Nevada Multi-Site Cannabis Operator Energy: NV Energy Territories, Bundled Service, and Portfolio Peak Management

One operator, two NV Energy companies, zero supplier market

A Nevada portfolio might include:

• A 30,000 sq ft indoor grow in North Las Vegas on Nevada Power LGS-2
• A hydrocarbon lab on the same campus meter or an adjacent LGS-1 account
• Six dispensaries in Clark County, mostly on GS
• A Reno processor on Sierra Pacific GS-3
• Conditional licenses in the CCB pipeline not yet energized [ccb-active-license-list]

Every account above sits on bundled NV Energy service. Voters rejected Question 3 in November 2018, closing the path to a general retail market [nv-independent-q3-2018]. Portfolio energy work in Nevada is tariff harmonization, peak calendars, and conditional 704B analysis, not supplier RFPs [nrs-704b].

Active vs. conditional footprint

The CCB September 1, 2026 active list shows 103 cultivation, 82 production, and 107 dispensary licenses [ccb-active-license-list]. The conditional sheet adds 39 cultivation, 25 production, and 22 dispensary licenses awaiting inspection [ccb-active-license-list]. An MSO acquiring conditional assets should budget utility service applications and demand forecasts before revenue starts, because NV Energy class placement is set at energization [ccb-active-license-list].

Territory map

NV Energy subsidiary	Key cannabis load	Class system
Nevada Power (south)	Las Vegas metro grows, most dispensaries	GS, LGS-1/2/3, optional TOU [nve-south-commercial-rates]
Sierra Pacific (north)	Reno/Carson processors, northern retail	GS-1 through GS-4 [nve-south-commercial-rates]
Rural co-ops / districts	Scattered	Often outside PUCN IOU tariffs [pucn-electric]

Both subsidiaries file separately with the PUCN even though branding is unified [pucn-electric]. A corporate entity with sites in both territories cannot net peaks across them for billing; each meter stands alone.

What portfolio procurement looks like without choice

In Ohio or New Jersey, an MSO runs synchronized supplier renewals. In Nevada, the parallel calendar tracks:

1. TOU election windows and whether grow sites can shift load off 3:01 to 9 p.m. summer on-peak [nve-south-commercial-rates]
2. 704B filing period January 2 through February 1 for any megawatt-scale campus [nrs-704b]
3. PowerShift rebate cycles for LED, HVAC, and storage across stores and grows [nve-storage-incentive]
4. Conditional license energization dates that add new demand charges mid-year [ccb-active-license-list]
5. DEAA and fuel riders on bundled bills that move without a contract renewal [nrs-704b]

Standardize a monthly bill data feed: account number, subsidiary, schedule, kWh, kW, total dollars. That dataset replaces supplier offer comparison.

704B at portfolio scale

NRS 704B requires 1 MW average annual load per eligible customer [nrs-704b]. Strategies MSOs consider:

• Single campus meter combining cultivation, processing, and packaging if legally one customer of record
• Separate meters that each fail the threshold even when corporate load is large
• Impact fee modeling before filing; casino exits show fees can exceed supply savings [nrs-704b]

Applications must be filed January 2 through February 1 at least 280 days before purchases begin [nrs-704b]. A portfolio team that discovers eligibility in March waits until the next year.

Only the largest Nevada cultivation campuses approach 1 MW average load. Most MSOs optimize LGS-3 TOU plus storage instead of 704B [nve-storage-incentive].

Southern vs. northern peak strategy

Southern optional TOU concentrates demand charges June through September, 3:01 to 9 p.m. [nve-south-commercial-rates]. Portfolio playbook:

• Grows on TOU: stagger veg/flower lighting, pre-cool before 3 p.m., deploy storage [nve-storage-incentive]
• Dispensaries on GS: prioritize kWh reduction; TOU rarely helps small peaks
• Northern sites: model GS breakpoints at 50 kW and 500 kW separately; winter heating adds baseload [nve-south-commercial-rates]

Statewide commercial average was 9.83 cents/kWh in June 2026, but all-in costs diverge by class and peak [eia-epm-5-6-a].

Worked portfolio snapshot

Assumptions for illustration only:

Site	Subsidiary	Schedule	Monthly kWh	Peak kW	Primary lever
North Las Vegas grow	Nevada Power	LGS-2 TOU	220,000	380	Shift lighting off 3-9 p.m. on-peak [nve-south-commercial-rates]
Same campus lab	Nevada Power	LGS-1	85,000	210	Stagger chiller starts [nve-south-commercial-rates]
4x Las Vegas dispensary	Nevada Power	GS/LGS-1	7,500 each	45	Instant Discount LED [nve-instant-discount]
Reno processor	Sierra Pacific	GS-3	120,000	520	Northern breakpoint review [nve-south-commercial-rates]

Portfolio annual kWh: roughly 750,000 kWh across seven meters (illustrative).

