Illustrative Case: Grand Rapids Processor Waits in Consumers Choice Queue While Optimizing GPD Tariff

The facility and starting situation

Assume an adult-use processor in Kent County on Consumers Energy full service in MISO Zone 7 [consumers-large-business-rates]. The building is 32,000 square feet with hydrocarbon extraction, post-processing ovens, chillers, vacuum ovens, and cold storage. Licensed processors operate under the Michigan Regulation and Taxation of Marihuana Act alongside the medical program; the CRA publishes monthly licensing actions rather than a single running total [mpsc-choice-2025-report].

At energization in March 2025 the operator filed for Retail Open Access with a licensed Alternative Electric Supplier. Michigan's Customer Choice and Electricity Reliability Act opened retail access, but PA 286 of 2008 capped participation at 10 percent of each utility's average weather-adjusted retail sales [mcl-460-10a]. The MPSC reported 5,517 customers on choice in 2025 totaling 2,172 MW, with 5,101 more customers waiting [mpsc-choice-2025-report]. Consumers' September 3, 2026 cap tracker showed a 2026 cap of 3,661,684 MWh against 3,619,680 MWh enrolled, leaving 42,004 MWh of allotments available and 2,846 customers with 5,333,737 MWh queued [consumers-electric-choice]. This account landed at illustrative queue rank 1,847 with modeled annual load of 1.85 million kWh.

The account began on Rate GSD General Service Secondary Demand. Peak demand hit 340 kW when chillers, extraction skids, and HVAC aligned on a summer afternoon. Michigan averages 6,745 heating degree days and 579 cooling degree days; the short cooling season means chillers and dehumidification drive year-round latent load more than rooftop cooling alone [noaa-cag-michigan].

What the baseline bills showed

The table uses assumed usage and cited program facts. Dollar demand figures are modeled inputs pending confirmation in the Consumers rate book PDF.

Line item	Assumption or fact	Monthly (summer)	Monthly (winter)	Notes
Extraction and chillers	180 kW on 16 h/day	86,400 kWh	86,400 kWh	Assumed
Ovens and recovery	95 kW on 12 h/day	34,200 kWh	34,200 kWh	Assumed
HVAC and cold storage	85 kW avg	61,200 kWh	61,200 kWh	Assumed
Peak demand	340 kW / 310 kW	340 kW	310 kW	GSD class
Modeled demand charges	Assume $22 combined $/kW	$7,480	$6,820	Confirm in tariff
Energy and riders	Assume 8.4 cents per kWh	~$15,200	~$14,800	Full service
Approximate total		~$30,000	~$28,000	Excludes taxes

Annualized spend near $348,000 at roughly 1.85 million kWh. The EIA June 2026 Michigan commercial average of 16.63 cents per kWh on the same usage would imply about $308,000 [eia-epm-5-6-a], but processors on primary-voltage demand classes often bill above the state commercial average because of kW charges [consumers-large-business-rates].

The operator received a supplier quote at 6.9 cents per kWh fixed, worth roughly $128,000 a year on energy alone in the model. Without a cap allotment, that quote could not be executed [mcl-460-10a] [consumers-electric-choice].

What changed

Work focused on full-service optimization and queue hygiene, not supplier enrollment.

Queue confirmation and January 15 filing. The operator verified its rank on Consumers' ROA Cap Tracking System [consumers-electric-choice]. Under MCL 460.10a, utilities file the rank-ordered list each January 15; when allotments open, the next customers have five business days to accept [mcl-460-10a]. Staff set a calendar alert for the MPSC cap data release [mpsc-cap-data].

Rate GPD primary-voltage conversion. An engineer upgraded service to primary voltage and moved the account to Rate GPD Large General Service Primary Demand, which Consumers lists for high load-factor primary customers [consumers-large-business-rates]. Modeled distribution demand fell from illustrative $22 per kW to $14 per kW after conversion. The customer owned the transformer capital, roughly $95,000 in this example.

Process scheduling to cut coincident peak. Extraction batches shifted so chillers ramped before ovens, not during the same 15-minute interval. Peak demand modeled down from 340 kW to 275 kW. See demand charges explained for why interval stacking matters.

AES term sheet held in escrow. The operator signed a contingent agreement with a licensed AES at 7.1 cents per kWh all-in with capacity structured as a fixed adder, valid for 30 days after allotment notification [mpsc-choice-2025-report]. DTE's choice program carries stricter return-to-service penalties than Consumers [dte-electric-choice]; this site stayed on Consumers specifically to keep one switch per month on the bill-cycle date with a $5 fee when choice eventually opens [consumers-electric-choice].

