What is 4CP and how can Texas businesses reduce 4CP charges?

The core thesis

Four‑coincident‑peak (4CP) transmission charges are the single largest demand‑related cost for many Texas commercial and industrial (C&I) customers. They are calculated on the basis of a customer’s share of the four highest‑demand 15‑minute intervals across the June‑September summer window. Reducing a site’s contribution to those intervals can cut next‑year transmission bills by 5‑15 %, but the effort must be balanced against production constraints, staffing, and equipment wear. In short, 4CP is a cost‑allocation mechanism; you lower it by moving or shaving load during the exact moments the grid is most stressed.

What is 4CP?

ERCOT’s nodal market assigns transmission costs to each load based on the four coincident peaks (4CP) that occur during the summer peak season (June 1 through Sept 30). For each of the 15‑minute intervals that rank among the top four system‑wide demand spikes, ERCOT calculates a transmission cost factor (TCF). A customer’s 4CP charge equals the sum of its MW share of those four intervals multiplied by the applicable TCF, then multiplied by the transmission‑owner’s charge rate (often expressed in $/MWh). The result appears on the next year’s TDSP bill as a separate line item.

How the four summer peaks are identified

1. Data collection – ERCOT records system demand every 15 minutes. 2. Ranking – At the end of the summer season, the four intervals with the highest total MW are flagged. 3. Allocation – Each TDSP (Oncor, CenterPoint, AEP Texas, TNMP) allocates its portion of the TCF to its customers based on the MW each customer contributed during those intervals. 4. Billing – The charge is posted on the next year’s transmission‑delivery bill, typically as a $/MWh rate applied to the customer’s 4CP‑MW.

Why 4CP matters for Texas businesses

• Cost magnitude – For a 5 MW facility, a 10 % reduction in 4CP can shave $30 k–$45 k off the annual transmission bill. 8,000+ UPG clients collectively save $3.2 M each year, a portion of which comes from 4CP optimization.
• Regulatory backdrop – The Public Utility Commission of Texas (PUCT) mandates that TDSPs recover transmission costs through the 4CP mechanism. No alternative allocation method is permitted under current ERCOT tariffs.
• Competitive pressure – With 30+ top‑tier supplier options, a 27 % overall spend reduction is achievable when 4CP is addressed alongside commodity procurement.

Reducing 4CP charges

1. Predictive analytics and load forecasting

Accurate forecasting is the foundation. UPG’s Energy Health Check includes a 15‑minute interval load profile audit that identifies when a site typically peaks. By overlaying ERCOT’s historical 4CP intervals (often late afternoon on hot July days), you can model the probability of hitting a coincident peak.

• Tools – Use ERCOT’s real‑time LMP data, weather forecasts, and internal SCADA to generate a probability curve for each upcoming 15‑minute slot.
• Action – If the model shows a >70 % chance of being in the top‑four, schedule non‑essential processes, HVAC setbacks, or battery discharge for that window.

2. Demand‑response participation

TDSPs and REPs (Retail Electric Providers) run ancillary‑service markets that reward load curtailment during 4CP windows. Enrolling in a Capacity‑Based DR program can earn $/MW‑day credits that often exceed the cost of the 4CP charge itself.

• Example – A 1 MW plant that curtails 10 % for a single 15‑minute 4CP interval can earn $150–$250 in DR payments, while avoiding $300–$450 in transmission charges.

3. On‑site storage and controllable assets

Battery Energy Storage Systems (BESS) are the most precise tool for shaving 4CP load because they can discharge exactly when needed without affecting production.

• Sizing – A 2 MWh battery with 1 MW discharge capability can cover the typical 15‑minute peak, delivering up to 250 kWh of avoided 4CP consumption per event.
• Economics – Assuming a $/MWh 4CP rate of $30, each discharge saves $7.5 k per event. Over a 5‑year horizon, the net present value can justify the capital expense, especially when combined with DR revenue.

4. Operational curtailment strategies

When storage is not available, operational flexibility can still reduce 4CP exposure.

• Load shifting – Move batch processes (e.g., metal finishing, water treatment) to early morning or evening slots.
• HVAC staging – Pre‑cool facilities before the forecasted peak and raise thermostat setpoints during the 15‑minute window.
• Process throttling – For continuous processes, run at reduced capacity during the high‑probability interval and make up the output later.

5. When chasing 4CP isn’t worth it

Not every site benefits equally. Consider the following thresholds:

• Low baseline demand – Facilities under 1 MW rarely contribute enough MW to the top‑four intervals to generate a material charge.
• High production constraints – Plants that cannot safely reduce load without jeopardizing product quality or safety may incur higher indirect costs than the 4CP savings.
• Cost of implementation – If the capital or labor cost to add storage or DR participation exceeds the projected $/MWh savings (typically $20–$30 per MWh), the ROI is negative.

In those cases, focus on other cost levers—commodity procurement, fixed‑rate contracts, or demand‑charge restructuring—where UPG’s 30+ supplier panel can deliver up to 27 % spend reduction.

Leveraging UPG’s expertise

United Power Group (UPG) is headquartered in Lewisville, Texas, and brings 25 + years of Texas market experience. Our free Energy Health Check reviews your bill, audits TDSP delivery‑charge allocations, and maps your load profile against ERCOT’s 4CP intervals. With 8,000+ business customers, we have identified and acted on 4CP reduction opportunities that collectively saved $3.2 M annually. Our consultants can:

• Model 4CP exposure using proprietary software that aligns your SCADA data with ERCOT’s historical peaks.
• Design a DR participation plan that meets PUCT requirements and maximizes ancillary‑service payments.
• Evaluate storage economics and recommend right‑sized BESS solutions.
• Integrate demand‑side management into existing energy procurement strategies, including fixed‑rate or block‑and‑index contracts.

Bottom line

4CP charges reflect the cost of transmitting electricity during the grid’s most stressed moments. Texas C&I firms can lower those charges by forecasting peak intervals, participating in demand‑response, deploying storage, or strategically shifting load. However, the operational effort must be justified against the potential savings; low‑demand sites or those with rigid processes may find the ROI insufficient. A disciplined, data‑driven approach—backed by UPG’s free Energy Health Check and decades of Texas expertise—ensures you chase 4CP only when the financial upside outweighs the operational pain.