Business Context and Reporting Period
This Form 10-Q covers Enron Oil & Gas Company for the quarterly and nine-month periods ended September 30, 1995. The registrant is an exploration and production company engaged in natural gas, crude oil, condensate, and natural gas liquids operations, primarily in North America, Trinidad, and India. The financial statements are unaudited.
Key Financial Metrics
| Metric (Nine Months Ended Sept 30, 1995) | Value ($ in Millions) |
|---|---|
| Net Operating Revenues | 492.3 |
| Net Income | 110.7 |
| Earnings Per Share (Diluted) | $0.69 |
| Net Operating Cash Inflows | 229.2 |
| Discretionary Cash Flow | 387.0 |
| Total Assets | 2,109.9 |
| Long-Term Debt (Other) | 247.6 |
| Cash and Cash Equivalents | 8.5 |
Operating Margins: Operating income for the nine months ended September 30, 1995, was $154.1 million, representing an operating margin of approximately 31.3% on net operating revenues. Net income margin was approximately 22.5%.
Material Changes vs. Prior Period
- Revenue: Net operating revenues increased 3.8% to $492.3 million for the nine months ended September 30, 1995, compared to $474.3 million in 1994. This increase was driven by a 55% rise in crude oil/condensate volumes and significant gains from commodity price hedging ($51 million gain in 1995 vs. $2 million loss in 1994), which offset a 27% decline in average wellhead natural gas prices.
- Net Income: Net income increased 5.0% to $110.7 million from $105.4 million in the prior year period.
- Expenses: Total operating expenses decreased 1.8% to $338.2 million. Depreciation, Depletion, and Amortization (DD&A) decreased $24 million to $157.9 million due to a lower average DD&A rate ($0.69/Mcfe vs. $0.81/Mcfe) driven by a higher mix of lower-cost international production.
- Cash Flow: Net operating cash inflows decreased 23.8% to $229.2 million from $300.9 million, primarily due to lower revenues, higher working capital requirements, and reduced tax credit benefits.
- Capital Expenditures: Exploration and development expenditures increased to $405 million from $354 million, largely due to $114 million in property acquisitions in 1995 compared to $14 million in 1994.
Guidance, Outlook, and Risks
- Hedging Strategy: As of October 23, 1995, the company hedged approximately 381 MMcf/d of North America natural gas volumes for the remainder of 1995 and 504 MMcf/d for 1996. Crude oil hedges covered approximately 10,100 Bbl/d for late 1995 and 9,600 Bbl/d for 1996. These hedges are designed to enhance revenue certainty.
- Production Curtailment: The company voluntarily curtailed U.S. wellhead natural gas volumes due to significantly lower market prices, averaging 140 MMcf/d curtailment in the first nine months of 1995.
- Accounting Risks: The company is evaluating the impact of SFAS No. 121 (Impairment of Long-Lived Assets). Preliminary evaluation suggests potential non-cash impairment charges ranging from $5 million to $60 million upon adoption in 1996.
- Legal Contingencies: A significant lawsuit filed by TransAmerican Natural Gas Corporation in 1992 was settled in October 1995. Management states the settlement will not have a materially adverse effect on financial condition.
- Liquidity: Management believes net operating cash flow and available financing alternatives are sufficient to fund requirements for the remainder of 1995. The company maintains significant flexibility in adjusting its capital expenditure budget.
Investor Verification Checklist
- Hedging Exposure: Verify the specific terms and counterparty risks associated with the extensive commodity price swap agreements (approx. 400-500 BBtu/d natural gas and 10,000 Bbl/d crude) entered into late 1995.
- Impairment Charges: Monitor the final assessment of SFAS No. 121 adoption in 1996, as potential charges could range up to $60 million.
- Volume vs. Price Sensitivity: Assess the impact of continued low natural gas prices on the company's strategy to curtail U.S. production versus international growth.
- Acquisition Valuation: Review the $114 million in property acquisitions completed in the first nine months of 1995 to ensure the cost per Mcfe ($0.53) aligns with long-term reserve replacement value.
- Debt Structure: Note the classification of commercial paper and uncommitted bank lines ($100 million total) as long-term debt based on intent to refinance; verify the company's ability to roll over these obligations.