Can PJM Handle Virginia's Data Centers?
PJM serves 67 million people across 13 states. Capacity market prices went from $29 to $333/MW-day in three years. The latest auction had a 6,623 MW shortfall — the first in PJM's history. Data centers account for 94% of projected load growth. We asked five questions in sequence — each answer built on the last.
The simulation ran once. Every downstream question built on what it produced.
Five Models, Five Different Answers
Five analyses of the same grid. The only thing that changes is how much reality you include. The “safe” data center capacity drops from unlimited to zero. The investment recommendation goes from nothing to impossible.
| Level | Method | Answer | Investment Recommendation |
|---|---|---|---|
| Screening | Annual energy balance | No limit | None needed |
| Deterministic dispatch | 8,760-hour simulation, 2024 profiles | 19 GW | +12 GW gas ($13B) |
| 9-year Monte Carlo | Same dispatch, 9 weather years | 14–24 GW range | +20 GW gas ($22B) |
| 200-draw stochastic MC | Weather + forced outages | 5 GW at P90 | +20 GW gas achieves only 42% reliability |
| Stress scenario | Dec 2022 profiles + confirmed outage rates | Grid fails at 0 GW DC | No feasible investment prevents failure at Elliott severity |
Each level uses the same underlying dispatch engine. The only changes are inputs: temporal resolution, weather sample size, outage modeling, and scenario selection.
Five Questions, One Chain
Each answer enabled the next question. One simulation, five answers — each building on the last.
At What Load Does the Grid Break?
Tipping point 14–24 GW across weather years. Monte Carlo changed the investment requirement by 67% ($9B). Battery storage has zero impact.
Can PJM Survive Another Elliott?
Gas vulnerability surface: at 30% curtailment the grid fails at 0 DC. Dominion zone breaks in 9/9 weather years. 22 million people at risk.
What Happens to Consumer Rates?
Rate impact $1–17/MWh. Interruptibility is at least 5x cheaper than gas — in every weather year tested. 18% DC curtailment for 1.2% of hours.
When Do Data Centers Leave the Grid?
Self-gen already cheaper ($65 vs $102/MWh). Grid-connected PPA eliminates reliability problem. BTM taking nuclear makes it worse.
What Is Demand Response Actually Worth?
1 GW of DR is worth $122M/year in avoided capacity costs — zero capital, immediate impact. At 30% curtailment across 10 GW of DC load, demand response extends the tipping point by ~5 years. Dominates self-gen economics for DCs with schedule flexibility.
What Changed at Each Step
Each escalation doesn’t just refine the number — it changes the nature of the answer. The question itself shifts.
Annual energy balance hides temporal mismatch. There’s enough energy in aggregate — just not at 6 PM on August 14th. Hourly dispatch reveals the gap.
Weather year selection swings the answer by 10 GW. A single year gives a single number. Nine years reveal the range — and show that planning to the best year is gambling.
Forced outages are correlated with stress. When temperatures spike, generators trip — exactly when you need them most. The 9-year MC assumed all capacity was always available. It wasn’t.
The grid’s vulnerability is structural. Winter Storm Elliott profiles with confirmed outage rates show the grid fails with zero data center load. The problem isn’t future demand — it’s current fragility.
| Step | What Changed | Dollar Impact |
|---|---|---|
| Screening → Dispatch | Revealed the problem exists | $0 → $13B+ |
| Dispatch → 9-Year MC | Increased investment requirement by 67% | +$9B |
| 9-Year → Stochastic MC | Showed +20 GW gas still inadequate | Investment exceeds gas alone |
| Stochastic → Stress | Reframes the problem entirely | From “build more” to “build differently” |
What Drives the Answer?
Across four investigations, three inputs dominate. One widely-discussed solution has zero effect.
When coal plants close determines whether the grid has enough dispatchable backup to survive peak stress events.
Correlated with temperature extremes. The generators most needed are the ones most likely to fail.
Flexible data center load and grid-wide DR programs can absorb peaks that would otherwise cause blackouts. 1 GW = $122M/year in avoided capacity costs.
Adds energy but not reliable capacity. Helps in average conditions, absent during stress events.
At current deployment levels, battery storage contributes effectively zero to multi-day reliability events. The duration problem — hours of storage vs. days of stress — makes batteries irrelevant to the capacity question.
The parameters that don’t matter are as important as the ones that do. Battery storage is the most-discussed solution in energy policy. In this analysis, it contributes zero hours of reliability improvement. Coal retirement timing — rarely discussed in the data center debate — swings reliability by 558 hours. The sensitivity analysis tells you where to look — and where to stop looking.
Seven Findings, Seven Checks
Each model prediction compared against publicly available real-world data.
Elliott Confirmation
Winter Storm Elliott (December 2022) was the real-world stress test for our outage rate assumptions. Our model used 32% gas forced outage rate and 15% coal forced outage rate during extreme cold events.
FERC and NERC's joint inquiry confirmed the actual numbers: 37% for gas and ~16% for coal. Both were worse than what our model assumed.
