City of Rocky Mount Utilities Rate Selection Guide
City of Rocky Mount Utilities is a municipal electric and natural gas provider serving roughly 46,200 combined customers across Nash and Edgecombe Counties in North Carolina, operated by the city's Energy Resources Department. Customers view and download billing and usage data through the My Account Online portal (CIS Infinity), while the Beat the Peak load management program offers up to $225/year in demand credits; Green Button, EDI, and APIs are not offered, so third-party access runs through written-authorization requests.
Market Overview
City of Rocky Mount Utilities is a publicly owned municipal utility governed by the city's Energy Resources Department under North Carolina municipal utility law, rather than full Public Utilities Commission regulation. It is a member of ElectriCities of North Carolina (64 public power cities), the American Public Power Association (RP3 award recipient), and the American Public Gas Association (Gold SOAR award). Customers receive bundled service from the city with no retail supplier choice.
Need to pull your actual usage data to compare rates? See the City of Rocky Mount Utilities Data Access Guide →
Current Rate Schedules
Rocky Mount sets electric and gas rates by City Council administrative policy (a public hearing on April 1, 2026 rate adjustments was held March 30, 2026). Nonresidential electric service tiers by demand: SGS under 30 kW (energy-only), MGS, LGS at 500+ kW, and an Industrial schedule built around a Utility Peak Contribution charge. All schedules carry a Purchased Power Adjustment (PPA) on every kWh — 0.8¢/kWh as of October 1, 2025 — plus a $0.32/rkVA reactive charge on demand-metered schedules. Demand bills on the highest 15-minute interval. Natural gas commercial/industrial customers with 240,000+ therms/year can take Firm Delivery (transportation) Service, supplying their own gas while paying the city delivery charges; a Purchase Gas Adjustment ($0.20/therm as of Oct 2025) applies to sales service. The city participates in the ElectriCities 'Beat the Peak' load management program with bill credits up to $225/year.
Effective: July 1, 2025 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| Schedule SGS – Small General Service | commercial | Nonresidential service with maximum demand under 30 kW; transferred off if demand exceeds 40 kW in two of the last twelve months | Facilities charge $31/month single-phase or $51/month three-phase; all energy at 11.001¢/kWh plus PPA (0.8¢/kWh as of Oct 2025) and NC utility sales tax. Proposed 4/1/2026: $35/$55 facilities, 11.120¢/kWh. | ~11.8¢/kWh including PPA |
| Schedule MGS – Medium General Service | commercial | Nonresidential demand-metered accounts between SGS and LGS thresholds | Proposed 4/1/2026: facilities charge $65 single-phase / $85 three-phase; energy 7.052¢/kWh; demand $10.75/kW; reactive $0.32/rkVA; plus PPA. Demand billed on the highest 15-minute interval. | —+ $10.75/kW |
| Schedule LGS – Large General Service | commercial | Nonresidential accounts with maximum annual metered or contract demand of 500 kW or greater; requires Electric Service Agreement | $675/month facilities charge; energy 5.838¢/kWh (proposed 5.985¢ 4/1/2026); demand $16.75/kW; reactive $0.32/rkVA; plus PPA. Billing demand is the greater of the 15-minute monthly peak, 500 kW, or contract demand. Emergency backstand service available with city-owned generation by agreement. | —+ $16.75/kW |
| Schedule IND – Industrial Service | industrial | Largest industrial accounts under Electric Service Agreement | $1,300/month facilities charge; energy 4.5640¢/kWh; Utility Peak Contribution $22.80/kW; Additional Demand $3.15/kW (rises to $12.30/kW when city-owned generation reduces the customer's peak contribution); reactive $0.32/rkVA; plus PPA. Pricing rewards reducing load at the utility's coincident peak. | —+ $22.80/kW utility peak contribution + $3.15/kW additional |
| Schedule GSS – General Seasonal Service (closed) | agricultural | Closed to new customers; seasonal nonresidential loads over 30 kW, primarily agricultural processing | Facilities charge $38 single-phase / $55 three-phase; energy 12.5156¢/kWh first 2,000 kWh, 9.924¢/kWh additional; seasonal demand charge $5.30/kW applied in only three consecutive billing months per year; reactive $0.32/rkVA; plus PPA. | —+ $5.30/kW (3 months/year only) |
| Natural Gas Firm Delivery (Transportation) Service | industrial | Commercial/industrial gas customers with minimum annual volume of 240,000 therms who nominate and deliver their own supply | $250/month facilities charge per meter; delivery: $0.2400/therm first 20,000 therms, $0.1400/therm above; capacity charge $0.3000/therm. Customer bears all commodity and upstream transport costs to the city gate. Sales-service customers instead pay bundled rates plus the PGA ($0.20/therm as of Oct 2025). | — |
Rate Recommendations by Use Case
Small retail, office, or restaurant under 30 kW
Small storefronts in downtown Rocky Mount and along US-301 take Schedule SGS — a simple facilities charge plus flat energy rate with no demand exposure.
