The best way to understand governance is through concrete examples. These hypothetical scenarios illustrate common decision-making situations token holders face, with realistic trade-offs based on current industry economics. Each scenario presents options with pros and cons, allowing you to practice evaluating proposals.
📖 How to Use These Scenarios
These are teaching examples based on realistic renewable energy economics (2024 data). Project parameters like LCOE ($29-92/MWh for solar, $27-73/MWh for wind[3]), capacity factors (solar 21-34%, wind 33-47%[4]), and IRR ranges (8-13%[8]) reflect actual industry standards. Consider each scenario, decide how you'd vote, then read the analysis.
Scenario 1: Technology Diversification vs. Concentration
Situation:
The DAO has $25M to deploy. Two proposals emerge:
| Option | Project A | Project B |
|---|---|---|
| Technology | 50MW Solar (Arizona) | 30MW Wind (Texas) |
| Capital Cost | $25M ($0.50/W) | $25M ($0.83/W) |
| LCOE | $32/MWh | $38/MWh |
| Capacity Factor | 28% | 42% |
| Expected IRR | 11.5% | 9.8% |
| Risk Profile | Low (mature tech, strong sun) | Medium (equipment complexity) |
| PPA Status | 15-year signed | 12-year signed |
Key Trade-offs:
- Higher returns vs. diversification: Solar offers better IRR, but wind adds technology diversity
- Production patterns: Solar produces during day peaks; wind often produces at night
- Geographic risk: Concentrating in one state vs. spreading across regions
- Learning opportunity: Wind operational experience could inform future projects
Stakeholder Perspectives:
- Return-focused investors: Favor solar for higher IRR and lower risk
- Long-term strategists: Favor wind for portfolio diversification
- Environmental advocates: Favor wind for better capacity factor (more total generation)
Decision Framework:
Consider the DAO's current portfolio. If this is the first project, solar's lower risk makes sense. If the DAO already has solar projects, wind diversification becomes more attractive despite slightly lower IRR. The 2-3% IRR difference may be worth the risk reduction from diversification.
Scenario 2: Project Size and Economies of Scale
Situation:
The DAO has $40M available. Should we fund one large project or multiple smaller ones?
| Aspect | Option A: Single Large Project | Option B: Three Smaller Projects |
|---|---|---|
| Configuration | 100MW solar farm (California) | 25MW solar (AZ) + 30MW wind (TX) + 15MW solar (NV) |
| Total Cost | $40M | $41M (2.5% premium) |
| Avg LCOE | $30/MWh | $34/MWh |
| Expected IRR | 12.2% | 10.5% |
| Development Risk | High (single point of failure) | Lower (risk spread across projects) |
| Timeline | 18 months to operation | 12-20 months (staggered) |
| Geographic Risk | Concentrated in CA (regulatory risk) | Spread across 3 states |
Key Trade-offs:
- Economies of scale: Large project has 13% lower LCOE due to bulk equipment purchasing
- Execution risk: If large project fails permitting, entire capital is delayed
- Market exposure: California has aggressive renewable policies but higher regulatory risk
- Cash flow timing: Smaller projects come online at different times, starting distributions earlier
Analysis:
Research shows economies of scale in renewables are more complex than traditional industries[9]. While a 100MW project enjoys cost advantages in equipment and construction through bulk purchasing and larger-scale operations, it faces higher development risks, more complex permitting, and concentration risk. Industry experience suggests large projects often face greater permitting challenges than smaller projects, though specific failure rates vary by jurisdiction and project type.
Suggested approach: If this is the DAO's first major deployment, the diversified option (Option B) reduces risk despite lower IRR. Once the DAO has operational experience and proven processes, larger projects become more attractive.
Scenario 3: Distribution Policy - Growth vs. Income
Situation:
Three projects are now operational, generating $3.2M annually after expenses. How should revenue be allocated?
| Approach | Option A: Reinvest | Option B: Distribute | Option C: Hybrid |
|---|---|---|---|
| Distribution to Token Holders | $0 (0%) | $3.2M (100%) | $1.6M (50%) |
| Reinvestment for New Projects | $3.2M | $0 | $1.6M |
| Immediate Yield (on $50M portfolio) | 0% | 6.4% | 3.2% |
| Projected 5-Year Portfolio Growth | $50M → $100M | $50M (no growth) | $50M → $70M |
| 5-Year Total Distributions | $0 for 5 years, then $6.4M/yr | $16M over 5 years | $8M over 5 years, $4.5M/yr after |
Stakeholder Perspectives:
- Income-seeking investors: Prefer Option B (immediate distributions)
- Growth investors: Prefer Option A (compound growth)
- Balanced approach: Prefer Option C (distributions + growth)
Analysis:
This classic growth vs. income trade-off has no universally correct answer—it depends on investor base and market conditions. However, many successful renewable energy funds use a tiered approach:
- Years 1-3: Reinvest 80-100% for rapid portfolio growth
- Years 4-7: Transition to 50-50 split
- Years 8+: Increase distributions to 70-80% as growth slows
For a young DAO, Option A or C makes strategic sense to build portfolio scale. Once the portfolio reaches critical mass ($100M+), shifting toward distributions rewards early supporters.
Scenario 4: Risk vs. Return - Merchant vs. Contracted
Situation:
A developer offers two versions of the same 40MW wind project:
| Aspect | Option A: PPA Contracted | Option B: Merchant |
|---|---|---|
| Revenue Model | 15-year PPA at $45/MWh | Sell into market (avg $52/MWh) |
| Expected IRR | 9.2% | 14.5% |
| Revenue Certainty | 100% for 15 years | Fluctuates with market prices |
| Downside Scenario (low prices) | 9.2% IRR (unchanged) | 4.2% IRR (if prices drop to $35/MWh) |
| Upside Scenario (high prices) | 9.2% IRR (unchanged) | 22.8% IRR (if prices rise to $65/MWh) |
| Financing | 70% debt available (due to PPA) | 50% debt available (higher risk) |
Key Considerations:
- Market outlook: Electricity prices rising (energy transition, electrification) or falling (overcapacity)?
- Risk tolerance: Can token holders handle volatile distributions?
- Portfolio position: If DAO has mostly contracted projects, adding merchant exposure increases overall returns
- Leverage impact: PPA allows 40% more debt, improving equity returns
Analysis:
Industry observations suggest merchant renewable projects can potentially achieve higher IRR than PPA projects during periods of rising electricity prices, but with significantly higher volatility (2-3x). The key question: does the DAO's token holder base prefer stable distributions or higher expected returns with volatility?
Recommended approach: For a DAO's first few projects, PPA contracts provide stability and allow higher leverage. Once portfolio reaches 100+ MW with stable cash flows, adding 20-30% merchant exposure can boost returns without excessive risk.