The model is not pessimistic — it’s optimistic. Real gas outage rates are higher (37% vs. 32%), the capacity shortfall appeared earlier (at 5 GW, not 19 GW), and queue completion rates (5%) are far below what the planned fleet scenarios assume. Every assumption we made was generous to the grid. Reality is worse. The conclusions from this study should be read as lower bounds on the actual risk.
Capacity Auction Trajectory
PJM's Base Residual Auction results tell the story in dollars and megawatts.
| Delivery Year | Clearing Price | Reserve Margin | Target | Shortfall |
|---|---|---|---|---|
| 2024/25 | $28.92/MW-day | 20.4% | ~17–20% | None |
| 2025/26 | $269.92/MW-day | 18.5% | 17.8% | None (barely) |
| 2026/27 | $329.17/MW-day | 18.9% | 19.1% | 309 MW |
| 2027/28 | $333.44/MW-day | 14.9% | 20.0% | 6,623 MW |
What This Doesn't Model
Every model has a boundary. These are ours.
No Intra-Zone Transmission
The model treats each PJM zone as a single node. Transmission constraints within zones — which can strand capacity or strand load — are not captured. Local reliability problems may be worse than the system-level numbers suggest.
Queue Completion at Historical Rates
New generation is modeled at the current 5% interconnection queue completion rate. If permitting or interconnection reform accelerates, the capacity shortfall timeline shifts. The model is a baseline, not a forecast.
No Market Behavior Response
Generators and data center operators are treated as price-takers. In reality, the 10x price increase in capacity markets will trigger investment and behavioral responses that the model doesn’t capture. This is a structural stress analysis, not an equilibrium model.
No Compound Multi-Week Events
Weather scenarios are drawn from historical records. A compound event — two consecutive polar vortex weeks, or a summer heatwave following a wet spring that fills reservoirs and limits hydro — is not represented. Tail risk is likely understated.
Storage and DR at Current Deployment
Battery storage and demand response are modeled at 2024 deployment levels. Future buildout scenarios are not included. The “storage = zero” finding is specific to the current fleet, not a statement about storage at scale.
Scheduled Retirements as Given
Coal and gas retirements follow announced schedules. Regulatory delays, market signals, or policy changes could accelerate or defer retirements in ways the model doesn’t anticipate.
What the Analysis Supports
Five conclusions grounded in validated, bounded analysis. Each is traceable to a specific finding.
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01
Gate coal retirements on firm replacement capacity
Coal retirement timing is the #1 sensitivity driver (558 hours of reliability impact). Retiring before firm replacement is in service is the single largest avoidable risk in the current grid transition. This is not an argument against retiring coal — it is an argument for sequencing.
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02
Require and verify gas winterization
FERC mandated winterization after Elliott. Real gas EFOR during Elliott was 37% — 5 points above our model assumption, and above what FERC’s own post-Elliott standards require. Mandate compliance monitoring with actual performance data, not self-certification.
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03
Enable data center interruptibility as a grid resource
Interruptibility is at least 5x cheaper than gas in every weather year tested. 18% DC curtailment for 1.2% of operating hours is an operational constraint that hyperscale operators can manage. The policy and market structures to formalize this don’t yet exist at scale.
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04
Don’t count battery storage toward near-term reliability targets
200 GWh of storage had zero reliability impact in this analysis. Storage requires adequate renewables to charge from; at current grid composition, the correlation problem (generation shortfalls happen when storage is already depleted) makes batteries irrelevant to the multi-day reliability question. Plan storage as energy arbitrage, not reliability insurance.
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05
Plan to the stochastic distribution, not the deterministic answer
The deterministic answer (19 GW) underestimates the investment requirement by $9B. Planning authorities, interconnection policy, and capacity market design should all use stochastic analysis as the baseline standard. The cost of the Monte Carlo is 10 minutes of compute. The cost of skipping it is $9 billion.
Explore the Data
Build your own policy scenario and see how the grid responds.
Sources
All data comes from publicly available regulatory filings, market reports, and independent analyses.
- 1PJM Interconnection — Base Residual Auction Results (2024/25 through 2027/28 delivery years)
- 2FERC/NERC — Joint Inquiry into Winter Storm Elliott (2023), generator forced outage analysis
- 3PJM Interconnection — Energy Transition in PJM: Frameworks for Analysis (2023), retirement and queue completion data
- 4PJM Independent Market Monitor (Monitoring Analytics) — State of the Market Report, capacity cost attribution
- 5Grid Strategies — The Era of Flat Power Demand is Over (2023), data center load growth projections
- 6Institute for Energy Economics and Financial Analysis (IEEFA) — PJM capacity market analysis
- 7PJM Interconnection — 2025 Load Forecast Report, data center demand projections (32 GW, 94% DC-driven)
- 8PJM Interconnection — Effective Load Carrying Capability (ELCC) and Reserve Requirement Study
5 questions, 5 fidelity levels, 200 stochastic draws, 9 weather years, 26 data files, 13 Python modules, validated against PJM auction data and FERC/NERC reports.