Energy and utilities cases in consulting interviews fall into six recurring archetypes. Based on our analysis of 200+ energy cases across firm libraries, these six patterns account for roughly 85% of all energy-sector questions candidates encounter. Knowing which archetype you face — and the sector-specific twist each one carries — is the difference between a generic answer and one that demonstrates real industry fluency.
This guide complements our energy transition strategy overview and utilities regulatory deep-dive by giving you a practical solving playbook organized by case type.
The Six Energy Case Archetypes at a Glance
| Archetype | Frequency | Sector Twist | Typical Client |
|---|---|---|---|
| Renewable investment evaluation | ~25% | LCOE analysis + policy risk | Utility or energy developer |
| Utility rate case / profitability | ~20% | Regulated return mechanics | Regulated utility |
| Oil & gas cost optimization | ~15% | Upstream vs. midstream economics | E&P or integrated major |
| Energy M&A due diligence | ~15% | Asset valuation under commodity uncertainty | PE fund or strategic acquirer |
| Grid modernization / capex allocation | ~10% | Rate base growth + reliability metrics | T&D utility |
| Market entry into new energy segment | ~10% | Regulatory barriers + technology readiness | Diversified energy company |
Archetype 1: Renewable Investment Evaluation
This is the most common energy case archetype in our experience. The prompt typically asks: “Should the client invest in a 200 MW solar/wind project?”
flowchart TD
A[Should client invest in renewable project?] --> B{Levelized Cost of Energy}
B --> C[Capital cost per MW]
B --> D[Capacity factor]
B --> E[O&M costs over asset life]
A --> F{Revenue certainty}
F --> G[PPA contract available?]
F --> H[Merchant price exposure]
F --> I[Renewable energy credits]
A --> J{Policy & permitting risk}
J --> K[Tax credits / ITC / PTC]
J --> L[Interconnection queue position]
J --> M[Local permitting timeline]
Key metrics to calculate:
- LCOE (Levelized Cost of Energy): Total lifetime cost / total lifetime MWh output. Solar ranges $25-50/MWh; onshore wind $30-55/MWh in most markets.
- Capacity factor: Actual output vs. theoretical maximum. Solar ~20-30%; onshore wind ~30-45%; offshore wind ~40-55%.
- IRR threshold: Most energy developers require 8-12% unlevered IRR; PE-backed sponsors push for 12-15%.
Common candidate mistake: Treating renewable projects like consumer products with 3-year paybacks. These are 25-30 year infrastructure assets. The interviewer wants you to think in terms of long-duration cash flow certainty, not short-term ROI.
Practice prompt: “A utility client is evaluating a 150 MW onshore wind farm requiring $180M capex. The expected capacity factor is 35%, and local wholesale prices average $45/MWh. A 15-year PPA at $38/MWh is available. Should they proceed?”
Archetype 2: Utility Rate Case / Profitability
Regulated utilities earn a guaranteed return on their rate base — the total value of assets approved by regulators. When profitability is declining, the answer almost always connects to the regulatory formula.
The regulatory equation you must know:
Revenue Requirement = (Rate Base × Allowed ROE) + Operating Expenses + Depreciation + Taxes
| Profit Driver | What Moves It | Typical Interview Angle |
|---|---|---|
| Rate base | Capital investment in approved assets | “Client invested $2B in grid upgrades but earnings haven’t grown” |
| Allowed ROE | Regulatory proceedings (every 3-5 years) | “Client’s authorized ROE dropped from 10.5% to 9.2%” |
| Regulatory lag | Time between cost incurrence and rate adjustment | “Costs rose 8% but rates won’t reset for 18 months” |
| Load growth | Customer additions and usage per customer | “Residential usage declining 2% annually due to rooftop solar” |
Solving approach: Start by asking whether the issue is on the revenue formula side (rate base, ROE, load) or the cost side (O&M efficiency, procurement). In our experience, 70% of utility profitability cases involve regulatory lag or declining load — not operational waste.
For deeper coverage of rate case mechanics, see our utilities regulatory guide.
Archetype 3: Oil & Gas Cost Optimization
These cases typically feature an upstream producer whose margins have compressed due to commodity price declines. The interviewer expects you to understand the specific cost structure of extraction operations.
Cost breakdown for a typical onshore oil producer:
| Cost Category | % of Total | Key Levers |
|---|---|---|
| Lifting costs (LOE) | 25-35% | Well optimization, artificial lift efficiency |
| Drilling & completion | 20-30% | Lateral length, completion design, rig rates |
| Gathering & processing | 15-20% | Midstream contracts, pipeline access |
| G&A / overhead | 10-15% | Headcount, field office consolidation |
| Royalties & taxes | 10-15% | Largely fixed, but some mineral rights negotiable |
Sector-specific insight: Unlike manufacturing cases where you look for “quick wins” across all categories, oil & gas cost optimization has a critical sequencing constraint — you cannot reduce lifting costs on wells that aren’t producing economically. The first question is always: “Which wells should we shut in vs. optimize?”
Practice prompt: “Your client operates 800 wells in the Permian Basin with an average breakeven of $52/barrel. WTI is at $48. How would you approach reducing the breakeven by $8/barrel within 12 months?”
