{"id":5175,"date":"2026-10-10T00:00:00","date_gmt":"2026-10-09T16:00:00","guid":{"rendered":"https:\/\/xinya-ee.com\/?p=5175"},"modified":"2026-10-07T14:11:32","modified_gmt":"2026-10-07T06:11:32","slug":"%d1%82%d1%80%d0%b5%d0%b1%d0%be%d0%b2%d0%b0%d0%bd%d0%b8%d0%b5-%d0%ba-%d0%ba%d0%be%d0%bc%d0%bc%d0%b5%d1%80%d1%87%d0%b5%d1%81%d0%ba%d0%b8%d0%bc-%d1%81%d0%b8%d1%81%d1%82%d0%b5%d0%bc%d0%b0%d0%bc-%d0%b7","status":"publish","type":"post","link":"https:\/\/xinya-ee.com\/ru\/blog\/openadr-commercial-ev-charging-demand-response\/","title":{"rendered":"\u041a\u0430\u043a \u043a\u043e\u043c\u043c\u0435\u0440\u0447\u0435\u0441\u043a\u0430\u044f \u0437\u0430\u0440\u044f\u0434\u043d\u0430\u044f \u0441\u0442\u0430\u043d\u0446\u0438\u044f \u0434\u043b\u044f \u044d\u043b\u0435\u043a\u0442\u0440\u043e\u043c\u043e\u0431\u0438\u043b\u0435\u0439 \u043c\u043e\u0436\u0435\u0442 \u0438\u0441\u043f\u043e\u043b\u044c\u0437\u043e\u0432\u0430\u0442\u044c OpenADR \u0434\u043b\u044f \u0443\u043f\u0440\u0430\u0432\u043b\u0435\u043d\u0438\u044f \u0441\u043f\u0440\u043e\u0441\u043e\u043c?"},"content":{"rendered":"
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A utility requests a reduction in charging load, but the vehicles connected to the site still need enough energy for their next journey. Can the station reduce power without interrupting every session or missing a fleet departure? The answer depends on how the utility signal reaches the charging controller and how that controller allocates the remaining capacity. A charger that accepts remote commands is not, by itself, a complete demand-response system. The operator also needs event handling, charging priorities, measurable delivery, and a recovery policy. This distinction matters because an accepted event can become an operational problem if the promised reduction exceeds the energy flexibility actually available.<\/p>\n

The short answer is yes: commercial EV charging<\/strong> can participate through an OpenADR-compatible endpoint connected to a charging-management or energy-management system. OpenADR 2.0b exchanges demand-response events and reporting information; the local control system translates those events into charging limits. It must preserve electrical limits, respect vehicle and departure constraints, and verify the response against the program’s rules. Before enrolling, confirm the required OpenADR profile, the available charger-control interface, the measurement boundary, and whether the site can decline an event when essential charging leaves insufficient flexibility.<\/p>\n

How does an OpenADR event become a charger power limit?<\/h2>\n
\"XYDF<\/figure>\n

OpenADR defines communication between a Virtual Top Node, or VTN, and a Virtual End Node, or VEN. A utility, aggregator, or program platform can operate the VTN; the VEN represents the participating resource or site. The VEN may run in a gateway, energy-management platform, or charging backend rather than inside every charger. The OpenADR Alliance’s OpenADR 2.0<\/cite> specifications describe this exchange, including the more extensive 2.0b profile.<\/p>\n

An event can include identifiers, timing, target information, and signal values. Depending on the program, those values may represent a requested load reduction, a price signal, or another supported instruction. They do not always mean a direct command to set every connector to the same power. The site’s integration must map the program’s signal semantics to an approved operating policy.<\/p>\n

A workable control sequence has five steps:<\/p>\n

    \n
  1. Authenticate and receive the event, then validate its timing, target, and supported signal type.<\/li>\n
  2. Check whether the event is new, modified, cancelled, or already processed.<\/li>\n
  3. Evaluate participation against available charging flexibility and program obligations.<\/li>\n
  4. Translate the accepted event into a site budget and feasible connector-level charging limits.<\/li>\n
  5. Monitor delivery, report as required, and restore charging without creating an avoidable rebound peak.<\/li>\n<\/ol>\n

