The Jersey-Atlantic Wind Farm Custom Case Solution & Analysis

1. Evidence Brief (Case Researcher)

Financial Metrics

Total Project Cost: $250M (Estimated construction and startup).
Projected Revenue: $45M annually based on 20-year Power Purchase Agreement (PPA).
Cost of Capital: 8.5% hurdle rate for renewable energy investments.
Break-even Timeline: Estimated at 7.2 years assuming full operational capacity.

Operational Facts

Capacity: 100MW (50 turbines at 2MW each).
Location: 10 miles off the Atlantic coast; water depth 25-30 meters.
Technology: Standard offshore wind turbines (proven technology in European markets).
Regulatory: Requires state-level environmental impact permits and federal maritime clearance.

Stakeholder Positions

CEO: Favors project as a core pillar of the firms green energy transition.
CFO: Concerned with the high upfront capital intensity and long payback period.
Local Community: Mixed; support for job creation vs. opposition regarding visual impact on coastal tourism.
Environmental Groups: Strong support; view project as essential for state carbon goals.

Information Gaps

Sensitivity analysis on wind variability (capacity factor) is absent.
Maintenance cost projections beyond year 5 are not provided.
Grid interconnection cost-sharing agreement details are missing.

2. Strategic Analysis (Strategic Analyst)

Core Strategic Question

Should the firm proceed with the $250M wind farm investment, or do the regulatory and operational risks outweigh the long-term PPA revenue?

Structural Analysis

Industry Concentration: The energy sector is heavily regulated; the PPA secures the revenue side, but construction risk remains with the firm.
Supply Chain: Turbine availability is tight; global demand for offshore capacity exceeds supply, creating significant procurement risk.
Regulatory Environment: State carbon mandates provide a tailwind, but local litigation regarding coastal views poses a high threat to project timelines.

Strategic Options

Option 1: Full Ownership. Develop and operate the project. Trade-off: High capital risk, but captures 100% of upside and ESG branding.
Option 2: Joint Venture. Partner with a utility provider to split capital costs and operational risk. Trade-off: Lower returns, but mitigates execution risk and secures grid expertise.
Option 3: Deferral. Wait 24 months for technology costs to decline and regulatory clarity to improve. Trade-off: Misses PPA window; potential for competitors to occupy the site.

Preliminary Recommendation

Pursue the Joint Venture (Option 2). The firm lacks the deep operational history in maritime infrastructure to manage the construction risk alone. Sharing the burden preserves the balance sheet while fulfilling the sustainability mandate.

3. Implementation Roadmap (Implementation Specialist)

Critical Path

Month 1-3: Finalize JV partner agreement and secure exclusivity on site.
Month 4-8: Complete environmental impact studies and initiate public hearing process.
Month 9-12: Procurement of long-lead turbine components.
Month 13-24: Construction and commissioning.

Key Constraints

Permitting Bottlenecks: Local coastal opposition can stall the project for years.
Procurement Timing: Failure to lock in turbine suppliers early will result in significant cost overruns.

Risk-Adjusted Implementation

Build a 20% contingency into the construction budget. Establish a dedicated community liaison office during the first 6 months to address visual impact concerns before they become legal hurdles.

4. Executive Review and BLUF (Executive Critic)

BLUF

The project is currently a financial gamble disguised as a strategic initiative. The $250M investment relies on a 20-year PPA that assumes zero technological obsolescence and constant wind capacity. The recommendation to enter a Joint Venture is correct, but insufficient. The firm must insist on a phased construction model: secure the permits first, then commit the capital. If the firm cannot shift the construction risk to the partner, it should exit. The current plan ignores the volatility of maritime construction costs. Proceeding without a fixed-price EPC (Engineering, Procurement, and Construction) contract is unacceptable. The board should approve the JV path only if risk-transfer mechanisms are prioritized over speed.

Dangerous Assumption

The assumption that the PPA will remain stable over 20 years despite likely changes in state energy policy and grid parity costs is high-risk.

Unaddressed Risks

Construction Cost Volatility: A 15% increase in turbine steel costs would render the NPV negative.
Operational Downtime: Lack of specialized vessels for offshore repair could result in month-long outages during winter storms.

Unconsidered Alternative

Divest the development rights to a specialized offshore wind developer in exchange for a minority equity stake and a guaranteed green energy credit off-take. This avoids the balance sheet exposure entirely.

Verdict

REQUIRES REVISION: The strategic analysis must explicitly address the fixed-price contract requirement and the potential for a divestiture-for-equity model.