Archetype 4: Energy M&A Due Diligence
Energy acquisitions involve unique valuation challenges because asset value depends heavily on commodity price assumptions, remaining reserve life, and regulatory approvals.
flowchart LR
A[Energy M&A Evaluation] --> B[Asset quality]
A --> C[Synergy potential]
A --> D[Regulatory approval risk]
B --> B1[Reserve life / resource quality]
B --> B2[Asset age & maintenance backlog]
B --> B3[Contract portfolio PPA/offtake]
C --> C1[Operational synergies]
C --> C2[Geographic overlap]
C --> C3[Portfolio complementarity]
D --> D1[Antitrust / market concentration]
D --> D2[State utility commission approval]
D --> D3[FERC jurisdiction]
Valuation approaches by asset type:
- Renewable assets: DCF based on contracted cash flows (PPA terms) + terminal value for merchant tail
- Utility: Rate base multiple (typically 1.3-1.8x rate base for regulated utilities)
- Oil & gas reserves: $/BOE of proved reserves, benchmarked against recent transactions
- Midstream/pipeline: EBITDA multiple (8-12x for fee-based, contracted assets)
Common candidate mistake: Applying a standard DCF without stress-testing commodity assumptions. The interviewer will often ask: “What if oil drops to $40? What if the PPA counterparty defaults?” Always build a downside scenario.
Archetype 5: Grid Modernization / Capex Allocation
These cases ask how a utility should prioritize billions in potential infrastructure investments across competing needs: aging infrastructure replacement, renewable interconnection, EV charging, storm hardening, and smart grid technology.
Prioritization framework:
| Criterion | Weight | Metric |
|---|---|---|
| Reliability impact | High | SAIDI/SAIFI improvement per $M invested |
| Regulatory recoverability | High | % of spend likely approved for rate base inclusion |
| Customer benefit | Medium | Avoided outage cost, bill reduction |
| Policy alignment | Medium | State clean energy mandate progress |
| Execution risk | Low (tiebreaker) | Workforce availability, permitting complexity |
Key metrics interviewers expect you to know:
- SAIDI: System Average Interruption Duration Index (minutes of outage per customer per year). US average: ~120 min; top-quartile utilities achieve <60 min.
- Rate base growth: Annual increase in regulated asset base. Typical target: 6-8% CAGR for utilities with large capex programs.
- Regulatory compact: The implicit agreement that utilities invest in reliable infrastructure in exchange for a guaranteed return. Break this concept into the interview and you signal deep sector understanding.
Archetype 6: Market Entry into New Energy Segment
A traditional energy company wants to enter an adjacent segment — typically a fossil fuel company moving into renewables, a utility launching an unregulated retail business, or an energy trader entering storage/batteries.
Entry evaluation matrix:
quadrantChart
title Energy Market Entry: Capability Fit vs. Market Attractiveness
x-axis Low Market Attractiveness --> High Market Attractiveness
y-axis Low Capability Fit --> High Capability Fit
quadrant-1 Develop capabilities first
quadrant-2 Priority entry
quadrant-3 Avoid
quadrant-4 Partner or acquire
Utility-scale solar: [0.75, 0.6]
Residential solar: [0.5, 0.25]
Battery storage: [0.8, 0.4]
Hydrogen: [0.4, 0.3]
EV charging: [0.65, 0.45]
Offshore wind: [0.7, 0.7]
Questions to structure your analysis:
- Regulatory barriers: Does entry require licenses, utility commission approval, or environmental permits? Timeline?
- Technology readiness: Is the technology commercially proven at the client’s target scale?
- Capability transfer: What existing capabilities (land rights, grid interconnection expertise, commodity trading) give the client an advantage?
- Capital requirements: How much upfront investment vs. the client’s balance sheet capacity?
- Competitive landscape: Who already operates in this segment and what is their cost position?
For a broader market entry framework applicable across industries, see our market entry case framework guide.
Sector-Specific Mental Math You Need
Energy cases require comfort with large numbers and industry-standard conversion factors. Memorize these before your interview:
| Conversion | Value | Use Case |
|---|---|---|
| 1 MW solar output | ~2,000 MWh/year (at 23% CF) | Sizing renewable project revenue |
| 1 MW wind output | ~3,000 MWh/year (at 34% CF) | Sizing renewable project revenue |
| Typical household consumption | ~10,000 kWh/year (US) | Converting MW to “homes served” |
| 1 barrel of oil energy equivalent | ~1,700 kWh | Comparing across fuel types |
| Utility capex per customer | $1,500-3,000/year | Benchmarking utility investment levels |
Key Takeaways
- Energy cases cluster into six predictable archetypes; identifying which one you face in the first 60 seconds lets you deploy the right sector-specific framework immediately.
- Regulated utilities follow a mechanical revenue formula — always start there before investigating operational issues.
- Renewable investment cases hinge on LCOE, capacity factor, and revenue certainty (PPA vs. merchant exposure) rather than simple ROI calculations.
- Oil & gas cost cases require understanding the well-level shut-in decision before optimizing operations across the portfolio.
- Energy M&A valuations depend entirely on the asset type: rate base multiples for utilities, $/BOE for reserves, DCF on contracted cash flows for renewables.
- Grid modernization is a capital allocation problem where regulatory recoverability and reliability metrics drive prioritization.
Put Your Energy Sector Knowledge to the Test
Ready to practice these archetypes under realistic conditions? Explore energy industry cases in our case library, then test your approach with an AI Mock Interview that adapts difficulty based on your responses. Pair this guide with our profitability framework and operations case framework for the analytical foundations that underpin most energy case structures.