    The fourth step is where OpenADR EV charging<\/strong> becomes actual load control. A charging station management system, or CSMS, may deliver charging profiles through supported OCPP functionality. An energy-management system may coordinate chargers with other building loads. Either route needs tested limit enforcement, not merely a successful event receipt.<\/p>\n

    For the integration drawing, identify which EMS, controller, or CSMS hosts the VEN and which component has final authority to enforce the charging cap; the protocol does not mandate one topology. The OpenADR Alliance FAQ<\/a> describes the VEN as a client that can be an energy-management system, while the Open Charge Alliance OCPP overview<\/a> places OCPP between charging stations and their management system. These are distinct communication layers, not evidence that each charger must be a VEN.<\/p>\n

    Keep three quantities separate: the utility’s requested response, the controller’s issued setpoints, and the site’s measured power. A vehicle may draw less than its permitted limit, and a charger may reject or constrain a command. Only measurement shows the electrical result.<\/p>\n

    How can charging schedules protect fleet departures?<\/h2>\n

    Fleet charging should treat departure readiness as a constraint, not a priority label with no energy calculation behind it. For each vehicle, the scheduler needs a departure deadline, the energy still required, the permitted charging power, and the time during which charging is available. State-of-charge data may improve the calculation, but its availability depends on the vehicle, charging interface, and backend integration.<\/p>\n

    A basic feasibility check compares remaining energy with the energy that can be delivered before departure. For an illustrative calculation, a vehicle needing 24 kWh with four hours available needs an average of 6 kW at the defined measurement boundary. Pauses, charging losses, tapering, and interruptions can raise the necessary allocation. This arithmetic is a scheduling check, not a charger rating or a guarantee of vehicle readiness.<\/p>\n

    The controller should reserve capacity for vehicles with little remaining flexibility, then distribute the balance among sessions that can wait. If the requested reduction makes the energy plan infeasible, the system needs a defined response: use an allowed opt-out, reduce the participation commitment, or escalate for an operational decision. It should not silently promise both the full response and an impossible departure target.<\/p>\n

    Good smart charging<\/strong> also considers the period after an event. Restarting all deferred sessions together can create another peak. A controlled recovery schedule gradually reallocates capacity while checking approaching deadlines. Existing site limits remain applicable during both curtailment and recovery.<\/p>\n

    Automated load shedding compared with manual control<\/h3>\n

    Automation is useful when events arrive frequently or connector-level scheduling is needed. Manual control can remain appropriate for supervised participation or exceptional operating conditions, but it requires clear responsibility and timely action. The comparison below addresses control methods rather than comparing charger brands or claiming universal financial savings.<\/p>\n\n\n\n\n\n\n\n\n\n\n
    Decision factor<\/th>\nManual load shedding<\/th>\nAutomated event-driven control<\/th>\n<\/tr>\n<\/thead>\n
    Event response<\/td>\nAn operator reviews the request and applies approved changes.<\/td>\nThe controller evaluates the event and executes the configured policy.<\/td>\n<\/tr>\n
    Departure protection<\/td>\nDepends on current schedules and the operator’s information.<\/td>\nCan use explicit energy and deadline constraints when reliable inputs are available.<\/td>\n<\/tr>\n
    Charging continuity<\/td>\nMay use broad group reductions or pauses.<\/td>\nCan distribute limits among individual sessions if the equipment supports it.<\/td>\n<\/tr>\n
    Evidence<\/td>\nNeeds records linking operator actions to metered results.<\/td>\nCan retain event, command, and measurement records automatically.<\/td>\n<\/tr>\n
    Implementation cost<\/td>\nLower integration effort can be offset by recurring staff effort.<\/td>\nRequires integration, commissioning, monitoring, and ongoing support.<\/td>\n<\/tr>\n
    Exceptional conditions<\/td>\nOffers direct judgment but depends on staff availability.<\/td>\nNeeds tested overrides, alerts, and fallback rules.<\/td>\n<\/tr>\n<\/tbody>\n<\/table>\n

    What determines whether demand response produces a useful result?<\/h2>\n

    EV demand response<\/strong> is not the same as demand-charge management. A utility event follows a program’s dispatch and settlement rules. Demand charges follow the applicable tariff’s demand measurement and billing rules. Reducing power during an event may support both objectives, but an event outside the site’s billing peak may not reduce its demand charge.<\/p>\n