At 9.83 cents/kWh bundled average: energy portion about $73,700 before demand charges [eia-epm-5-6-a].

704B eligibility: no single meter averages 1 MW; combined corporate load does not aggregate for 704B [nrs-704b]. Strategy stays TOU plus storage on the grow, batch scheduling on the lab, efficiency on stores.

This is not a quote. It shows why Nevada MSO work is operational peak management per meter rather than one supply RFP.

Data standardization across sites

Use one spreadsheet schema:

Field	Why it matters
NV Energy subsidiary	Tariff book differs
Rate schedule	GS vs LGS vs TOU variant
Billing demand kW	Drives delivery on LGS
TOU flag	On-peak overlap
Conditional vs active license	Forecast new load
Rebate project ID	Track PowerShift spend

Interval data from AMI meters on grow sites supports TOU modeling. Dispensaries may remain monthly kWh only.

Submetering and tenant issues

MSOs leasing cultivation space should resolve meter ownership and class placement in the lease. A landlord meter that combines multiple tenants can push everyone into LGS-2 at 300 kW even when one tenant alone would stay on LGS-1. See submetering guidance.

Conditional license pipeline and capital planning

The CCB conditional sheet lists 39 cultivation, 25 production, and 22 dispensary licenses not yet operational as of September 1, 2026 [ccb-active-license-list]. MSOs acquiring conditional assets should model utility costs before revenue:

• Service application lead time with NV Energy for new LGS load
• Transformer and line extension costs borne by the customer of record
• TOU election timing before first summer on-peak season after energization
• PowerShift pre-approval for LED and storage bundled into buildout budgets [nve-storage-incentive]

A portfolio that adds 200 kW of new grow load in Q2 faces its first June through September on-peak window without twelve months of interval history. Use engineering estimates for TOU modeling until AMI data exists [nve-south-commercial-rates].

DEAA and bundled rate volatility

Bundled NV Energy bills include a Deferred Energy Accounting Adjustment that trues up fuel and purchased-power costs [nrs-704b]. AB 452 (2025) directs the PUCN to study fuel-cost sharing with a March 1, 2027 filing [nrs-704b]. MSO finance teams should track DEAA line items monthly even without supplier contracts to renew, because bundled energy charges move on regulatory schedules [nrs-704b].

Portfolio kWh vs 704B megawatt threshold

NRS 704B requires average annual load of 1 MW or more before a customer may buy energy from a provider of new electric resources [nrs-704b]. One megawatt average load implies roughly 8.76 million kWh per year at flat run hours. A portfolio of three 350 kW peaks does not automatically qualify unless combined annual kWh and load factor reach the threshold on a single PUCN application [nrs-704b].

Site	Assume peak kW	Assume annual kWh	704B relevance
Las Vegas cultivation	380	2,800,000	Below 1 MW average alone [nrs-704b]
Reno processing	140	900,000	Below threshold [nrs-704b]
Three-site sum	n/a	5,500,000	Still below 8.76M kWh unless load factor rises [nrs-704b]

Applications are accepted only January 2 through February 1 with at least 280 days' lead time [nrs-704b]. Impact fees have been large for casinos and data centers; model PUCN conditions before treating 704B as a portfolio procurement plan [nrs-704b].

DEAA volatility across a multi-site P and L

Bundled rates carry a Deferred Energy Accounting Adjustment that trues up fuel and purchased-power costs [nrs-704b]. AB 452 (2025) directs the PUCN to study fuel-cost sharing with a March 1, 2027 filing [nrs-704b]. A portfolio CFO should track DEAA line items monthly on every Nevada Power and Sierra Pacific bill, not just peak kW [pucn-electric].

Submetering Clark County cultivation from Reno processing

Portfolio operators with Las Vegas cultivation on Nevada Power and Reno processing on Sierra Pacific cannot merge accounts for 704B eligibility [nve-south-commercial-rates] [nve-north-commercial-rates] [nrs-704b]. Each service point averages load independently for the 1 MW threshold [nrs-704b]. Submetering tenant spaces within one building does not create a second 704B application path unless each submeter is a utility account [pucn-electric].

Standardize interval data exports from every NV Energy account monthly: billing demand kW, schedule code, DEAA riders, and kWh by rate period [nve-south-commercial-rates] [nrs-704b]. Compare summer on-peak kW across sites before electing optional TOU portfolio-wide [nve-south-commercial-rates].

Where to go next

• Nevada hub for regulatory context
• 704B procedure guide
• Commercial rates for class tables
• NV Energy utility page
• Compare portfolio strategy in choice states: California MSO guide, Texas MSO guide

Confirm conditional license energization dates with the CCB before publishing investor-facing cost forecasts.