US Energy Market Performance Analytics: Power BI Dashboard

Total Revenue

$522M

2-year portfolio

All 5 regions

Total Demand

11,986 GWh

Across 6 sources

Avg Price / MWh

$42.33

Blended portfolio rate

Renewable Share

27.2%

Target: ≥ 30%

2.8% below target

Outage Events

242

Target: < 150

▲ 61% above target

Revenue by Region ($M) All 5 regions nearly equal

Energy Mix: Renewable vs Non-Renewable Demand share %

Portfolio Finding: Revenue is evenly distributed across all 5 regions ($102–108M each), indicating a well-diversified geographic portfolio. However, the renewable share of 27.2% remains 2.8 percentage points below the 30% target, and outage events (242) are 61% above the 150-event threshold. The Southwest and West regions represent the highest outage frequency and should be prioritized for grid resilience investment.

Revenue by Energy Source ($M) Natural Gas dominates at $235M

Price vs CO₂ Intensity by Source Carbon-adjusted cost analysis

Source Performance Scorecard Revenue, price, CO₂, efficiency rating

Source	Type	Revenue ($M)	Avg Price/MWh	CO₂ Tons	Efficiency
Natural Gas	Non-Renewable	$234.8	$54.10	1,765	HIGH
Coal	Non-Renewable	$110.6	$45.14	1,945	MOD
Nuclear	Non-Renewable	$85.6	$38.47	0	HIGH
Solar	Renewable	$46.1	$30.13	0	LOW
Wind	Renewable	$31.1	$26.27	0	MOD
Hydro	Renewable	$14.1	$22.22	6	MOD

Carbon-Adjusted Cost Finding: Coal shows the lowest nominal price at $45/MWh, but at a carbon cost of $50/ton (EU ETS proxy), coal's effective cost rises to ~$87/MWh, making it more expensive than Natural Gas ($54) and Nuclear ($38). This single insight reframes the entire dispatch optimization model and supports an economic (not just regulatory) case for coal-to-renewable transition.

Current Renewable Share

27.2%

2-year avg

2.8% gap to 30% target

Renewable CO₂

0 T/GWh

Solar, Wind, Hydro

Zero carbon

Coal CO₂ Intensity

820 T/GWh

Highest of all sources

Best Renewable Quarter

Q1 2023

27.9% share

Renewable Share % by Quarter Target line at 30%

Seasonal Demand by Quarter Q1 & Q3 peak demand

Transition Insight: Renewable share has been range-bound at 21–29% across 8 quarters, not trending upward. The 30% target is achievable with a ~1.2GWh increase in renewable generation in the Southwest, which has the highest solar irradiance and existing grid interconnection. Q2 2023 shows the lowest renewable share (21.7%), likely driven by low-wind months, confirming the need for a diversified renewable mix (solar + wind + storage) rather than relying on a single source.

Total Outage Events

242

2023–2024 combined

Outage Rate

6.05%

Target: < 5%

Highest-Risk Region

West

59 outage events

Est. Outage Cost Formula

Hours × MWh × $0.08

Per-event cost model

Outage Events by Region West leads with 59 events

Revenue vs Outages by Region West: high revenue + high risk

Outage Risk Finding: The West region generates the highest revenue ($108M) but also records the most outage events (59), creating a high-value, high-risk concentration. A predictive outage model for West region gas and coal assets, using historical outage frequency and seasonal load patterns, would have a measurable ROI within 12 months. Priority action: implement condition monitoring on West assets and establish a $50K/year predictive maintenance program to target the top 5% of outage-risk asset-quarter combinations.

📊 Dashboard Analysis & Key Insights

🚨 Outage Crisis

With 242 outage events, 61% above the 150-event target, grid reliability is the single largest operational risk. The West region leads with 59 events while also generating the highest revenue ($108M), creating a high-value, high-risk concentration that demands immediate investment in predictive maintenance.

⚡ Renewable Gap

Renewable share is stuck at 27.2% across 8 quarters, range-bound, not trending upward. Hitting the 30% target requires only a ~1.2GWh shift, achievable with targeted Southwest solar investment. Q2 is the weakest quarter (21.7%), confirming a need for diversified renewable mix, not a single source dependency.

✅ Carbon Economics Case

Coal appears cheap at $45/MWh nominally, but at $50/ton carbon cost (EU ETS proxy) its effective price rises to ~$87/MWh, nearly 2× the cost of Nuclear ($38). This single insight reframes the entire dispatch optimization model and makes the coal-to-renewable transition an economic argument, not just regulatory.

🌍 Revenue Distribution

Revenue is nearly equal across all 5 regions ($102–$108M), indicating a well-diversified geographic portfolio. This is a strength, no single region accounts for more than 21% of total revenue. Natural Gas alone contributes $235M (45% of total), making it the dominant source but also a concentration risk if regulations tighten.

📅 Seasonal Demand Pattern

Q1 and Q3 are peak demand quarters (3,381 and 3,337 MWh avg) reflecting winter heating and summer cooling loads. Q2 is consistently the lowest demand period. Grid capacity planning should prioritize Q1 and Q3 resilience, particularly in the West and Northeast where both demand and outages are highest.

🎯 Strategic Priorities

Three priorities emerge from this data:
1. Implement predictive maintenance in West & Northeast to cut outages by 30%+.
2. Add 1.2GWh Southwest solar to reach the 30% renewable target.
3. Use carbon-adjusted cost model to build a board-level case for accelerated coal retirement.