    The economic assessment should include program revenue, potential tariff savings, integration fees, metering, platform subscriptions, commissioning, operational labor, and any participation penalties. Avoid calculating value from charger nameplate capacity alone: usable flexibility depends on occupancy, energy requirements, connection time, and competing site loads.<\/p>\n

    Operating conditions that change the charging policy<\/h3>\n

    The following planning matrix organizes the decision by application constraints. It does not prescribe identical settings for every site; the actual policy must match the program contract and equipment behavior.<\/p>\n\n\n\n\n\n\n\n\n\n
    Site condition<\/th>\nScheduling implication<\/th>\nWhat to verify<\/th>\n<\/tr>\n<\/thead>\n
    Long-dwell charging<\/td>\nSome energy may move outside an event window.<\/td>\nReal connection duration and user energy needs, not parking duration alone.<\/td>\n<\/tr>\n
    Fixed fleet departures<\/td>\nReserve energy for the least flexible vehicles first.<\/td>\nDeadline data, charging availability, and escalation when schedules become infeasible.<\/td>\n<\/tr>\n
    Short-stay charging<\/td>\nLess time is available to recover deferred energy.<\/td>\nCustomer commitments and whether a reduced-power service is acceptable.<\/td>\n<\/tr>\n
    Shared building supply<\/td>\nCharging capacity changes with non-charging loads.<\/td>\nThe meter boundary and coordination with the building controller.<\/td>\n<\/tr>\n
    Intermittent communications<\/td>\nThe site needs a bounded local operating policy.<\/td>\nEvent expiry, offline limits, reconnection, and alarm delivery.<\/td>\n<\/tr>\n<\/tbody>\n<\/table>\n

    Measurement and verification in practice<\/h3>\n

    Agree on the measurement boundary before implementation: whole-site demand, charging-system demand, and connector energy describe different things. The program determines the accepted meter, reporting intervals, baseline method, exclusions, and settlement rules. The International Performance Measurement and Verification Protocol<\/cite>, maintained by EVO, provides a general measurement-and-verification framework; it does not replace a demand-response program’s own settlement requirements.<\/p>\n

    Record event timing, participation decisions, issued limits, meter timestamps, actual demand, and relevant overrides. Synchronize clocks and units across systems. A command log can explain what the controller attempted, but it cannot establish a delivered reduction by itself. Baseline comparison also needs the program’s prescribed treatment of changes in occupancy and other loads.<\/p>\n

    An event acknowledgement records the endpoint response, not measured load reduction. Align acknowledgement, control, and meter timestamps to the agreed measurement boundary, and record when each lost link begins and ends, when fallback takes effect, and when normal control resumes. Evaluate the resulting meter trace using the utility or aggregator’s baseline and settlement method, rather than treating an accepted event or restored connection as delivery evidence.<\/p>\n

    What do the standards cover, and what happens when a signal is lost?<\/h2>\n

    OpenADR 2.0b concerns automated demand-response communication. The OpenADR Alliance’s certification program concerns specified implementations and profiles; an OpenADR claim does not establish electrical safety, vehicle compatibility, or certification of an entire charging installation. Request the exact certified component, profile, version, and intended integration boundary where certification is required.<\/p>\n

    The OpenADR Alliance FAQ<\/a> states that OpenADR 3 complements rather than replaces OpenADR 2.0. Confirm the utility program’s required version, profile, and endpoint before procurement instead of choosing the newest version by default. Verify the exact product’s certification where required; a certificate does not guarantee fleet readiness or the site’s measured response.<\/p>\n

    OCPP concerns communication between charging stations and management systems. The Open Charge Alliance describes smart-charging functionality in its protocol materials, but actual support depends on the version, implemented features, configuration, and equipment. The presence of an OCPP connection does not prove that a particular charger enforces the profiles needed for EV charging load control. Electrical installation, charger safety, metering acceptance, and vehicle communication have separate requirements that must be checked for the intended installation.<\/p>\n

    Communication loss should trigger a documented policy, not indefinite curtailment or an unrestricted restart. An accepted event already stored locally may continue through its valid end time if the agreed policy allows. A stale signal should not authorize a new event. The controller must also handle cancellation or modification messages when communication returns.<\/p>\n

    Define separately what happens if the VEN loses its upstream connection and if the CSMS loses contact with chargers. Those failures affect different parts of the control path. Configure local electrical limits, bounded schedules, alerts, and a recovery sequence that avoids duplicate event processing. Test these behaviors alongside ordinary commissioning; a valid protocol exchange alone does not establish dependable fallback.<\/p>\n

