Alabama Power, a subsidiary of the Southern Company, offers a set of real-time and time-of-use pricing programs.

• In what is essentially a "block-and-swing" (aka "block-and-index") pricing program, customers are alternatively credited or charged for electricity usage below or above a pre-determined customer baseline load (CBL) at the utility's market rates when subscribed to the Real-Time Pricing plan. Participants may choose to pay for these differences from their CBL based on either day-ahead or hour-ahead market pricing. Furthermore, customers may also select from a variety of price protection products, including caps, collars, contracts for differences, index swaps, and index caps. These variants on the basic real-time pricing service are risk management tools that customers can use as hedges against possible periods of high real-time electricity prices.
• The company's time-of-use pricing service can provide predictable utility bill savings for customers who can shift electricity use to off-peak hours, particularly during the summer. On-peak hours are defined as weekdays from 12–7 p.m. from June 1 to September 30 (though some rates define on-peak hours as 1–7 p.m.), and weekdays from 5–9 a.m. from November 1 to March 31. Intermediate-period hours are from 10 a.m.–12 p.m. and 7–9 p.m., Monday to Friday. All other hours are off-peak.
• Commercial and industrial customers can enroll in the Business Electric Vehicle Time-of-Use (BEVT) rate and save on energy costs by shifting the charging of electric vehicles (EV) away from on-peak hours (12–7 p.m.) between June and September. Customers under this rate must have their EV charging load metered separately from all other electrical loads. Customers are charged 21.67¢/kWh during these summer on-peak hours.

Alabama Power offers a Non-Firm Capacity Interruptible Credit option to customers who are able to curtail their load during times of high demand. There are two options that offer different remuneration rates and terms. Option 1 offers customers $24.24 per kW enrolled. Curtailment events last a maximum of eight hours and occur no more than three days per week. There is a maximum of 100 hours of curtailment events called under Option 1. Customers enrolled in Option 2 receive a lower remuneration payment, $11.76 per kW enrolled, but are only subjected to 50 hours per year, and curtailment events are limited to one day per week. Curtailment events under Option 2 also last no more than eight hours.

The TVA-Enel X Demand Response Program provides payments to participants in exchange for their agreeing to reduce electricity consumption with 30 minutes notice during times of exceptionally high demand. Demand response events may occur between 5 a.m.–8 p.m. Enel X collaborates with customers to create an optimal demand reduction plan. Interested customers should contact their local electricity distributor.

Entergy offers several standard and custom load management programs:

• The Large Commercial & Industrial Demand Response program offers three options for customers who are able to shift or curtail load during peak pricing events:
  • The Optional Interruptible Service Rider (OISR) is for customers who can interrupt at least 100 kW of load throughout the year during on-peak hours. On-peak hours are defined as 1–8 p.m. from June through September weekdays, and 7 a.m.–6 p.m. in other months. Program participants can save on utility bills through a reduction in demand charges. Participants must have appropriate metering and communications equipment installed, and penalty charges apply if the agreed-upon load is not curtailed when requested. Customers will be notified of a curtailment event via email or any other mutually acceptable method by 4:30 p.m. the previous day (day-ahead notice). The day-ahead notice also provides customers an estimated event starting time. Actual starting times must occur within four hours of the estimate. Curtailment events may occur up to 10 days per month and last no more than 4 hours per event in the summer and 3 hours per event in other months. In the summer months, only one curtailment event may be called per day, but the rest of the year up to two events may be called each day.  If emergency conditions exist, Entergy may call upon customers to reduce their load by more than their contracted demand during on-peak hours, and provide a 30-minute notification via a mutually acceptable method.
  • The Large General Service Time-of-Use Rate Schedule (GST), for customers with demand of less than 1,000 kW. This rate provides utility bill savings for customers who can shift electricity use to off-peak hours, particularly during summer months. Summer on-peak hours are defined as June through September weekdays, 1–8 p.m. Contact Entergy at (800) 368-3749 for more information.
  • The Large Power Service Time-of-Use Rate Schedule (PST), for customers with demand of 1,000 kW and greater. This rate provides utility bill savings for customers who can shift electricity use to off-peak hours, particularly during summer months. Summer on-peak hours are defined as June–September weekdays, 1–8 p.m. Contact Entergy at (800) 368-3749 for more information.
• Small commercial customers are eligible to participate in Entergy's Small Direct Load Control Pilot Program and save money through the installation of an advanced smart thermostat installed by Entergy at no additional cost to the customer. Customers will save money when Entergy sends a signal to the enrolled thermostat to automatically adjust the temperature by two to four degrees on days when electricity demand is highest. Events are called between 12–7 p.m. from June 1 to September 30. Customers may receive an annual enrollment incentive of up to $100.
• Agricultural customers can enroll in Entergy's Agricultural Irrigation Load Control Program and reduce energy costs through demand reductions. At no cost to the customer, Entergy will install load control equipment to each participating irrigation pump and allow the utility to shut off irrigation pumps during times of high electricity demand. Customers will receive on average $100 per month for each enrolled pump. Load control events are called only on weekdays during peak demand months from June through August. Power interruptions last no more than four hours and occur between 12–9 p.m. Customers can be interrupted a maximum of 15 times per summer period and no more than twice per week. Agricultural customers under Entergy's service can also participate in the Energy Conversion Program, which allows customers to claim incentives to switch from diesel/gas to electric-powered irrigation pumps. Customer can save money by switching to electric pumps because they have fewer operating costs and longer lifespans than diesel/gas-powered pumps.

AEP Southwestern Electric Power Company (SWEPCO) offers two load management opportunities:

• The Load Management Standard Offer Pathway (SOP) provides incentives to energy efficiency service providers (e.g., ESCOs, retail electric providers or customers themselves) for load curtailment on short notice (as little as one hour) during non-holiday weekday afternoon peak demand periods (between 1–7 p.m.) from June 1 through September 30. Customers are notified at least one hour before an interruption. Curtailment events are limited to a maximum of three weekdays per month, lasting no more than four hours each and for no more than three consecutive days. Participants must have a peak demand of at least 175 kW. Payments are based on verified demand savings.
• The Experimental Curtailable Service Rider is available to customers with loads larger than 500 kW. As little as 10-minutes notice is provided for curtailments. This rider is available only in conjunction with the company's Lighting and Power or Large Lighting and Power rate schedules.
• Industrial customers who qualify for service under the Lighting and Power Service schedule with a minimum demand of 100 kW can enroll in the Lighting and Power – Time of Use rate to reduce their energy costs by shifting demand away from on-peak hours, which occur non-holiday weekdays between 1–7 p.m. from June through September. Customers on both primary and secondary services pay different kW and kWh rates for on-peak and off-peak hours.

Oklahoma Gas and Electric Company (OGE) offers several large business rates for load management via their SmartHours^TM program:

• The Variable Peak Pricing Rate allows customers to be credited or charged, based upon day-ahead notification of hourly energy prices, for usage below or above a pre-determined customer baseline load profile.
• The time-of-use rate offers lower total electricity costs for facilities that are able to reduce usage during peak hours (2-7 P.M. weekdays, June 1 through September 30, excluding company-observed holidays) or shift load to off-peak hours, when the rate is substantially lower.
• The Electric Vehicle Time-of-Use rate allows customers to save on energy costs by shifting the charging of electric vehicles away from on-peak hours (2-7 p.m. weekdays excluding company-observed holidays). 

OG&E customers with a minimum load of 200 kW can take advantage of the Load Reduction Rider. Participants receive billing credits for their "subscribed curtailment load" (Subscription Credits) and load reduction (Performance Credits) during curtailment events. The Load Reduction on-peak period begins June 1 and ends September 30. Curtailment events are called weekdays from 12–8 p.m. Customers can choose an event notification period of 30 minutes or 4 hours. Those who choose the 30-minute notification option will receive a 10% premium to the subscription credit. Curtailment hours are selected by customers, who can choose a curtailment limit of 40, 80, or 160 hours.

OG&E also offers customers time-of-use and variable-peak-pricing rates that incentivize them to shift their energy demand away from peak hours and save on energy costs.

Electric Cooperatives of Arkansas, a generation and transmission utility providing power to 17 distribution cooperatives in the state, offers its distribution cooperative customers an interruptible rider that provides incentives or bill credits for participation. Check your local cooperative to see if this option or others are available to end-use customers.

Utilities in the footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's various demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

Tampa Electric (TECO) offers several load management programs:

• The Conservation Value Program provides rebates up to $92 per kW reduction for equipment that shifts or reduces energy use during summer and/or winter peak periods. The peak-demand savings are determined at 5 p.m. in August and 7 a.m. in January, roughly coincident to the time of the utility's peak demand. Measures providing as little as 5 kW are eligible. For more information or to sign up, call (813) 275-3909.
• The Load Management Program offers customers $3.00-$3.50/kW credit on their monthly bills for allowing Tampa Electric to control operation of air conditioning or specialized equipment during peak demand periods. Payment occurs regardless of whether TECO calls the program or not. Summer operating season is April 1 to October 31 from 2–10 p.m. Winter operating season is November 1 to March 31 from 6–11 a.m. and 6–10 p.m. For more information or to sign up, call (813) 275-3909.
• The Standby Generator Program provides customers with credits on their monthly electric bill (@ $6.15/kW) for the portion of the normal facility load that can be served by a standby generator within 30 minutes' notice during peak demand periods. A minimum of 25 kW of transferable load is required to qualify. For more information or to sign up, call (813) 275-3909.