The Michigan switching guide covers enrollment when an allotment arrives. The fixed vs. index page explains why the operator rejected a pure index offer that would expose MISO Zone 7 summer spikes.

The math after

Compare baseline GSD full service to optimized GPD while still waiting in queue. Supplier savings are shown as contingent, not realized.

Component	Before (annual)	After GPD + scheduling	If choice opens (modeled)	Notes
Annual kWh	1,850,000	1,780,000	1,780,000	Scheduling savings
Peak demand	340 kW avg	275 kW	275 kW	Modeled
Demand charges	~$89,000 at $22/kW	~$46,000 at $14/kW	~$46,000	Illustrative $/kW
Energy + riders	~$155,000 at 8.4 cents	~$149,000	~$126,000 at 7.1 cents AES
Transformer capital	$0	$95,000 one-time	$0 incremental
Modeled annual all-in	~$348,000	~$195,000 + capital	~$172,000	Queue not yet cleared

Near-term savings of roughly $153,000 a year came from tariff and peak work, not supplier choice. If 42,004 MWh of statewide cap space freed rank 1,847 in the model (which would require many customers ahead to drop off), an additional ~$23,000 supply-side savings might layer on [consumers-electric-choice]. Real queue movement depends on customers leaving choice, not illustrative rank alone [mcl-460-10a].

Simple payback on $95,000 transformer capital against $153,000 annual demand savings: about 7.5 months on demand lines alone in this model.

At the EIA Michigan industrial average of 9.24 cents per kWh, energy would look cheaper, but GPD demand charges still apply on full service [eia-epm-5-6-a] [consumers-large-business-rates].

What did not work

Declining full service to force choice. The operator asked whether skipping utility service application would bypass the queue. MCL 460.10a ties allotments to utility load lists; there is no shortcut [mcl-460-10a].

Signing a live AES contract without allotment. One supplier offered to enroll immediately. MPSC cap data showed Consumers over subscribed except for 42,004 MWh total, not per customer [consumers-electric-choice]. The contract would have defaulted to utility service.

Flat load across three shifts. 24-hour oven and chiller operation kept peak demand high. Batch scheduling saved more than a speculative supplier rate.

Ignoring return-to-service rules at a second DTE site. The MSO's Detroit packaging facility on DTE choice faced a two-year initial term and December 1 notice for June through September peak return [dte-electric-choice]. That site stayed on choice; the Grand Rapids processor learned from that penalty story and planned Consumers migration carefully.

Queue position and attrition

When choice programs are fully subscribed, new meters stay on default until another customer returns to bundled service or cap legislation changes. Monitor MPSC queue reports quarterly if supplier savings are part of your pro forma [mi-mpsc-choice-2025].

Default service while queued

Facilities in the Michigan choice queue remain on utility default service at regulated rates [mi-mpsc-choice-2025]. Processor load with high batch peaks still pays delivery demand on the utility tariff. Supplier savings wait on cap space; demand scheduling does not.

Processor peak kW on default service

Batch equipment peaks still drive utility demand charges while supply stays on default [mi-mpsc-choice-2025]. Schedule chillers and stills before shopping supply; delivery savings may exceed supply savings until cap space opens.

Attrition monitoring

When a large industrial customer exits choice back to default, cap space may open without legislation change. MPSC monthly reports list program subscription levels [mi-mpsc-choice-2025].

Processor load letter for queue wait years

While on default service, submit updated load letters when batch equipment changes. Utility demand charges respond to measured peak even without competitive supply [mi-mpsc-choice-2025]. Stagger chiller starts before cap space opens so supplier block sizing uses a lower PLC.

MPSC report monitoring cadence

Review MPSC electric choice status reports each quarter when supplier savings are in the pro forma [mi-mpsc-choice-2025]. Attrition opens cap space without legislative action.

Lessons that transfer to other Michigan processors

Enter the choice queue at service application and monitor the Cap Tracking System [consumers-electric-choice] [mcl-460-10a]. Assume full service for budgeting: the cap has been binding for years [mpsc-choice-2025-report]. Primary-voltage GPD or GPTU often beats secondary GSD for high load-factor process plants [consumers-large-business-rates]. Schedule chillers and ovens to avoid coincident peaks. Hold a contingent AES term sheet, not a live contract, until allotment. Read the Michigan processing energy page and the FAQ on supplier choice.