Greenville Utilities Commission Rate Selection Guide
Greenville Utilities Commission (GUC) is a municipally owned multi-service utility serving Greenville, North Carolina and surrounding Pitt County with electric, natural gas, water, and wastewater service to roughly 74,000 electric customers. Billing and usage data are accessed through the myaccount.guc.com customer portal with third-party account delegation; interval data access will expand as GUC's 2026-2031 Sensus FlexNet AMI deployment comes online.
Greenville Utilities Commission Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| EG-2 Medium General Service | Commercial | $77/mo + $4.17/kW + 8.975 cents/kWh | Mid-size commercial loads 35-750 kW |
| EG-4 Large General Service-CP | Industrial | $231/mo + $23.90/CP kW + $10.92/NCP kW + 3.082 cents/kWh | Large C&I loads >=750 kW able to manage coincident peaks |
| EG-6 Transmission Service-CP | Industrial | Transmission-level CP rate (see schedule) | Very large industrial customers at transmission voltage |
Market Overview
GUC is a municipal utility with an exclusive service territory and no retail electric choice. Rates are set by the GUC Board of Commissioners. Wholesale power comes from NCEMPA, and NCEMPA's coincident-peak demand and energy rates pass through to large C&I customers via the EG-4 Large General Service-CP schedule and the RR-4 Purchase Power Adjustment rider.
Need to pull your actual usage data to compare rates? See the Greenville Utilities Commission Data Access Guide →
Current Rate Schedules
GUC electric rates are set by the Board of Commissioners and published as Part E rate schedules, with the current C&I schedules effective April 1, 2026. Nonresidential customers are tiered by demand: Small General Service (EG-1), Medium General Service (EG-2, 35-750 kW), and Large General Service-CP (EG-4, >=750 kW). The EG-4 schedule passes through NCEMPA coincident-peak demand and energy costs plus the RR-4 Purchase Power Adjustment rider. All charges are subject to NC sales tax.
Effective: April 1, 2026 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| EG-2 Medium General Service | commercial | Nonresidential customers with contract or registered demand of 35 kW up to 750 kW. | Base Facilities Charge $77.00/month; Demand Charge $4.17 per kW of billing demand; Energy Charge 8.975 cents/kWh; minimum = base facilities charge. Energy includes RR-4 PPA. (Effective April 1, 2026.) | — |
| EG-3 Medium General Service-CP | commercial | Mid-size nonresidential customers electing coincident-peak demand billing. | Coincident-peak demand structure tracking NCEMPA wholesale CP rates plus RR-4 PPA. See published schedule for current per-kW and per-kWh values (effective April 1, 2026). | — |
| EG-4 Large General Service-CP | industrial | Nonresidential customers with contract or registered demand >=750 kW, served at 7,200/12,470Y volts. | Base Facilities Charge $231.00/month; Coincident-Peak (CP) Demand $23.90 per CP kW; Non-coincident Peak (NCP) Demand $10.92 per kW; rkVA Demand 25.000 cents per rkVA; Energy 3.082 cents/kWh; interruptible demand $11.78/kW (<25 MW) or $16.49/kW (>25 MW). CP demand and energy track NCEMPA wholesale rates plus RR-4 PPA. (Effective April 1, 2026.) | — |
| EG-6 Transmission Service-CP (E-INDTRN) | industrial | Large industrial customers taking transmission-level service. | Transmission-level coincident-peak service tracking NCEMPA wholesale rates; see published schedule for current values (effective July 1, 2025). | — |
| EV-1 Electric Vehicle Fast Charge Service | ev | Commercial DC fast-charging / EV charging installations. | Dedicated EV fast-charge tariff; see published schedule for current demand and energy charges (effective April 1, 2026). | — |
Rate Recommendations by Use Case
Large industrial / manufacturing site (>=750 kW)
Take EG-4 Large General Service-CP and build operations around the monthly NCEMPA coincident-peak window.
EG-4's low 3.082 cents/kWh energy and CP-only demand billing reward customers who can curtail during the single system-peak interval. GUC's advance CP notifications make this actionable.
- Automate response to GUC CP-event signals
- Correct power factor to avoid reactive charges
- Evaluate interruptible enrollment if load exceeds 1 MW
Mid-size commercial (office, retail, light industrial 35-750 kW)
Use EG-2 Medium General Service and focus on flattening peak demand.
EG-2's flat $4.17/kW demand charge applies to the monthly 15-minute peak regardless of timing, so reducing the single highest demand interval is the main lever.
- Stagger startup of large equipment to cut peak demand
- Track the monthly 15-minute peak in the portal
- Consider EG-4/EG-3 if approaching 750 kW with peak-aligned load
Energy consultant / aggregator managing client accounts
Use portal account delegation for ongoing access and contact the Key Accounts Team for data needs.