TECO also offers time-of-use rates for customers that can shift their demand away from on-peak hours during the summer (April–October), 12–9 p.m., and winter (November–March), 6–10 a.m. and 6–10 p.m. For more information or to sign up, call 866-832-6249 or email mybusinessacount@tecoenergy.com.

Florida Power and Light's load management offerings include the following:

• The Commercial Demand Reduction (CDR) program provides substantial monthly credits to customers that demonstrate the ability to shed at least 200 kW by allowing FP&L to install direct load control devices on assorted equipment following a free audit. Credits are awarded regardless of whether FPL initiates a demand event. Advance notice of four hours or more is provided to participants. In the event of an emergency, customers are notified of curtailment events 15 minutes prior. Curtailment events occur during the summer season (April through October) from 3 to 6 p.m. and from 6 to 9 a.m. November through March. This program is available to customers in FPL's Region Territory only.
• Under the On Call® Savings Program, customers agree to let FPL occasionally cycle their air conditioners during peak demand times (3–6 p.m.) and in return receive a monthly bill credit of $2 per ton per month for each of the seven months of the program (April–October), even if the air conditioning is never turned off. The program has historically been activated three to four times per year. During an event, the customer's A/C may cycle off for 17.5 minutes per 30-minute period for a maximum of 3.5 hours per day. This program is available to customers in FPL's Region Territory only.
• The Custom Incentives program offers financial incentives for implementing energy-saving ideas (subject to FPL approval) that trim at least 25 kW of demand during FPL's peak demand periods (June–September). To find out if you qualify contact your FPL customer representative or the Businesses Care Center at 1-800-375-2434.
• FP&L also provides a set of Curtailable Service rates, in which customers agree to shed 200 kW or greater "from time to time" and are remunerated each month of the year. There are penalties for non-compliance with curtailment requests.

FPL also offers time-of-use rates to customers that can shift their demand away from on-peak hours during the summer (April through October) from 12 to 9 p.m. and during the winter (November through March) from 6 to 10 a.m. and p.m.

The former Gulf Power (which was recently acquired by NextEra Energy and merged with Florida Power & Light) offers many time-variable rate options specifically for commercial customers in its Northwest FL territory: 

• The General Service Demand Time of Use (GSDT) rate defines on-peak periods as non-holiday weekdays from 11 to 8 p.m. CT during the summer (April through October) and 5 to 9 a.m. and p.m. CT during the winter (November through March). This rate has specifications for customers whose demand ranges from 25-499 kW (GSDT-1), 500-1999 kW (GSLDT-1), and 2000+ kW (GSLDT-2).
• A special Electric Vehicle Infrastructure Rider (GSLD-1EV) is available to customers whose chargers have demand between 500 and 2000 kW. The monthly demand charge on this tariff is capped at the monthly consumption divided by 75 hours. Chargers must be monitored via a dedicated meter. 
• The Interruptible Service Rate (ISST-1) remunerates customers for allowing their service to be interrupted at any time, with one hour's notice, up to 25 times per year. In return, customers are levied much lower demand charges, based on the firm demand to which they're willing to reduce to during events.

Duke Energy (Duke) offers its Backup Power Systems program, in which customers grant the utility the right to control participants' generators during periods of extreme energy demands. Customers will be notified of events 24 hours prior. Remuneration is based on the capacity of the subscribed generator(s) and the frequency of events.

Duke offers time-of-use rates to its commercial and industrial customers. On-peak periods for TOU rates occur on non-holiday weekdays from 12–9 p.m. during the summer (April through October) and 6–10 a.m. and p.m. during the winter (November through March).

Georgia Power offers several load management opportunities:

• The company offers multiple time-of-use rate options to non-residential customers in Georgia. These rates provide utility bill savings for customers who can shift electricity use to off-peak hours, particularly during summer months. On-peak periods are defined as 2–7 p.m. on non-holiday weekdays during the summer (June through September).
• In addition, a number of real-time pricing programs are available. In one popular set of options under this service, customers are alternatively credited or charged for electricity usage below or above a pre-determined customer baseline load (CBL). Participants may choose to pay for these differences from their CBL based on either day-ahead or hour-ahead market pricing. Furthermore, customers may also select from a variety of price protection products, including caps, collars, contracts for differences, index swaps, and index caps. These variants on the basic real-time pricing service are risk management tools that customers can use as a hedge during periods of higher real-time electricity prices.
• Through Georgia Power's Demand Plus Energy Credit Rider (DPEC-5), customers are credited $2.53 per kW during summer months for reducing their demand by at least 200 kW, and are also remunerated for actual energy reductions at $0.092 per kWh. Bill credits are paid for reductions for the months of June through September. Load curtailment requests occur on non-holiday weekdays from 12 to 8 p.m. Curtailment requests can be issued with as little as 30 minutes' notice. A maximum of eight hours per day and 100 hours per year are subject to curtailment requests. There are significant penalties for non-compliance.

The TVA-Enel X Demand Response Program provides payments to participants in exchange for their agreeing to reduce electricity consumption with 30 minutes notice during times of exceptionally high demand. Demand response events may occur any day between the hours of 5 a.m. and 8 p.m. CT. Enel-X collaborates with customers to create an optimal demand reduction plan. Interested customers should contact their local electricity distributor.

The PJM Interconnection (PJM), a regional transmission organization (RTO), offers several demand response programs. Two specific programs may be attractive to federal facilities in the PJM footprint:

• PJM's Capacity Performance program allows demand resources to participate in PJM's Reliability Pricing Model (RPM) forward capacity market via an aggregator (any existing PJM member, such as their utility, a third-party electricity supplier, or a specialty curtailment service provider, CSP). Participants pledge to either reduce their load by a specified amount (guaranteed load drop, GLD), or to a specific kW level (known as firm service level, FSL), within one or two hours of an event notification. Load reductions are mandatory and may occur up to 10 times per year, lasting up to six hours per event. While events can be called any day of the year, some CSPs offer a summer-only option (pairing those resources with winter-only ones at their disposal). Penalties for non-compliance are substantial. Remuneration is based on the results of the annual RPM capacity auctions in various PJM regions. Remuneration levels for the 2023–24 PJM year (which runs from June 1, 2023, to May 31, 2024) are in the $12,000 per MW range for most Illinois customers. Participants are also eligible to receive energy payments for actual reductions, if and when the program is called.
• The Economic Load Response program allows electricity users to provide load reductions in exchange for a payment based on hourly wholesale electricity prices. Participation is fully voluntary. Customers start by submitting load reduction bids (through their CSP) of at least 100 kW into the day-ahead energy market. Participants whose bids are accepted are paid for their load reductions based upon the day-ahead, hourly electricity market prices (the day-ahead "locational marginal price," or LMP). Reductions are figured based on a customer baseline load (CBL), which is essentially the average loads for the same hours in four of the facility's previous non-responding days. Regardless of which type of firm it is, the CSP will generally offer to split the revenues with the customer at a pre-determined percentage.

In both programs, participants can provide load reductions either through curtailing electricity use or by operating on-site generation consistent with local environmental regulations and permits.

PJM also allows energy efficiency projects to participate in its forward capacity markets, based on the Reliability Pricing Model. To be eligible, energy efficiency projects must reduce load continuously by at least 100 kW during peak summer hours. This load reduction can be bid into PJM's annual (for three years in advance) and "residual" (nearer-term) capacity auctions, and if selected will receive the auction clearing price. Interested customers can participate through contractors such as energy service companies (conducting ESPCs) or utilities (executing UESCs) at their sites.

Customers in the footprint of MISO (the Midcontinent Independent System Operator) may enroll in MISO’s demand response offerings, from which they can receive payments for reducing load. Customers can participate via aggregators (including curtailment service providers, CSPs). 

ComEd's Voluntary Load Reduction (VLR) program pays customers for responding to individual load reduction requests of generally 2–8 hours with at least one-hour notice. Participants are notified of the payment level in advance of each event and are guaranteed at least $0.25 per kWh for their reduced usage. The program is open to any customer in ComEd's service territory, although electricity generation customers of ComEd are eligible for greater incentives. To participate, a customer must have an interval meter and be able to curtail at least 10 kW of peak load. Participation in curtailment events is voluntary.

ComEd commercial customers who do not opt for third-party supply are defaulted on to the company's Basic Electric Service Hourly Pricing (BESH), a real-time rate that floats with the wholesale electricity market in the area.

