemicals) and refining margins.
  • Regulatory/Project Risk: The Mackenzie Gas Project is in the public consultation phase; regulatory approval and pipeline capacity are uncertain.
  • Accounting Changes: The company adopted FAS 142 (Goodwill) and FAS 144 (Impairment) effective Jan 1, 2002. FAS 143 (Asset Retirement Obligations) is effective Jan 1, 2003, and its impact is currently under evaluation.

Investor Verification Checklist

• Commodity Price Sensitivity: Verify current natural gas and crude oil prices against the reported averages ($3.36/MMBtu for gas; $40.06/barrel for crude in Q3) to assess future earnings potential.
• Refining Margins: Monitor industry refining margins, as the Petroleum Products segment swung from record profits to a loss YTD due to margin compression.
• Capital Expenditure Execution: Confirm the on-schedule status of the Cold Lake and Syncrude expansion projects, which represent significant future capacity.
• Liquidity Position: Review the cash balance of $453 million against the high capital expenditure run rate to ensure sufficient liquidity for ongoing operations and debt service.
• Share Repurchases: Note that no shares were repurchased in Q3 2002 under the current issuer bid, though $13 million was spent in the first half of the year.