At 11.001¢/kWh plus PPA, SGS keeps billing simple. The 40 kW transfer trigger matters: exceed it in two of twelve months and the city moves you to a demand schedule, so growing loads should model MGS proactively.
- Track your computed demand — the city can install a demand meter at any time to test the 15-minute peak
- Budget for the PPA line item, which the Council adjusts based on actual power costs (0.8¢/kWh as of Oct 2025)
- Enroll in Beat the Peak for bill credits even at small scale
Manufacturing or warehouse at 500 kW and above
LGS pairs a low 5.838¢/kWh energy rate with a $16.75/kW demand charge and a 500 kW billing demand floor, making demand control the dominant cost lever.
Billing demand is the greater of the monthly 15-minute peak, 500 kW, or contract demand — so a facility peaking at 700 kW pays $11,725/month in demand alone. Shaving peaks pays $16.75/kW/month directly, and the reactive charge penalizes poor power factor at $0.32/rkVA.
- Set your contract demand carefully — it acts as a floor on every monthly bill
- Correct power factor with capacitor banks to cut the rkVA reactive charge
- Coordinate large motor starts to avoid setting a new 15-minute peak
Large industrial with curtailable or generator-backed load
Schedule IND prices most demand as a $22.80/kW Utility Peak Contribution — load you avoid during the system coincident peak escapes the charge.
Rocky Mount buys power through NCEMPA/ElectriCities, so its costs key off coincident peaks. IND's structure (4.564¢/kWh energy, $22.80/kW peak contribution, $3.15/kW additional demand) directly rewards curtailing or self-generating during CP windows announced via Beat the Peak.
- Subscribe to ElectriCities coincident peak alerts and curtail during CP intervals
- Evaluate on-site or city-owned generation — note Additional Demand rises to $12.30/kW when city generation offsets your peak contribution
- Negotiate the Electric Service Agreement terms with the Energy Resources Director before signing
Large gas users (process heat, boilers) above 240,000 therms/year
Firm Delivery Service lets qualifying customers buy their own gas commodity and pay Rocky Mount only for delivery — $0.14-$0.24/therm plus a $0.30/therm capacity charge.
With the PGA on sales service at $0.20/therm (Oct 2025) on top of bundled commodity rates above $1.05/therm residential-equivalent, large users who can manage their own supply and nominations typically beat bundled sales service substantially.
- Confirm you clear the 240,000 therm/year minimum before applying
- Line up a gas marketer to handle monthly nominations to the city gate
- Compare all-in transportation cost (delivery + capacity + commodity + upstream transport) against bundled sales service annually
Cost Optimization Strategies
Rocky Mount's rate book concentrates costs in 15-minute demand peaks, the coincident-peak-driven Industrial schedule, reactive power charges, and Council-adjusted PPA/PGA pass-throughs. Because the city buys wholesale power through ElectriCities/NCEMPA, peak-coincident load reduction flows straight through to customer savings via Beat the Peak credits and the IND schedule's structure.
