ERCOT Emergency Response Service (ERS)
Texas
ERCOT (Texas ISO)
Capacity payment (contracted $$ for availability; 10-min or 30-min notice); no energy charge for load shed
≥100 kW (often much larger) via QSE aggregator; must drop agreed MW in 10 or 30 min during ERCOT
Active
Year-round, procured quarterly by ERCOT
ERCOT 4CP Transmission Charge Reduction
Texas
ERCOT (Texas utilities)
Bill savings (avoidance of demand charges)
Large customers with transmission-level service (typically >700 kW); reduce load during ERCOT’s peak hour each of June–Sept
Active
Austin Energy Commercial DR (“Fast DR”)
Texas
Austin Energy (Texas municipality)
Bill credit per kW per event season ($65–$80/kW for fast response)
≥10 kW reducible; Standard option (30-min notice) or Fast with ADR (10-min notice); summer weekday events
Active
CPS Energy C&I DR Program
Texas
CPS Energy (San Antonio, TX)
Bill credit per kW (e.g. $70+/kW for summer)
≥50 kW (aggregate sites allowed); 30-min or 2-hr notice plan; ~25 events Jun–Sep, weekday afternoons
Active
IESO Capacity Auction DR
Canada
Ontario (IESO)
Capacity payment (auction-cleared $/MW-month) + energy payments in events
≥1 MW reduction (or aggregate); 1-day or same-day notice; 4-hour event capability (summer 12–9pm, winter 4–9pm)
Active
Seasonal auctions; formerly DR3
Ontario Industrial Conservation (ICI)
Canada
Ontario (Provincial)
Cost savings (lower Global Adjustment charges)
Class A customer (≥500 kW peak, opt-in); must cut load on top-5 annual peak hours (no advance notice – customer must predict)
Active
Annual peak-based billing
ISO-NE Active Demand Capacity (ADCR)
Connecticut, Maine, Massachusetts, New Hampshire, Rhode Island, & Vermont
ISO New England (all 6 states, Connecticut Maine, Massachusetts, New Hampshire, Rhode Island, and Vermont)
Monthly capacity payments (FCM) + energy payments (real-time LMP) for dispatched reductions
≥100 kW (often via aggregator); dispatch by ISO-NE during high-price or shortage hours; must have interval metering
Active
Fully integrated in ISO-NE markets
Connected Solutions (Summer DR)
Massachusetts & Rhode Island
MA, RI (National Grid, Eversource)
Performance incentive ($200–$275 per kW per summer for meeting targets)
≥50 kW typically (smaller with storage); day-ahead notice; ~30–60 peak events June–Sept, 2-3 hr each
Active
Utility program, tied to EE plans
NYISO ICAP Special Case Resource (SCR)
New York
NY (NYISO statewide)
Monthly capacity payment (ICAP market) + event performance payment
≥100 kW reducible (or aggregate); 21-24 hr advance notice (advisory) then 2-hr confirmation; must curtail for up to 4–6 hrs in reliability events; test if no event
Active
Year-round, primarily summer events
NYISO Emergency DR (EDRP)
New York
NY (NYISO statewide)
Energy payment for voluntary curtailment (e.g. ≥$500/MWh or market price)
≥100 kW; same notice as SCR (day-ahead advisory, 2-hr day-of) but voluntary – no penalty for not curtailing
Year-round, used in emergencies
NYISO Economic DR (DADRP/DSASP)
New York
NY (NYISO statewide)
Energy payments (LMP) for bids; Ancillary service payments for fast response
≥1 MW typically; bid load cut in day-ahead market (DADRP) or provide reserves/regulation (DSASP) with telemet
Active
2025 – transitioning to DER model; infrequent participation
Con Edison CSRP (21-hour notice)
New York
NYC (ConEd)
Reservation payment (~$18–$30/kW-summer) + energy pay for events
≥50 kW; May–Sep network-specific peaks; day-ahead ~21 hr notice; 4-hour afternoon events
Active
Con Edison DLRP (2-hour notice)
New York
NYC (ConEd)
Reservation payment (higher than CSRP) + energy pay; bonus for immediate reductions
≥50 kW; May–Sep (can extend to Oct-Apr if called); 2-hr or less notice for contingency events, potentially anytime 8AM–12AM
Active
Events on local emergency
PJM Emergency DR (Capacity Load Response)
Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, and West Virginia
PJM (13-state RTO)
Capacity payments (RPM auction $/MW-day, paid monthly) + energy payments in events
≥100 kW (often via CSP); 30 min to 2 hr notification; must sustain load drop up to 6+ hrs if calledenel625.zendesk.comenel625.zendesk.com; penalties for non-performance
Active
Year-round, high availability; critical in summer
PJM Synchronized Reserve (DR)
Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, and West Virginia
PJM (13-state RTO)
Market payments for reserves (paid per event or per hour available)
Typically ≥500 kW; telemetry required; must begin curtailment instantly and be down by 10 min, for ~10-30 min
Active
Year-round; frequent brief dispatches
PJM Economic DR (Load Response)
Delaware, Illinois, Indiana, Kentucky, Maryland, Michigan, New Jersey, North Carolina, Ohio, Pennsylvania, Tennessee, Virginia, and West Virginia
PJM (all zones)
Bill credit or direct payment at LMP for voluntary curtailments
≥100 kW with interval meter; no obligations – curtail at will when prices high; baseline methodology to determine load drop
Active
Year-round; enabled by PJM market rules
ComEd Voluntary Load Reduction (VLR)
Illinois
Illinois (within PJM)
Energy payment or bill credit (state program during emergencies)
Large C&I in ComEd territory; event-based, typically on request of grid operator/state; no penalty if not curtailing
Active
Onitiated 2021, used during tight grid events
FPL Commercial Demand Reduction
Florida
Florida (FPL)
Monthly bill credit (~$8.76 per kW of controlled load)
≥200 kW curtailable load; must allow FPL to install load-control device to drop load to firm service level during peak events
Active
Year-round, events mostly summer; FPL main & NW Fla.
Florida Small Business On-Call
Florida
Florida (FPL, others)
Bill credit (fixed $ per device tonnage per month)
Must have eligible equipment (e.g. central A/C) for utility to control; cycling of equipment on peak days
Active
Primarily summer; ongoing DSM program
California Critical Peak Pricing (CPP/PDP)
California
California IOUs (PG&E, SCE, SDG&E)
Bill discount on standard rates + High event charges (no separate payment; savings if usage reduced on event days)
Available to most C&I customers; no tech req beyond smart meter; ~12 event days/year (day-ahead notice) where ~4-5 hour window has 3-5× normal price
Active
Summer seasons; default for many large C&I with opt-out
California Base Interruptible Program (BIP)
California
California IOUs (PG&E, SCE, SDG&E)
Monthly capacity credit (bill credit ~$7–9 per kW-month) + penalty for non-compliance
≥100 kW curtailable; 15 or 30 min notice; must drop to firm service level; typically 1-2 tests or events/year, events can last up to 2-4 hours
Active
Year-round, used in CAISO emergencies
California Capacity Bidding Program (CBP)
California IOUs
Monthly capacity pay (varies by month/option) + energy pay per event; no penalties beyond non-payment
≥50 kW (often via aggregators can combine smaller); Day-Ahead option (notify day prior) or Day-Of (1-2 hr notice); up to ~5 events/month, 1-4 hrs each
Active
Summer-focused; enrollment optional each month
CAISO Emergency Load Reduction (ELRP)
California
California (CPUC/IOUs & CAISO)
Energy pay $1–2 per kWh for load drop in emergency events
All non-residential customers eligible via utility; no firm commitment required; events called during grid emergencies (Flex Alerts/EEA), typically 1-4 hrs; no penalty if no response.
Active
Pilot extended through 2025+; used during extreme conditions
Automated DR (ADR) Technology Incentive
California
California IOUs
One-time rebate (e.g. $200/kW of load enabled for DR)
Install qualifying controls that allow utility/aggregator to remotely curtail load or implement preset load drop strategies
Active
On-going incentive to facilitate participation in DR programs