MidAmerican Energy offers its Curtailment program to its Illinois commercial and industrial customers who can reduce load by a minimum of 250 kW during peak demand periods. Curtailments generally take place from June through September (though can be called year-round) and last a maximum of six hours. Curtailment calls occur 2–6 hours in advance of required reductions. Curtailment incentives are based on the contracted kW to be reduced during peak periods and are payable as rebates at the end of the peak energy season.

MidAmerican Energy also offers time-of-use rate options to its non-residential customers who shift their energy usage away from peak hours (1–6 p.m.), weekdays from June through September, to off-peak hours (10 p.m.–8 a.m.).

Ameren offers its commercial/industrial customers the Hourly Supply Service (Rider HSS), an hourly priced option based on the relevant MISO delivery point. Small commercial customers are eligible to enroll in the company's Real Time Pricing (Rider RTP) offering, which is also based on the local hourly market. 

Ameren also offers the optional EV Rate Program for certain non-residential facilities (particularly, customers on rate schedules DS-2, DS-3, and DS-4). These rates offer steep discounts for charging fleets during Preferred Charging Periods (11 p.m. – 7 a.m.) and substantial discounts for charging fleets during Standard Charging Periods (7– 11 a.m. and 7– 11 p.m.). 

Utilities in the footprint of MISO (the Midcontinent Independent System Operator), such as Vectren (see below), may enroll interested customers in any of MISO's demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

Duke Energy's PowerShare program remunerates participants who can curtail at least 100 kW up to 5% of their total bill for reducing load below a customer-specific baseline during periods when the grid is compromised or when market prices are high. There are several options, including voluntary and mandatory ones. Payments are higher for the mandatory programs, but there is a penalty for not meeting the committed load shed during notified events.

Indiana Michigan Power (AEP) offers several interruptible and time-of-use options, including the Emergency Demand Response Rider, to its commercial and industrial customers in Indiana.

AEP also offers a General Service Plug-in Electric Vehicle tariff available to customers on Tariff GS who have averaged less than 4,500 kWh use per month in the previous 12 months. AEP offers two options under this rate, stand-alone PEV service and sub metered PEV Time-of-day. The stand-alone PEV service option offers substantial savings to customers who charge their fleet during off-peak hours (11 p.m. – 6 a.m.). The sub-metered PEV Time-of-day option offers credits to customers' bills for all off-peak PEV charging measured. 

AES Indiana offers various curtailable riders (particularly, riders 14–18 and 22–23) that permit customers to take advantage of credits both for capacity (contracted kW) and energy (actual kWh curtailed during events) in exchange for curtailing consumption or using their generators in times of grid emergencies or high wholesale power prices.

AES Indiana also offers CoolCents^©, a direct load control program that remunerates customers up to $60 each summer per air conditioning unit for the right to cycle the unit's compressor via a smart thermostat. As a smart thermostat is required for participation, interested customers can receive a free Nest Thermostat from AES if interested in participating in the program. 

Vectren (Southern Indiana Gas and Electric) encourages its customers to participate in demand response programs sponsored by MISO (see above) and also offers several interruptible riders to its commercial customers, along with a direct load control air conditioner cycling program ("Rider DLC") that remunerates commercial customers at the following levels: $5 per month for each electric air conditioner or heat pump of five tons or less; $4 per month per kW for each electric air conditioner or heat pump greater than five tons; and $2 per month for each electric water heater. The DLC rider is applicable from June through September.

Wabash Valley Power, a generation and transmission utility, provides incentives to its numerous northern Indiana distribution cooperatives for demand response through its Power Shift initiative. Most of these distribution cooperatives offer interruptible options to their large customers. Consult with your cooperative’s representative to learn what opportunities are available.

The PJM Interconnection (PJM), a regional transmission organization (RTO), offers several demand response programs. Two specific programs may be attractive to federal facilities in the PJM footprint:

• PJM's Capacity Performance program allows demand resources to participate in PJM's Reliability Pricing Model (RPM) forward capacity market via an aggregator (any existing PJM member, such as their utility, a third-party electricity supplier, or a specialty curtailment service provider, CSP). Participants pledge to either reduce their load by a specified amount (guaranteed load drop, GLD), or to a specific kW level (known as firm service level, FSL), within one or two hours of an event notification. Load reductions are mandatory and may occur up to 10 times per year, lasting up to six hours per event. While events can be called any day of the year, some CSPs offer a summer-only option (pairing those resources with winter-only ones at their disposal). Penalties for non-compliance are substantial. Remuneration is based on the results of the annual RPM capacity auctions in various PJM regions. Remuneration levels for the 2023–24 PJM year (which runs from June 1, 2023, to May 31, 2024) are in the $12,000 per MW range for Indiana customers. Participants are also eligible to receive energy payments for actual reductions, if and when the program is called.
• The Economic Load Response program allows electricity users to provide load reductions in exchange for a payment based on hourly wholesale electricity prices. Participation is fully voluntary. Customers start by submitting load reduction bids (through their CSP) of at least 100 kW into the day-ahead energy market. Participants whose bids are accepted are paid for their load reductions based upon the day-ahead, hourly electricity market prices (the day-ahead "locational marginal price," or LMP). Reductions are figured based on a customer baseline load (CBL), which is essentially the average loads for the same hours in four of the facility's previous non-responding days. Regardless of which type of firm it is, the CSP will generally offer to split the revenues with the customer at a pre-determined percentage.

In both programs, participants can provide load reductions either through curtailing electricity use or by operating on-site generation consistent with local environmental regulations and permits.

PJM also allows energy efficiency projects to participate in its forward capacity markets, based on the Reliability Pricing Model. To be eligible, energy efficiency projects must reduce load continuously by at least 100 kW during peak summer hours. This load reduction can be bid into PJM's annual (for three years in advance) and "residual" (nearer-term) capacity auctions, and if selected will receive the auction clearing price. Interested customers can participate through contractors such as energy service companies (conducting ESPCs) or utilities (executing UESCs) at their sites.

Alliant Energy's Interruptible Service Option rider offers customers bill credits in exchange for reducing consumption during peak periods when called. Participants receive a credit of $5.37/kW for curtailment commitments during summer months and $3.46/kW during winter months. Customers are typically given two-hour notice to reduce usage to a pre-determined level, and must be able to curtail at least 200 kW during events.

Alliant also offers Time of Day Pricing for Iowa business customers to take advantage of significantly lower electricity prices during off-peak hours. Off-peak hours are from 8 p.m.–7 a.m. on weekdays, and all weekend. Usage is billed at a 60% discount to peak hours (7 a.m.–8 p.m.). The program requires the installation of a smart meter that the customer pays for through a minimal monthly charge. In the case that the business does not realize a reduction in electricity costs, Alliant will remove the smart meter and reinstall a standard meter free of charge.

MidAmerican Energy offers its Curtailment program to commercial and industrial customers able to reduce load by a minimum of 250 kW during peak demand periods. Curtailments generally take place between June and September (though can be called year-round) and last a maximum of six hours. Curtailment calls occur two to six hours in advance of required reductions. Curtailment incentives are based on the contracted kW to be reduced during peak periods and are payable as rebates at the end of the peak energy season.

MidAmerican also offers its commercial and industrial customers a set of optional time-of-use rates with very large (up to four to five times) differences in kWh prices between off-peak (10 p.m.–8 a.m. every day) and peak (1–6 p.m. weekdays) energy usage in the summer. Other hours (8 a.m.–1 p.m. and 6–10 p.m. on weekdays, as well as non-off-peak hours on weekends and holidays) are also heavily discounted relative to peak prices.

Utilities in the footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

Duke Energy offers several load management opportunities that may be of interest to federal customers.

• The Peak Load Management program offers negotiated incentives for small- to mid-sized customers (< 500 kW) to reduce load during the utility's peak periods. Participants must reduce their demand down to a firm level upon being notified by the company.
• The PowerShare program provides financial incentives for reducing energy consumption levels during peak use periods. Customers may choose from a variety of curtailment options, including voluntary and mandatory load drops. The minimum curtailment is 100 kW. There are also options to participate with self-generation equipment and to tailor the program for the number of events your site is willing to participate in each year. Incentives range up to 5% off monthly bills for participating customers.
• Duke offers time-of-use rates to its medium voltage (< 34,500 volts) commercial customers with an average monthly demand of at least 500 kW, as well as to customers who take their electricity at transmission voltage (> 69,000 volts). Off-peak hours are: 8 p.m.–11 a.m. in the summer; 9 p.m.–9 a.m. and 2–5 p.m. in the winter.
• Duke offers a set of real-time pricing options through its PathWise™ initiative. For more information on the PathWise^TM, email BSCteam@duke-energy.com.
• Duke customers can enroll in the Load Management Rider. This billing mechanism allows customers to be assessed for only their peak power draw during the company's peak period hours (i.e., the "coincident" peak), such that off-peak demand is not penalized. This rate is tailored for sites, such as those with thermal energy storage (TES), that can shift substantial load to off-peak periods. Summer off-peak hours are from 8 p.m. to 11 a.m., Monday to Friday; winter off-peak hours are from 2 to 5 p.m. and 9 p.m. to 9 a.m. during weekdays. All hours on weekends and holidays are considered off-peak, as well.
• Duke customers can also participate in the Peak Load Management Program (Rider PLM), very similar to the Load Management Rider (above). This program offers customers the opportunity to reduce costs by managing their electric usage during the company's peak load periods. This rate is available to customers served under Rate DS, DT, DP, TT, or special contracts, whose billing period 15-minute demands are less than 500 kW. The specific hours for the PLM service option will be mutually agreed upon between the customer and company and specified in the service agreement. 

