Business Context and Reporting Period
This Form 10-Q covers the quarterly period ended June 30, 1995, for Public Service Enterprise Group Incorporated (Enterprise) and its principal subsidiary, Public Service Electric and Gas Company (PSE&G). Enterprise is a holding company engaged in electric and gas utility operations, oil and gas exploration, and real estate investments. The financial statements are unaudited but reflect normal recurring accruals.
Key Financial Metrics (Six Months Ended June 30, 1995)
| Metric | Enterprise (Consolidated) | PSE&G (Utility Subsidiary) |
|---|---|---|
| Total Operating Revenues | $3,005.1 million | $2,815.0 million |
| Net Income | $323.3 million | $318.2 million |
| Earnings Per Share (Enterprise) | $1.32 | N/A |
| Operating Cash Flow | $549.5 million | $492.5 million |
| Long-Term Debt | $5,235.4 million | $4,586.4 million |
| Short-Term Debt | $883.1 million (Commercial Paper/Loans) | $725.9 million (Commercial Paper/Loans) |
| Cash and Equivalents | $77.7 million | $38.1 million |
Material Changes vs. Prior Period
- Earnings Decline: Enterprise Net Income decreased by $36.8 million (10.2%) compared to the six months ended June 30, 1994. Earnings per share dropped from $1.47 to $1.32.
- Revenue Drivers: Total operating revenues decreased by $70.0 million. This was primarily driven by lower gas sales due to a milder winter and cooler spring (Degree days were 11.4% lower; THI Hours were 36.8% lower).
- Expense Variance: Fuel costs for electric generation increased by $92.9 million due to higher fuel prices and volumes, while gas purchased costs decreased by $114.3 million due to lower sales volumes.
- Cash Flow Improvement: Operating cash flow increased significantly by $254.9 million year-over-year, driven by greater recovery of electric and gas costs through adjustment clauses (LEAC/LGAC) and a net decrease in prepaid/accrued taxes.
- Asset Impairments: No property impairments were recorded in the current period, contrasting with a $77.6 million impairment recorded in the prior year's twelve-month period.
Outlook, Risks, and Management Commentary
Nuclear Operations and Regulatory Risks
- Salem Outage: Both Salem Nuclear Generating Station units (Units 1 and 2) are out of service for the remainder of 1995 due to equipment and management issues identified by the NRC. Restart is estimated for Q1 and Q2 of 1996. This outage is expected to result in a penalty of approximately $3 to $4 million under the Nuclear Performance Standard (NPS) and replacement power costs of ~$5 million per month per unit.
- Hope Creek: The NRC issued a Notice of Violation regarding an unplanned release of low-level radioactive materials in April 1995 and a subsequent event in July involving a valve positioning error. No fines were issued, but a special inspection team has been assigned.
- Performance Standard: PSE&G estimates the 1995 aggregate capacity factor for its five nuclear units will be approximately 63%, falling below the 65% minimum standard, triggering penalties.
Competition and Regulation
- Market Transition: Management notes increasing pressure from the transition to a competitive market environment, particularly for large industrial customers. FERC's proposed open access rules could fundamentally change the industry.
- Rate Matters: PSE&G has petitioned the BPU to recover $4.1 million in remediation costs. A stipulation was reached regarding a tariff modification for a major industrial customer.
Environmental and Contingencies
- Remediation Program: Costs for the Manufactured Gas Plant Remediation Program are estimated at $20 million annually for over 30 years. As of June 30, 1995, the estimated liability was $105.6 million.
- Bergen Station: Repowering was completed and synchronized to the grid in June 1995. Final costs are estimated at $350 million (excluding AFDC). Cost recovery depends on BPU authorization or competitive market sales.
Investor Verification Checklist
- Nuclear Restart Timeline: Verify the feasibility of the Q1/Q2 1996 restart dates for Salem Units 1 and 2 and the associated $17 million in additional operating expenses.
- Regulatory Penalties: Confirm the final calculation of the NPS penalty for 1995 and potential additional NRC enforcement actions regarding Hope Creek and Peach Bottom.
- Cost Recovery: Monitor BPU decisions on the recovery of the $350 million Bergen Station repowering costs and the $4.1 million remediation costs.
- Competitive Exposure: Assess the impact of FERC's open access rules and New Jersey's Energy Master Plan on PSE&G's ability to retain large industrial customers and recover stranded costs.
- Environmental Liabilities: Track the progress of the Manufactured Gas Plant Remediation Program and the potential for costs to exceed the current $105.6 million liability estimate.