GUC has no API or Share My Data program, so delegated portal access is the only repeatable third-party path until AMI expands data availability.
- Have each client delegate Visitor access in myaccount.guc.com
- Plan around monthly (not interval) data today
- Track AMI rollout for future interval-data access
EV charging / fleet depot operator
Evaluate the EV-1 Fast Charge schedule against standard C&I schedules for charging-heavy load.
Dedicated EV tariffs can reduce demand-charge exposure for spiky charging loads; compare EV-1 economics to EG-2/EG-4 for your profile.
- Stagger charging to limit demand spikes
- Compare EV-1 vs. EG-2 total cost for your duty cycle
- Use GUC energy services for charging design support
Historical Rate Trends
GUC reviews rates annually with its fiscal-year budget. For FY2025-26, GUC proposed an average electric increase of roughly 3.9%, and updated C&I schedules took effect April 1, 2026, superseding the July 1, 2025 schedules. Much of the cost movement is driven by NCEMPA wholesale rates passed through via the RR-4 Purchase Power Adjustment.
April 1, 2026
Updated electric rate schedules (EG-1/EG-2/EG-4 and riders) took effect, superseding the July 1, 2025 schedules.
~+3.9%July 1, 2025
Prior FY2024-25 rate schedules in effect before the April 2026 update.
n/aOverall trend: Gradual upward, driven primarily by NCEMPA wholesale power cost pass-through.
Next expected change: Next annual review with the FY2026-27 budget; interim changes possible via the RR-4 PPA rider.
Cost Optimization Strategies
Because EG-4 bills demand on the single NCEMPA coincident-peak interval, the highest-leverage strategy for large GUC C&I customers is reliable peak-event curtailment. Power-factor correction, interruptible enrollment, and energy efficiency further reduce the rkVA, demand, and energy components.
Coincident-Peak Curtailment
For: EG-4 Large General Service-CP customers
Use GUC's advance CP-event notifications (via Beat-the-Peak signals) to shed or shift load during the monthly NCEMPA system peak, directly lowering the $23.90/CP kW demand charge on EG-4.
Power-Factor / Reactive Correction
For: EG-4 customers with low power factor
Install capacitors or correction equipment to reduce rkVA demand below the reactive billing threshold, cutting the 25.000 cents/rkVA reactive charge on EG-4.
Interruptible Demand Enrollment
For: C&I customers >1 MW able to curtail
Loads over 1 MW willing to curtail can take interruptible demand pricing ($11.78/kW under 25 MW), reducing the effective demand cost relative to firm CP demand.
Rate Schedule Right-Sizing
For: All nonresidential customers near the 750 kW threshold
Confirm the load is on the optimal schedule (EG-2 flat demand vs. EG-4 CP). Loads with high but peak-aligned demand may benefit from CP billing; flatter mid-size loads may be better on EG-2.
To implement these strategies, you need your 15-minute interval data. Learn how to download Greenville Utilities Commission interval data →
Frequently Asked Questions
Can a third-party energy manager or consultant access our GUC usage data?▾
Yes, through portal account delegation. The primary account holder logs into myaccount.guc.com, adds the third party by email, and grants Visitor (read-only) or Account Holder (full) access. There is no Share My Data portal or API, so delegation is the only third-party path today.
Does GUC offer interval (15-minute) data for C&I load analysis?▾
Not yet. GUC reads meters monthly via AMR. True interval data is expected as the Sensus FlexNet AMI program rolls out from 2026 through 2031, with a consumer-facing real-time usage portal anticipated post-2027.
Is Green Button or an API available for automated data feeds?▾
No. GUC has not implemented Green Button Download/Connect My Data, a public API, or ESPI. The Oracle Customer Cloud Service platform supports these capabilities, but GUC has not exposed them publicly. For bulk or integration needs, contact procurement at haddocgc@guc.com.
How are large C&I customers billed, and how can demand charges be reduced?▾
Large customers (>=750 kW) fall under Schedule EG-4 Large General Service-CP, which bills a coincident-peak (CP) demand charge tied to the NCEMPA wholesale peak. GUC issues advance CP-event notifications; curtailing load during those windows directly reduces the CP demand charge. Mid-size customers (35-750 kW) use EG-2 with a flat $4.17/kW billing demand charge.
Who do we contact for EDI or system integration?▾
GUC has no formal EDI trading partner program. Direct inquiries to Customer Service (252-752-7166) and ask for the Key Accounts Team, or contact Procurement at haddocgc@guc.com / 252-551-1533.
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