The TVA-Enel X Demand Response Program provides payments to participants in exchange for their agreeing to reduce electricity consumption with 30 minutes notice during times of exceptionally high demand. Demand response events may occur any day between the hours of 5 a.m.–8 p.m. CT. Enel-X collaborates with customers to create an optimal demand reduction plan. Interested customers should contact their local electricity distributor.

The PJM Interconnection (PJM), a regional transmission organization (RTO), offers several demand response programs. Two specific programs may be attractive to federal facilities in the PJM footprint:

• PJM's Capacity Performance program allows demand resources to participate in PJM's Reliability Pricing Model (RPM) forward capacity market via an aggregator (any existing PJM member, such as their utility, a third-party electricity supplier, or a specialty curtailment service provider, CSP). Participants pledge to either reduce their load by a specified amount (guaranteed load drop, GLD), or to a specific kW level (known as firm service level, FSL), within one or two hours of an event notification. Load reductions are mandatory and may occur up to 10 times per year, lasting up to six hours per event. While events can be called any day of the year, some CSPs offer a summer-only option (pairing those resources with winter-only ones at their disposal). Penalties for non-compliance are substantial. Remuneration is based on the results of the annual RPM capacity auctions in various PJM regions. Remuneration levels for the 2023–24 PJM year (which runs from June 1, 2023, to May 31, 2024) are in the $12,000 per MW range for Kentucky customers. Participants are also eligible to receive energy payments for actual reductions, if and when the program is called.
• The Economic Load Response program allows electricity users to provide load reductions in exchange for a payment based on hourly wholesale electricity prices. Participation is fully voluntary. Customers start by submitting load reduction bids (through their CSP) of at least 100 kW into the day-ahead energy market. Participants whose bids are accepted are paid for their load reductions based upon the day-ahead, hourly electricity market prices (the day-ahead "locational marginal price," or LMP). Reductions are figured based on a customer baseline load (CBL), which is essentially the average loads for the same hours in four of the facility's previous non-responding days. Regardless of which type of firm it is, the CSP will generally offer to split the revenues with the customer at a pre-determined percentage.

In both programs, participants can provide load reductions either through curtailing electricity use or by operating on-site generation consistent with local environmental regulations and permits.

PJM also allows energy efficiency projects to participate in its forward capacity markets, based on the Reliability Pricing Model. To be eligible, energy efficiency projects must reduce load continuously by at least 100 kW during peak summer hours. This load reduction can be bid into PJM's annual (for three years in advance) and "residual" (nearer-term) capacity auctions, and if selected will receive the auction clearing price. Interested customers can participate through contractors such as energy service companies (conducting ESPCs) or utilities (executing UESCs) at their sites.

Utilities in the western Kentucky footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

Entergy offers various interruptible riders, including the following:

• The Experimental Energy Reduction Service Rider is available to customers who can curtail at least 150 kW. The company will post hourly day-ahead energy pricing for the curtailable hours on the following day. Enrolled customers can choose to participate at their discretion. If the customer chooses to submit a proposal for participation, the company then has the right to accept or reject the customer’s curtailment proposal.
• The General Service Time of Day Rate provides utility bill savings for customers who can shift electricity use to off-peak hours, particularly during the summer. On-peak summer hours are defined as 1–9 p.m., Monday–Friday, from May 15 to October 15. On-peak winter hours are defined as 6–10 a.m. and 6–10 p.m., Monday–Friday, from October 16 to May 14.
• The High Load Factor Service Time of Day and Large Power Service Time of Day rates are available to customers who contract for at least 2,500 kW of electric service. These rates provide utility bill savings for customers who can shift electricity use to off-peak hours, particularly during the summer. On-peak summer hours are defined as 1–9 p.m., Monday–Friday, from May 15 to October 15. On-peak winter hours are defined as 6–10 a.m. and 6–10 p.m., Monday–Friday, from October 16 to May 14.

Utilities in the footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

DTE Energy offers interruptible rates to all its commercial and industrial customers. Electricity is discounted in exchange for interruptibility in times of system need or when wholesale prices are high. Interruptible rate discounts vary from approximately 10% to 25% depending on the tariff. To participate, customers must agree to shed a minimum of 50 kW and interrupt within one hour of notification. Failure to interrupt results in a penalty for all usage above the customer's committed firm demand level (i.e., on top of the prescribed monthly rate) during the interruption period.

DTE's commercial/industrial customers can also take advantage of a "critical peak pricing" option (a time-of-use rate where peak prices are several times higher on announced peak days but lower at all other times), an electric vehicle rate, and a direct load control option (Interruptible Space Conditioning).  All of these rates' terms are summarized.

Xcel Energy offers the Electric Rate Savings program, which provides reduced demand charges for peak demand reduction at commercial and industrial facilities that can cut load by 50 kW or more during peak periods, primarily in the summer (though customers can be called on to reduce anytime during the year). Participating customers receive a per-kW discount on controllable demand every month, but in exchange must commit to reducing their load to a pre-determined level, usually for four to eight hours. There is a penalty for non-compliance.

Xcel customers can also take advantage of the company's interruptible gas rate, which offers discounted natural gas for customers who can reduce their gas usage within one hour's notice. 

Wisconsin Public Service Corp. (WPSC) provides several options for customers with load management capability:

• WPSC offers an interruptible rider, CP-1. Participants contract for a 200 kW or greater load reduction (with curtailability up to 600 hours/yr.) subject to WPSC's determination of either economic or emergency conditions on the grid. In exchange, the customer receives reduced rates for its monthly peak demand.
• WPSC provides a time-of-use option with attractive terms for customers who can switch a significant portion of their usage to off-peak periods.
• WPSC also sponsors a Direct Control Rider, through which it remunerates customers up to $8 per unit per summer month for the ability to control their packaged air conditioners, and $3 per month (throughout the year) for controlling electric storage water heaters (40 gallons and above).

Upper Peninsula Power Company offers both a standard interruptible rider, in which participants pay lower demand charges for committing to reduce their load to a firm service level (with at least one hour's notice) during events, and a real-time pricing option for customers over 1,000 kW.

Customers in the footprint of MISO (the Midcontinent Independent System Operator) may enroll in MISO's demand response offerings, from which they can receive payments for reducing load. Both retail choice and utility supply customers with peak demand over 1MW can participate via aggregators (including curtailment service providers, CSPs) unless they are participating in another utility tariff or program that would constitute double counting (e.g., interruptible tariffs).

The PJM Interconnection (PJM), a regional transmission organization (RTO), offers several demand response programs. Two specific programs may be attractive to federal facilities in the PJM footprint:

• PJM's Capacity Performance program allows demand resources to participate in PJM's Reliability Pricing Model (RPM) forward capacity market via an aggregator (any existing PJM member, such as their utility, a third-party electricity supplier, or a specialty curtailment service provider, CSP). Participants pledge to either reduce their load by a specified amount (guaranteed load drop, GLD), or to a specific kW level (known as firm service level, FSL), within one or two hours of an event notification. Load reductions are mandatory and may occur up to 10 times per year, lasting up to six hours per event. While events can be called any day of the year, some CSPs offer a summer-only option (pairing those resources with winter-only ones at their disposal). Penalties for non-compliance are substantial. Remuneration is based on the results of the annual RPM capacity auctions in various PJM regions. Remuneration levels for the 2023–24 PJM year (which runs from June 1, 2023, to May 31, 2024) are in the $12,000 per MW range for customers in PJM's southwest Michigan footprint (AEP), depending on location. Participants are also eligible to receive energy payments for actual reductions, if and when the program is called.
• The Economic Load Response program allows electricity users to provide load reductions in exchange for a payment based on hourly wholesale electricity prices. Participation is fully voluntary. Customers start by submitting load reduction bids (through their CSP) of at least 100 kW into the day-ahead energy market. Participants whose bids are accepted are paid for their load reductions based upon the day-ahead, hourly electricity market prices (the day-ahead "locational marginal price," or LMP). Reductions are figured based on a customer baseline load (CBL), which is essentially the average loads for the same hours in four of the facility's previous non-responding days. Regardless of which type of firm it is, the CSP will generally offer to split the revenues with the customer at a pre-determined percentage.

In both programs, participants can provide load reductions either through curtailing electricity use or by operating on-site generation consistent with local environmental regulations and permits.