    What should buyers verify before selecting a charging system?<\/h2>\n

    For a utility demand response EV project, procure the control chain as an integrated scope. Four checks are especially useful:<\/p>\n

      \n
    1. Obtain the program’s required profile, signal definitions, response expectations, participation rules, and reporting requirements.<\/li>\n
    2. Require a demonstrated path from event receipt to enforced charger limits, including session-specific and site-wide constraints where needed.<\/li>\n
    3. Specify acceptance tests for event updates, cancellation, active-session curtailment, communication loss, override, and staged recovery.<\/li>\n
    4. Assign ownership for credentials, software updates, metering, alarms, support, and evidence retention.<\/li>\n<\/ol>\n

      When reviewing XYDF’s charging equipment catalog<\/a>, request model-specific documentation for the proposed backend and load-management integration. The 22 kW commercial EV charger product page<\/a> provides a model-level starting point for that documentation request, not evidence of OpenADR functionality. Do not infer protocol support or certification from a product category description.<\/p>\n

      \"XYDF<\/figure>\n

      Frequently asked questions<\/h2>\n

      What is OpenADR and how does it control EV charging?<\/h3>\n

      OpenADR is a protocol for exchanging automated demand-response information between a program platform and a participating endpoint. For EV charging, a controller interprets the event and applies supported charging limits through the station-management or energy-management interface. OpenADR itself does not directly define every charger’s power-control behavior.<\/p>\n

      Can a commercial EV charging station respond to utility demand signals?<\/h3>\n

      Yes, when the site has a compatible event endpoint, a controllable charging system, and an approved participation policy. Enrollment also depends on the utility or aggregator’s program requirements. Available charging flexibility determines how much response the site can credibly commit.<\/p>\n

      How are charging sessions scheduled during a demand-response event?<\/h3>\n

      The scheduler applies the accepted site limit while allocating energy according to connection time, departure deadlines, and session priorities. Vehicles with little remaining flexibility need protection before flexible sessions are deferred. The plan should be recalculated as vehicles arrive, leave, or change their energy requirements.<\/p>\n

      What happens if an OpenADR signal interrupts an active charge?<\/h3>\n

      The integration may reduce permitted charging power or pause a session according to the approved policy. Vehicle response, minimum charging limits, session recovery, and user notification depend on the equipment and software. Commissioning should test actual active-session behavior instead of assuming every vehicle resumes identically.<\/p>\n

      Can OpenADR reduce demand charges without delaying fleet departures?<\/h3>\n

      It can contribute when flexible charging overlaps the tariff’s relevant demand periods and enough energy can still be delivered before departure. OpenADR does not guarantee either outcome. Validate the energy schedule and billing rules separately, then test their combined operation.<\/p>\n

      What hardware and software are needed for OpenADR-enabled EV charging?<\/h3>\n

      The system needs an OpenADR-compatible VEN, event-management logic, a charger-control interface, suitable metering, and reliable communications. Scheduling inputs and local fallback capability are important where departure commitments apply. These functions may be distributed across a gateway, charging backend, and site controller rather than supplied by one device.<\/p>\n

      References<\/h2>\n
        \n
      • OpenADR Alliance: OpenADR specifications, including version 2.0<\/a>.<\/li>\n
      • OpenADR Alliance: protocol and certification program information<\/a>.<\/li>\n
      • Open Charge Alliance: Open Charge Point Protocol materials<\/a>.<\/li>\n
      • EVO: International Performance Measurement and Verification Protocol<\/a>.<\/li>\n<\/ul>\n

        How should an operator move from signals to dependable charging control?<\/h2>\n

        The essential distinction is between receiving a demand-response event and delivering a measured response without breaking charging commitments. Start with the program’s obligations, calculate the site’s genuine energy flexibility, and then select the hardware and software capable of enforcing the resulting policy. Validate departure readiness, reporting, and offline behavior together before relying on the system in operation. Neither protocol support nor a successful command is a substitute for measured performance. XYDF equipment selection belongs within that wider integration decision: confirm the proposed model, control interface, and documentation against the site’s requirements. Contact XYDF<\/a> with the program profile, charging schedule, supply limits, and backend requirements to discuss the equipment scope.<\/p>\n<\/article>\n