Coincident peak (CP) curtailment
For: All customers; highest value for Schedule IND
The Beat the Peak program credits customers up to $225/year for reducing demand during announced CP intervals, and Schedule IND's $22.80/kW Utility Peak Contribution makes CP avoidance worth far more for industrials. Curtailing or shifting load during summer afternoon and winter morning CP windows is the single highest-value action in this territory.
15-minute peak demand management
For: MGS, LGS, and IND customers
MGS ($10.75/kW) and LGS ($16.75/kW) bill the highest 15-minute interval each month. Staggering equipment starts, demand-limiting controls, and battery or thermal storage flatten the peak. LGS customers should also right-size contract demand, since billing demand never falls below it or 500 kW.
Power factor correction
For: Demand-metered customers with motor-heavy loads
All demand schedules charge $0.32/rkVA on the maximum 15-minute reactive demand. Facilities with large induction motor loads can install capacitor banks to push power factor toward unity, eliminating most of the reactive charge and freeing transformer capacity.
Gas transportation service conversion
For: Large commercial/industrial gas users
Customers above 240,000 therms/year can move from bundled sales (exposed to the PGA, $0.20/therm as of Oct 2025) to Firm Delivery Service, buying commodity at market through a marketer and paying the city $0.14-$0.24/therm delivery plus $0.30/therm capacity.
PPA/PGA tracking and rate change monitoring
For: All electric and gas customers
The Council adjusts the Purchased Power Adjustment and Purchase Gas Adjustment based on actual wholesale costs (PPA moved to 0.8¢/kWh and PGA to $0.20/therm on Oct 1, 2025), and base rates change via public hearing (next adjustments effective April 1, 2026). Tracking city public notices keeps budgets and bill validation current.
To implement these strategies, you need your 15-minute interval data. Learn how to download City of Rocky Mount Utilities interval data →
Frequently Asked Questions
How do commercial customers download usage data from Rocky Mount Utilities?▾
Register at https://myutilities.rockymountnc.gov/app/login.jsp using a recent utility bill for verification. The My Account Online portal lets you view current and historical bills, review payment history, and analyze and download electricity, gas, and water usage across multiple accounts under one profile. Specific export formats are not published — confirm in-portal or with Customer Service at 252-972-1250.
Can third parties or aggregators access Rocky Mount customer data automatically?▾
Not through the utility itself — Rocky Mount has no Share My Data portal, public API, or ESPI support. Nectar provides API access to Rocky Mount billing data — see docs.nectarclimate.com. Otherwise, third parties must obtain a signed customer data disclosure authorization and negotiate directly with the Energy Resources Department at energyspecialist@rockymountnc.gov or 252-467-4800. Typical turnaround is 5-10 business days, with delivery via email or manual export.
Is interval data available from Rocky Mount's smart meters?▾
Not in a documented way. Smart meters are deployed across the electric territory and enable remote reads and real-time monitoring, but the utility has not published interval granularity or a customer download path for raw interval data. The portal exposes usage analytics; for anything more granular, submit a request to Customer Service at 252-972-1250.
Does Rocky Mount support EDI or Green Button?▾
Neither. There is no EDI program (no 814, 820, 867, or 810 transactions, no VAN partnerships, no trading partner enrollment) and no Green Button DMD or CMD — Rocky Mount is not on the Green Button participating utilities list. Business customers use the online portal, paper invoicing, or direct arrangements with the Energy Resources Department.
How can large facilities reduce demand costs with Rocky Mount Utilities?▾
Enroll in the Beat the Peak load management program (commercial line: 252-467-4800), which credits bills for demand reduction during coincident peak intervals — worth up to $225/year. The program monitors CP-interval demand, giving enrolled facilities indirect visibility into their peak contribution even though raw interval downloads are not offered.
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