PJM also allows energy efficiency projects to participate in its forward capacity markets, based on the Reliability Pricing Model. To be eligible, energy efficiency projects must reduce load continuously by at least 100 kW during peak summer hours. This load reduction can be bid into PJM’s annual (for three years in advance) and "residual" (nearer-term) capacity auctions, and if selected will receive the auction clearing price. Interested customers can participate through contractors such as energy service companies (conducting ESPCs) or utilities (executing UESCs) at their sites.

Mississippi Power offers a few different time-of-use rates to commercial and industrial customers:

• The Large General Service TOU Rate (GS-TOU-17) and Large Power TOU Electric Service Rate (LPO-TOU-16) both charge increased rates during peak periods. Peak periods are 12-8 p.m. Monday through Friday from April through October, and 6–10 a.m. and 6–10 p.m. Monday through Friday from November through March.

The TVA-Enel X Demand Response Program provides payments to participants in exchange for their agreeing to reduce electricity consumption with 30 minutes notice during times of exceptionally high demand. Demand response events may occur any day between the hours of 5 a.m.–8 p.m. CT. Enel-X collaborates with customers to create an optimal demand reduction plan. Interested customers should contact their local electricity distributor.

Utilities in the footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

Evergy, formed from the merger of KCP&L and Westar Energy, offers its Business Demand Response program, which provides a credit on summer energy bills in exchange for reducing electrical usage for as many as eight hours on up to 10 summer weekdays, between 12–8 p.m. Program participants earn $28 per each kW they commit to and achieve (on average over the summer), adjusted for over- (up to 110%) and under- (down to 40%) performance. Contact Evergy's demand response team at (816) 227-6399 for more information and to confirm that the program is accepting new applicants in your service area.

Ameren Missouri offers its Demand Response Program using Enel X, an aggregator (also known as a curtailment service provider, or CSP). One- to four-hour events can be called (with at least one hour's notice) anytime May to September; events generally take place between 3–7 p.m. A minimum of two events and maximum of 15 events will be called per program season. Participants agree to curtail usage according to their customized (with Enel X) "energy reduction plan," and in exchange receive bill credits commensurate with these reductions.

Ameren's Large Primary Service and other commercial and industrial customer rates provide customers with an optional time-of-day adjustment that offers significant differences in on- and off-peak rates, particularly in the summer. Also, summer (June through September) demand charges (over $19/kW-mo. for Large Primary Service) are roughly two times those during winter months.

Utilities in the eastern Missouri footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

Duke Energy offers three demand response programs that may be of interest to federal customers:

• The PowerShare program provides financial incentives for reducing energy consumption levels during peak use periods. Customers may choose from a variety of curtailment options, including voluntary and mandatory load drops. The minimum curtailment is 100 kW. There are also options to participate with self-generation equipment and to tailor the program for the number of events your site is willing to participate in each year. Incentives range up to 8% off monthly bills for participating customers. Customers enrolled in the voluntary option are notified a day prior to curtailment events, while mandatory option customers receive 15–30 minutes advance notice. There are penalties for failure to perform under the mandatory and self-generation options. Note: customers located in the Duke Energy Progress area are not eligible for this program.
   
• The On-Site Generation Service Program targets customers that do not currently own back-up generation but would like to. Duke will install, own, and operate new generators (300 kW or larger) for participants willing to let the company use them in times of grid stress or high wholesale prices. There is a monthly service fee for this rate based on the levelized cost to own and operate the equipment. Note: customers located in the Duke Energy Progress area are not eligible for this program.

• Small and medium commercial customers can enroll in the EnergyWise^® Business program and save on energy costs by allowing Duke to temporarily reduce energy consumption during times of high demand called "conservation periods." Two enrollment options are available through EnergyWise® Business

  • Winter – Bring Your Own kW: This program offers participants two options, manual and automatic. The manual option allows the customers to decide on how much electrical load to reduce at their business during peak usage events. This is a payforperformance program, i.e., the more you reduce the more you earn. With the automatic option, the customer connects their equipment to receive event communications and determines how the equipment will respond during peak usage events. Compensation levels for participating customers vary based on degree of participation. 
  • Summer – Load Control: This program provides the installation of new Wi-Fi programmable thermostats or cellular switch. Duke Energy will reduce a customer’s AC operation by sending a signal to cycle off and on the demand from a customer’s central air conditioning unit or electric heat pump. Conservation periods occur during the summer weekdays from May through September. Duke typically cycles units for 10–15 minute intervals for up to four hours. Cycling will not exceed more than 40 hours for any summer season. Compensation levels for participating customers vary based on what percentage the customer allows the utility to cycle their equipment. There is no cost for customers to enroll and participate in the program. Customers may choose up to two days per summer season to override the cycling of their facility’s equipment.

In addition, Duke offers a suite of tariffs that reward load management abilities. For example:

• The Optional Power Service Time-of-Use rate is available for non-residential customers in North Carolina. This rate provides utility bill savings (particularly, reduced demand charges) for customers who can shift electricity use to off-peak hours, particularly during summer months. On-peak hours are defined as 1–9 p.m., Monday–Friday, from June 1 to September 30, and 6 a.m.–1 p.m., Monday–Friday, October 1 to May 31.
• Real-time pricing is available to Duke Energy's large customers (demand of 1,000 kW or greater) through its NC Hourly Pricing for Incremental Load rate schedule. Customers are notified of the hourly energy prices for the following day and are alternatively credited or charged, based on the hourly price, for usage below or above a pre-determined customer baseline load profile.

Duke Energy Progress customers can participate in the following programs, rates and riders:

• Customers can enroll in the Demand Response Automation (DRA-9) rider and commit to a "contracted curtailable demand" of 50 kW or greater during peak demand periods in the summer (April through September) and winter (December through February). The customer can allow Duke Energy to install a load control device and remotely control the customer’s electrical equipment, or just manually curtail its load upon notification of a curtailment event. Events last no more than eight hours and occur a maximum of 10 times per year. Customers will receive a minimum of 30 minutes notice before an event is called by the utility. Customers are not subjected to the 50 kW minimum contracted curtailable demand in the winter.
• The General Service Thermal Energy Storage rate (GS-TES-72) is available to customers who use thermal storage equipment  to shift load away from on-peak periods in the summer from 12–8 p.m. (April through September) and winter from 6 a.m.–1 p.m. (October through March). This rate is available to customers with a peak load of 4,000 kW or less.
• The Large Load Curtailable Rider (LLC-6) is available to customers who can reduce their load by a contracted amount during curtailment periods. These periods last no longer than eight hours and may occur during on- or off-peak hours. The total hours of curtailment periods will be no more than 400 per calendar year. On-peak hours occur weekdays in the summer from 10 a.m.–10 p.m., and in the winter from 6 a.m.–1 p.m. and 4–9 p.m. Customers are notified a minimum of 30 minutes before a curtailment period.
• Duke offers a variety of time-of-use rates to customers who can reduce energy costs by shifting load away from on-peak periods.

Dominion Energy offers a set of tariffs that reward commercial and industrial customers that can shift their load away from on-peak hours.

The PJM Interconnection (PJM), a regional transmission organization (RTO), offers several demand response programs. Two specific programs may be attractive to federal facilities in the PJM footprint:

• PJM's Capacity Performance program allows demand resources to participate in PJM's Reliability Pricing Model (RPM) forward capacity market via an aggregator (any existing PJM member, such as their utility, a third-party electricity supplier, or a specialty curtailment service provider, CSP). Participants pledge to either reduce their load by a specified amount (guaranteed load drop, GLD), or to a specific kW level (known as firm service level, FSL), within one or two hours of an event notification. Load reductions are mandatory and may occur up to 10 times per year, lasting up to six hours per event. While events can be called any day of the year, some CSPs offer a summer-only option (pairing those resources with winter-only ones at their disposal). Penalties for non-compliance are substantial. Remuneration is based on the results of the annual RPM capacity auctions in various PJM regions. Remuneration levels for the 2023–24 PJM year (which runs from June 1, 2023, to May 31, 2024) are in the $12,000 per MW range for customers in PJM's northeastern North Carolina footprint. Participants are also eligible to receive energy payments for actual reductions, if and when the program is called.
• The Economic Load Response program allows electricity users to provide load reductions in exchange for a payment based on hourly wholesale electricity prices. Participation is fully voluntary. Customers start by submitting load reduction bids (through their CSP) of at least 100 kW into the day-ahead energy market. Participants whose bids are accepted are paid for their load reductions based upon the day-ahead, hourly electricity market prices (the day-ahead "locational marginal price," or LMP). Reductions are figured based on a customer baseline load (CBL), which is essentially the average loads for the same hours in four of the facility's previous non-responding days. Regardless of which type of firm it is, the CSP will generally offer to split the revenues with the customer at a pre-determined percentage.

In both programs, participants can provide load reductions either through curtailing electricity use or by operating on-site generation consistent with local environmental regulations and permits.

