Business Context and Reporting Period
Company: W&T Offshore, Inc.
Filing Type: Form 10-K (Annual Report)
Period Ended: December 31, 2004
Business Overview: W&T Offshore is an independent oil and natural gas acquisition, exploitation, and exploration company focused primarily in the Gulf of Mexico. The company operates in deepwater (water depths >500 feet) and deep shelf (well depths >15,000 feet) environments. As of December 31, 2004, the company held 467.5 Bcfe of proved reserves, with a PV-10 value of $1.47 billion.
Key Financial Metrics
| Metric (in millions, except per share) | 2004 | 2003 |
|---|---|---|
| Total Revenues | $508.7 | $422.6 |
| Net Income | $149.5 | $116.6 |
| Net Income Applicable to Common Shareholders | $148.6 | $110.7 |
| Diluted Earnings Per Share | $2.27 | $1.79 |
| EBITDA | $396.1 | $323.7 |
| Net Cash Provided by Operating Activities | $377.3 | $263.2 |
| Capital Expenditures | $284.8 | $203.4 |
| Long-Term Debt (Year-End) | $35.0 | $67.0 |
| Cash and Cash Equivalents (Year-End) | $65.0 | $4.0 |
| Shareholders' Equity | $359.9 | $214.5 |
Note: The company had a working capital deficit of $10.5 million at year-end 2004, which is permitted under its credit facility covenants.
Material Changes vs. Prior Period
- Revenue Growth: Total revenues increased 20.4% to $508.7 million, driven by a 28% increase in average realized oil prices ($36.77/bbl vs. $28.74/bbl) and a 10% increase in natural gas prices ($6.18/Mcf vs. $5.60/Mcf). Production volumes also increased slightly.
- Profitability: Net income rose 28.2% to $149.5 million. This was primarily due to higher commodity prices and volumes, partially offset by increased operating expenses and depreciation, depletion, and amortization (DD&A).
- Capital Spending: Capital expenditures increased 40% to $284.8 million, with significant allocation to exploration ($150.4 million) and development ($90.7 million). The company drilled 32 exploratory wells (21 successful) and 7 development wells (all successful).
- Liquidity: Cash and cash equivalents surged from $4.0 million to $65.0 million, funded by strong operating cash flows. Long-term debt decreased by $32.0 million as the company repaid borrowings.
- Reserves: Proved reserves increased to 467.5 Bcfe from 444.7 Bcfe in 2003, with 62% classified as proved developed.
Guidance, Outlook, and Risks
- 2005 Outlook: The company expects to spend $266 million on capital projects and $42 million on plug and abandonments/maintenance. It anticipates drilling 30 exploratory wells and five or more development wells.
- Dividends: The board declared a cash dividend of $0.02 per share in March 2005. The credit facility allows for annual dividends up to $30 million subject to financial tests.
- Market Risk: The company is highly sensitive to oil and natural gas price fluctuations. A 10% decline in realized prices would have reduced 2004 pre-tax income by approximately 22%.
- Operational Risks: Significant risks include the geographic concentration of assets in the Gulf of Mexico (exposure to hurricanes, as seen with Hurricane Ivan in 2004), the high cost and technical difficulty of deepwater drilling, and the inability to control development timing on non-operated properties (24% of undeveloped/non-producing reserves).
- Regulatory Risks: Operations are subject to extensive federal and state regulations regarding environmental protection, lease stipulations, and pipeline access. The company operates a platform in a National Marine Sanctuary, subjecting it to unique restrictions.
Investor Verification Checklist
- Reserve Accuracy: Verify the independent reserve report by Netherland, Sewell & Associates, Inc., particularly the classification of 38% of reserves as proved undeveloped and the associated development costs ($230.9 million estimated).
- Commodity Price Sensitivity: Assess the impact of potential price declines on the company's ability to fund its $266 million 2005 capital budget without additional financing.
- Non-Operated Assets: Review the status of the 24% of proved undeveloped/non-producing reserves operated by third parties, as the company cannot control the timing or cost of their development.
- Asset Retirement Obligations (ARO): Confirm the $142.4 million ARO liability and the assumptions used for discount rates and future abandonment costs.
- Concentration Risk: Evaluate the risk of losing major customers (BP Amoco, Shell Trading, ConocoPhillips accounted for over 60% of revenues in 2004) and the impact of pipeline constraints (e.g., the June 2005 pipeline shutdown mentioned in the filing).