PJM also allows energy efficiency projects to participate in its forward capacity markets, based on the Reliability Pricing Model. To be eligible, energy efficiency projects must reduce load continuously by at least 100 kW during peak summer hours. This load reduction can be bid into PJM's annual (for three years in advance) and "residual" (nearer-term) capacity auctions, and if selected will receive the auction clearing price. Interested customers can participate through contractors such as energy service companies (conducting ESPCs) or utilities (executing UESCs) at their sites.

The PJM Interconnection (PJM), a regional transmission organization (RTO), offers several demand response programs. Two specific programs may be attractive to federal facilities in the PJM footprint:

• PJM's Capacity Performance program allows demand resources to participate in PJM's Reliability Pricing Model (RPM) forward capacity market via an aggregator (any existing PJM member, such as their utility, a third-party electricity supplier, or a specialty curtailment service provider, CSP). Participants pledge to either reduce their load by a specified amount (guaranteed load drop, GLD), or to a specific kW level (known as firm service level, FSL), within one or two hours of an event notification. Load reductions are mandatory and may occur up to 10 times per year, lasting up to six hours per event. While events can be called any day of the year, some CSPs offer a summer-only option (pairing those resources with winter-only ones at their disposal). Penalties for non-compliance are substantial. Remuneration is based on the results of the annual RPM capacity auctions in various PJM regions. Remuneration levels for the 2023–24 PJM year (which runs from June 1, 2023, to May 31, 2024) are in the $12,000 per MW range for Ohio customers. Participants are also eligible to receive energy payments for actual reductions, if and when the program is called.
• The Economic Load Response program allows electricity users to provide load reductions in exchange for a payment based on hourly wholesale electricity prices. Participation is fully voluntary. Customers start by submitting load reduction bids (through their CSP) of at least 100 kW into the day-ahead energy market. Participants whose bids are accepted are paid for their load reductions based upon the day-ahead, hourly electricity market prices (the day-ahead "locational marginal price," or LMP). Reductions are figured based on a customer baseline load (CBL), which is essentially the average loads for the same hours in four of the facility's previous non-responding days. Regardless of which type of firm it is, the CSP will generally offer to split the revenues with the customer at a pre-determined percentage.

In both programs, participants can provide load reductions either through curtailing electricity use or by operating on-site generation consistent with local environmental regulations and permits.

PJM also allows energy efficiency projects to participate in its forward capacity markets, based on the Reliability Pricing Model. To be eligible, EE projects must reduce load continuously by at least 100 kW during peak summer hours. This load reduction can be bid into PJM’s annual (for three years in advance) and "residual" (nearer-term) capacity auctions, and if selected will receive the auction clearing price. Interested customers can participate through contractors such as energy service companies (conducting ESPCs) or utilities (executing UESCs) at their sites.

Duke Energy customers can participate in the following programs and riders:

• Duke offers a set of real-time pricing options through its PathWise™ initiative. For more information on the Pathwise™ program, contact BSCteam@duke-energy.com.
• Duke customers can participate in the Load Management Rider (Rider LM). This billing mechanism allows customers to be assessed for only their peak power draw during the company's peak period hours (i.e., the "coincident" peak), such that off-peak demand spikes are not penalized.  This rate is tailored for sites, such as those with thermal energy storage (TES), that can shift substantial load to off-peak periods.  Summer off-peak hours are from 8 p.m. –11 a.m., Monday to Friday (June 1 to September 30); winter off-peak hours are from 2–5 p.m. and 9 p.m.–9 a.m. during weekdays. All hours on weekends and holidays are considered off-peak, as well.
• Duke customers can enroll in the voluntary Peak Load Management Program (Rider PLM) to reduce their costs by shifting their electric usage away from peak periods (from 11 a.m.–8 p.m., Monday to Friday, during the summer, and 7 a.m.–1 p.m., Monday to Friday, during winter).
• The Real Time Pricing program (Rate RTP) allows customers to lower their electricity costs by either shifting load from higher to lower cost pricing periods and adding new load during lower cost pricing periods or by learning about market pricing. Binding price quotes will be sent to each customer on a day-ahead basis.
• The Thermal Energy Storage Rider (Rider TES) allows customers who have installed a thermal storage cooling system to enter into a service agreement with Duke that specifies the kW of load to be shifted away from on-peak periods. These periods occur during the summer (June 1 to September 30) from 11 a.m.–8 p.m., Monday to Friday, excluding legal holidays.

Ohio’s First Energy subsidiary utilities (Ohio Edison, Toledo Edison, and The Illuminating Company) offer real-time and combination fixed and variable (e.g., "block-and-swing") electric rate products.

Oklahoma Gas and Electric Company (OGE) offers several large business rates for load management:

• The Day Ahead Pricing (or variable peak pricing) program allows customers to be credited or charged, based upon day-ahead notification of hourly energy prices, for usage below or above a pre-determined customer baseline load profile.
• The Flex Pricing program offers lower total electricity costs for facilities that are able to reduce usage during peak hours (2–7 p.m. weekdays, June 1 through September 30) or shift load to off-peak hours, when the rate is substantially lower.
• The Load Reduction program is available to customers who can curtail load when notified of peak events by OGE. The customer chooses the amount of demand reduction and receives a billing discount for the pledged reduction. The rider is available in conjunction with the Day Ahead Pricing tariff (above), subject to special conditions.
• The Electric Vehicle Time-of-Use rate allows customers to save on energy costs by shifting the charging of electric vehicles away from on-peak hours (2–7 p.m. weekdays excluding company-observed holidays). 

Public Service Company of Oklahoma's Peak Performers program offers incentives for voluntarily reducing energy use for 2–4 hours on no more than 16 "peak event" days per summer. Peak events occur between June 1 and September 30 from the hours of 1 to 7 p.m. on any weekday (excluding holidays). Once per year, PSO will pay participants an average of $32 per kilowatt enrolled in the program. Customers receive notification at least two hours prior to a peak event. Incentives are based on the average kW saved over all peak event days. Contact PSO at 888-776-1366 for more information or to apply.

Duke Energy offers several load management programs. The program availability depends on the service territory. The following programs are available for Duke Energy Carolinas customers:

• The PowerShare program provides financial incentives for reducing energy consumption levels during peak use periods. Customers may choose from a variety of curtailment options, including voluntary and mandatory load drops. The minimum curtailment is 100 kW. There are also options to participate with self-generation equipment and to tailor the program for the number of events your site is willing to participate in each year. Incentives range up to 8% off monthly bills for participating customers. These incentives include monthly Energy Credits based on curtailment. Mandatory and generator curtailment customers are provided a Capacity Credit even if there are no curtailment periods during the month. Customers enrolled in the voluntary option are typically notified a day prior to curtailment events, while mandatory and generator curtailment option customers receive a minimum 15 to 30 minutes notice. There are penalties for failure to perform under the mandatory and self-generation options. Note: customers located in the Duke Energy Progress area are not eligible for this program. 
• The On-Site Generation Service Program targets customers that do not currently own back-up generation but would like to. Duke will install, own, and operate new generators (300 kW or larger) for participants willing to let the company use them in times of grid stress or high wholesale prices. There is a monthly service fee for this rate based on the levelized cost to own and operate the equipment. Note: customers located in the Duke Energy Progress area are not eligible for this program.
• Small and medium commercial customers enrolled in the EnergyWise^® Business program can save on costs by temporarily reducing energy consumption during times of high energy demand called "conservation periods." Customers can decide between participating in the winter or summer enrollment options. For winter enrollment, customers can choose how much electrical load to reduce during a peak event. Winter program events may occur for up to four hours per day between October and April. Customers are given at least four hours' notice prior to the start of each event. With summer enrollment, Duke Energy provides customers with a new Wi-Fi programmable thermostat and controls the customers' cooling energy usage during times of peak demand. This is done by sending a signal to cycle off and on the demand from a customer's central air conditioning unit or electric heat pump. 
• Conservation periods may occur for up to four hours each day from May through September. Duke typically cycles units for 10-15 minute intervals for up to four hours. Compensation levels for participating customers vary based on what percentage the customer allows the utility to cycle their equipment. Customers may choose up to two days per summer season to override the cycling of their equipment. For either season, there is no cost for customers to enroll and participate in the program, and events will not exceed a total of 40 hours.

In addition, Duke offers a suite of tariffs that reward load management abilities for the Duke Energy Carolinas area. For example:

• Real-time pricing is available to Duke Energy's large customers (demand of 1,000 kW or greater) through its SC Hourly Pricing for Incremental Load rate schedule. Customers are notified of the hourly energy prices for the following day and are alternatively credited or charged, based on the hourly price, for usage below or above a pre-determined customer baseline load profile.
• The Optional Power Service, Time-of-Use rate is available for non-residential customers in South Carolina. This rate provides utility bill savings for customers who can shift electricity use to off-peak hours, particularly during summer months. On-peak hours are defined as 1–9 p.m, Monday – Friday, from June 1 to September 30, and 6 a.m. – 1 p.m., Monday – Friday, October 1 to May 31.

Duke Energy Progress customers can participate in the following programs and riders:

• Customers can enroll in the Demand Response Automation (DRA-10) rider and commit to a "contracted curtailable demand" of 50 kW or greater during peak demand periods in the summer (June through September) and winter (December through February). The customer can allow Duke Energy to install a load control device and remotely control the customer's electrical equipment, or forgo Duke Energy's remote load control device and manually curtail its load upon notification that a curtailment event is being declared. Curtailment events last no more than eight hours and occur no more than ten times per year. Customers will receive a minimum of 30 minutes notice before an event is called by the utility. Customers are not subjected to the 50 kW minimum in the winter.
• The Large Load Curtailable Rider LLC is available to customers who can reduce their load by a contracted amount during curtailment periods. These periods last no longer than eight hours and may occur during on- or off-peak hours. The total hours of curtailment periods will be no more than 400 during a calendar year. On-peak hours occur weekdays in the summer from 6 a.m. to 9 p.m., and from 6 to 9 a.m. during the rest of the year. Customers are notified a minimum of 30 minutes before a curtailment period.
• Duke also offers a variety of time-of-use rates to customers who can reduce energy costs by shifting load away from on-peak periods.

The following programs are available for customers in both the Duke Energy Carolinas and Duke Energy Progress areas:

• Small and medium commercial customers enrolled in the EnergyWise^® Business program can save on costs by temporarily reducing energy consumption during times of high energy demand called "conservation periods." Customers can decide between participating in the winter or summer enrollment options. For winter enrollment, customers can choose how much electrical load to reduce during a peak event. Winter program events may occur for up to four hours per day between October and April. Customers are given at least four hours' notice prior to the start of each event. With summer enrollment, Duke Energy provides customers with a new Wi-Fi programmable thermostat and controls the customers' cooling energy usage during times of peak demand. This is done by sending a signal to cycle off and on the demand from a customer's central air conditioning unit or electric heat pump. Conservation periods may occur for up to four hours each day from May through September. Duke typically cycles units for 10–15 minute intervals for up to four hours. Compensation levels for participating customers vary based on what percentage the customer allows the utility to cycle their equipment. Customers may choose up to two days per summer season to override the cycling of their equipment. For either season, there is no cost for customers to enroll and participate in the program, and events will not exceed a total of 40 hours.
• The Small General Service Time of Use Rate program is available to customers with a demand of 30 kW or less. Customers can save money by shifting energy usage away from peak electric use periods. The year is split between the cooling (April through September) and heating season (October through March). The cooling season's on-peak rates are from 1 to 6 p.m. on weekdays, with "shoulder" rates in effect from 11 a.m. to 1 p.m. and 6 to 8 p.m. All other times, including weekends and holidays, are off-peak. The heating season's on-peak rates are from 6 to 9 a.m., with shoulder rates from 9 a.m. to 12 p.m. and 5 to 8 p.m. Customers can receive a digital electric meter upgrade at no cost to them.

Dominion Energy offers the Interruptible Service rider to large commercial and industrial facilities that can commit to reduce 1,000 kW or greater during periods of peak demand. On-peak periods occur weekdays from 6 A.M. to 12 P.M. between November and April, and from 1 to 9 P.M. May to October. Customers are notified of curtailment periods at least four hours prior to an interruption, except during a system emergency when as little as ten minutes notice is given.

Dominion also offers a set of time-of-use rates to commercial and industrial customers. 

The (Tennessee Valley Authority (TVE) TVA-Enel X Demand Response Program provides payments to participants in exchange for their agreement to reduce electricity consumption with 30 minutes notice during times of exceptionally high demand. Demand response events may occur between 5 a.m. and 8 p.m. year-round. Enel-X collaborates with customers to create an optimal demand reduction plan. Interested customers should contact their local electricity distributor.

Appalachian Power offers two demand response options to its large commercial customers:

• The Peak Shaving Demand Response Rider is a winter-only interruptible/curtailable program in which customers agree to up to 10 curtailments (of no more than six hours per event) between December and March. Customers must commit to either 1) a "guaranteed load drop" of at least 250 kW from a "customer baseline load" (based on consumption during the same hours in the four highest of five similar recent non-event days) or 2) a "firm service level" (kW) that they will not exceed during events. Customers must have at least 250 kW of curtailment capacity to participate. Participants receive a minimum of 90 minutes' prior notification before a curtailment event is called by the utility.
• The Peak Shaving and Emergency Demand Response Rider has very similar rules to the Peak Shaving Demand Response Rider discussed above, but with the opportunity to respond to DR events year-round. Another difference is that up to 20 events of six hours or less may be called. Accordingly, remuneration rates for the emergency program are higher. The minimum PSEDR load reduction is 250 kW.

Federal customers can receive payments for providing load curtailments through several programs offered by the Electric Reliability Council of Texas (ERCOT):

• The Emergency Response Service (ERS) program allows qualified loads and generators (including aggregators of loads and generators) to make themselves available for curtailment (on 10- to 30-minute notice) in an electric grid emergency. ERS is designed to decrease the likelihood of the need for involuntary load shedding, such as rolling blackouts. Customers bid to provide load reductions. Note this program is aimed solely at alleviating emergency (as opposed to high price) conditions on the ERCOT grid.
• Voluntary Load Response is when a customer decides independently to reduce consumption from its scheduled or anticipated level in response to price signals or high demand on the ERCOT system. Remuneration levels depend on how the retail contract with a customer’s "load serving entity" (retail electric provider, municipally owned utility, or electric cooperative) is structured. ERCOT encourages customers to check with their load serving entity to find out whether Voluntary Load Response products are available.
• Load Resource Participation in the ERCOT Markets: Customers who are capable of managing their load and can meet certain performance requirements may qualify to become "load resources." Qualified load resources may participate in ERCOT's real-time energy market and/or provide operating reserves to the ERCOT ancillary services markets (non-spinning reserves or frequency regulation), which require very quick responses. Load resources participating in ERCOT’s real-time energy market submit bids to buy power up to a specified price level and are instructed by ERCOT to reduce load if wholesale market prices equal or exceed that level. Load resources that are scheduled or selected in ERCOT’s day-ahead ancillary services markets are eligible to receive a capacity payment regardless of whether they are actually curtailed. A load resource needs to register with ERCOT and must be represented by a "qualified scheduling entity" that is responsible for market operations and financial settlement.

For all three programs, the customer participates through its retail electricity provider (REP), and transactions with ERCOT are conducted by the qualified scheduling entity (QSE) for the customer’s REP. The specific terms for customer participation, including compensation, are based on the contractual arrangement between the customer and their REP.

AEP provides the Texas Load Management Standard Offer Program to distribution customers who are prepared to curtail electric load with at least 30 minutes' notice. The program performance period is for one year, during which time customers receive one scheduled load interruption as well as up to four, eight or twelve unscheduled interruptions (depending on their agreement with AEP). The duration of unscheduled interruptions is based on the option chosen by the customer. For the summer peak period, customers eligible for this program must have a minimum load of 500 kW and be able to reduce by at least 5 kW (in Texas Central territory) or 50 kW (in SWEPCO territory). Interruptions during this period take place on weekdays from 1 to 7 P.M. starting on June 1st and ending September 30th. Incentives depend on the unscheduled interruptions option chosen and are based on verified demand savings that occur as a result of interruptions. During the winter period, customers must be able to reduce electric demand by at least 100 kW. Events may be called at any time of day or week during the program operating period from December 1st  through February 28th. AEP offers the program in its Texas Central (TCC) territory for the summer peak and winter periods, and SWEPCO territories for just the summer peak period. For more information on SWEPCO demand response programs, contact Energy Efficiency & Consumer Program Coordinator Mike Nix. 

CenterPoint Energy's Commercial Load Management Program provides up to $31.50/kW to participants for curtailing load during up to four unscheduled peak events lasting a maximum of four hours each. The available curtailment periods are summer weekdays (June 1–September 30) between 1–7 p.m. There are also up to two scheduled curtailments lasting no more than three hours each. Participants must agree to curtail at least 100 kW per site. Aggregators (e.g., ESCOs or curtailment service providers) can also participate in the program.

The Entergy Texas Load Management Program offers $32.50/kW for participation in one scheduled curtailment event, which lasts one hour, and up to four unscheduled events that last a maximum of four hours. Curtailments occur during the summer from June through September, from 1–7 p.m on weekdays. Customers must be able to curtail at least 250 kW to be eligible. Enrollment in this program is limited and typically ends the last day of April. Entergy also offers a series of time-of-use rates for different sized commercial customers.

El Paso Electric offers its Texas Load Management Program to customers who can curtail at least 100 kW per participating site during the summer (June 1 through September 30) with one-hour notice. Customers receive a maximum of $48/kW for the average kW reduction for all curtailments (see program manual for additional payment details). Up to nine peak events per year, lasting up to four continuous hours each, may be called on summer weekdays from 1–7 p.m. (MDT). Participants are required to demonstrate load reduction capability by participating in one scheduled curtailment at the beginning of the program period. 

El Paso Electric also offers its Electric Vehicle Rate to customers with 120V or up to 480V chargers. The chargers must use a separate meter. The rate is split into summer (June–September) and non-winter (October–May) rates, where the summer period has both on- and off- peak pricing. There is also a year-round rate for super-off peak periods, which occur from 12 to 8 a.m. (MT).

Texas-New Mexico Power Company's (TNMP) Load Management Standard Offer Program offers incentives of up to $40 per kW for curtailing at least 40 kW for a maximum of 18 hours total. For a given period (summer or winter), customers commit to a maximum of four unscheduled curtailments, each no more than a four-hour duration. Summer period curtailments can occur from June 1 to September 30, between 1–7 p.m. on weekdays, while winter period curtailments can occur any time of day from December 1 to February 28. Customers receive notification at least 30 minutes prior to curtailment events. Payment is based on amount of load curtailed; customers are not required to curtail a specific amount and there are no penalties for non-delivery of load reduction. Applications are evaluated on a first-come, first-served basis. Participants must be able to demonstrate load reduction capability by participating in a scheduled curtailment event of one to two hours.

Oncor's Commercial Load Management Program provides remuneration directly to service contractors (e.g., ESCOs, aggregators, energy efficiency service providers, retail electric providers, and utility customers themselves) to reduce energy use in facilities during peak demand periods from June 1 through September 30, between 1–7 p.m. Eligible facilities must be able to curtail at least 100 kW with 30 minutes' notice. More information on the Commercial Load Management Program can be found in the program manual.

Xcel (Southwestern Public Service Company) offers several load management programs:

• The Load Management Pilot Standard Offer Program is available to commercial customers who can curtail at least 100 kW during peak demand periods in return for payments of $35 or $50 per kW (based on customer commitments). Participating customers will receive one-hour advanced notice prior to events. The program runs from June 1 through September 30, with all events on weekdays between 12–8 p.m. The maximum event duration is four hours.
• The Saver's Switch Program provides savings on cooling costs by letting Xcel install a remote-controlled switch on air-conditioning units that cycle them on and off for brief 15- to 20-minute intervals for an average of four hours during times of peak demand. These load control events typically occur between late mornings and evenings on the hottest five to fifteen summer days. In addition to bill savings, customers receive a discount of $20 per ton of enrolled air conditioning on their October bills.
• Xcel offers a time of use rate for commercial customers in Texas. This rate provides utility bill savings for customers who can shift electricity use to off-peak hours, particularly during the summer. On-peak hours are defined as 1–7 p.m., Monday–Friday, from June through September.

Austin Energy customers can enroll in the following load management programs:

• Austin Energy's Commercial Demand Response program offers customers incentives for curtailing unnecessary load during peak demand periods, which fall between 4–7 p.m. from October through May or 1–7 p.m. from June through September. Curtailment events last up to two hours and average about 15 events per year, with an annual maximum of 20 events. Customers have the option to enroll in either the Standard Demand Response program or the Fast Demand Response program. Standard DR provides an incentive of $45–$60 per kW curtailed and a 30-minute notice before each curtailment event. Customers in the Fast DR option receive a $55–$70 per kW incentive and 10 minutes notice before each curtailment event. Participants have free access to a web-based Energy Profiler Online, which can generate customer-specific reports on daily energy usage, peak demand, and power and load factor.
• Austin Energy customers can also enroll in the Power Partner Program when they allow the utility to make brief temperature adjustments of 2 to 4 degrees on their thermostats during times of peak demand. Customers must have an eligible Wi-Fi-enabled thermostat to participate and will receive an $85 incentive for participating. Power Partner events occur no more than 25 times per year, on weekdays between 3 to 6 p.m. from June through September. 
• Customers can also enroll in the Load Shifting Voltage Discount Rider if they are able to shift 30% of their average monthly on-peak billed demand using storage technologies (e.g., thermal or battery energy storage). The billed kW used to determine a customer's charges is based on the highest 15-minute metered demand recorded during the on-peak period, which is every day from 3 to 6 p.m. (note that the company's billed energy (kWh) charge is based on all energy consumption during a separate on-peak period, which occurs every day from 7 a.m. to 10 p.m.).

CPS offers its Demand Response program to customers with a curtailable load of at least 50 kW per single site. Incentives are based on verified performance during peak events, which occur 1–7 p.m. on weekdays from June 1 to September 30 (though they typically occur between 3–6 p.m.). Events typically last three hours and occur approximately 25 times per year. Customers will receive either a two-hour or 30-minute notice (based on customer choice) before each curtailment event. Customers may choose to receive incentive payments via check or as a credit posted to their account.

Utilities in the eastern Texas footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's various demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.

We Energies (WE) offers a host of time-of-use and real-time pricing rates that allow customers to save on energy costs by shifting load to off-peak hours, typically during periods of compromised grid reliability or price spikes in the wholesale electricity market. Customers on the time-of-use rates pay about half for energy charges for off-peak hours, which vary based on the rate the customer chooses.

Xcel Energy offers several options for customers with load flexibility, including:

• The Electric Rate Savings program provides reduced demand charges for peak demand reduction at commercial and industrial facilities that can cut load by 50 kW or more during peak periods, primarily in the summer from June through September (though customers can be called on to reduce anytime during the year). Peak periods occur from 9 a.m.–9 p.m. Participating customers receive a per-kW discount on controllable demand every month, but in exchange must commit to reducing their load to a pre-determined level, usually for four to eight hours. There is a penalty for non-compliance.
• The Saver's Switch for Business offers program participants a year-round bill discount of $3 per kW of enrolled air conditioning in exchange for allowing the utility to cycle their air conditioners on and off for 15–20 minute intervals during periods of peak electric demand in the summer. These events last an average of four hours and typically occur on the five to 15 hottest summer days.
• The company's interruptible gas rate offers monthly bill credits for customers who can reduce gas usage with one hour's notice.
• Time-of-day rates are available to commercial and industrial customers that allow them to save on energy costs by shifting load to off-peak periods. Rates in the summer (June through September) are higher than in the winter (October through May).

Wisconsin Public Service Corp. (WPSC) offers several demand response programs:

• CG-20 Response Rewards is a "critical peak pricing" (CPP) option in which participating customers already on the company's time-of-use rate (CG-20) receive notifications (at least one hour in advance) of CPP events and then can reduce their loads during the following 2–8 hour "critical peak" period, when prices are six times higher than the standard TOU rate peak prices (and 10 times the off-peak rate). In exchange, participants receive 30% lower on-peak and 10% lower off-peak prices at all other times of the year. CPP events will not exceed 300 hours per year.
• WPSC also offers an interruptible rider (CP-12). Participants contract for a 200 kW or greater load reduction (with curtailability up to 600 hours/year) subject to WPSC's determination of either economic or emergency conditions on the grid. In exchange, the customer receives reduced rates for its monthly peak demand. WSPC provides an additional credit of 40¢/kW per interruption for voluntary curtailments that exceed the program maximum of 600 hours. Customers receive notification of a curtailment event at least one hour before an event.
• Time-of-use rates are available to commercial and industrial customers that allow them to save on energy costs by shifting load to off-peak periods, Monday to Friday. Rates during on-peak periods are roughly triple those of off-peak periods. Customers can choose from three on- and off-peak schedules that vary based on the time of year, with the summer period from May through September and winter from October through April. Customers can also enroll in a real-time market pricing rate that charges them varying hourly prices, which are quoted one day or less in advance.

Alliant Energy's Interruptible Program offers customers discounts for their willingness to reduce their power consumption to a firm level (by at least 200 kW) either immediately or with one hour's notice, depending on the option the customer chooses. Commercial and industrial customers can also take advantage of Alliant's Time of Day Pricing if they can divert load away from peak hours (weekdays 11 a.m.–7 p.m., June through August, and 5–9 p.m., December through February) and toward off-peak times (11 p.m.–6 a.m. on weekdays, as well as all hours on weekends and holidays). This time-of-use pricing is optional for small commercial (< 75 kW peak) customers, but mandatory for larger accounts.

Madison Gas & Electric (MGE) customers with peak loads over 20 kW are defaulted onto the company's time-of-use rates, for which weekday consumption during peak periods incurs higher prices, especially in the summer, and 9 p.m.–10 a.m. usage (as well as all consumption during weekends and holidays) is cheapest. There are three peak periods (10 a.m.–1 p.m., 1–6 p.m., and 6–9 p.m.), of which the second has the highest rate increase compared to off-peak periods. MGE also offers customers with at least 75 kW of curtailable demand an interruptible rate; there is a more generous interruptible option for customers that can curtail 500 kW or more. MGE can call no more than 150 hours of interruptions, but there are penalties for customers that fail to comply.

Utilities in the footprint of MISO (the Midcontinent Independent System Operator) may enroll interested customers in any of MISO's various demand response offerings, from which they can receive payments for reducing load. Customers should contact their local utility representative to inquire about participation.