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RTS Management in SMETS2

50 - RTS Management in SMETS2

  • Proposer
  • Proposing Company SSE ENERGY SUPPLY LIMITED
  • Status Closed
  • Urgent No
  • Synopsis

    Following on from DCP204 (Demand Control for Smart Metering) it was agreed with Ofgem that the matter of RTS and its overall management in the Smart world would be looked at after the implementation of DCP204. This was in agreement with the recommendation made out of the SIG meeting (27 March 2015) – point 3.8. (In reference to DIF045). Concerns were raised and this is documented in Change Report_7, item 7.24 (page 34).

    As such, there is still a need to work through how RTS (especially Dynamic) management will work. It has already been agreed, in the previous works under DCP204 and DIF045, that this falls under DCUSA but there is need for this work, now DCP204 has completed, to be picked up and looked at.

    The issue itself is:

    “A specific concern raised by a working group member and by a consultation respondent is regarding a change to which party will be responsible for defining appropriate tariff switching times in any given geographical area (load switching of heating and hot water usually corresponds to cheaper rate/off-peak/night rate tariff times). Currently the distributor defines the switching times, through the application of Standard Settlement Configuration (SSC) rules under the BSC, in their GSP. The Working Group noted that the removal of SSCs will not be for several years and is therefore not an immediate issue, however, there may be future unintended consequence of moving away from SSCs.

    In conventional metering the time switch settings on metering systems are implemented on site by the MOP (as the Supplier’s agent) via the equipment fitted to reflect the tariff (the settings being based on the SSC/TPRs provided by the Supplier). Time switching settings on smart metering systems can be applied remotely or locally (via hand-held terminal equipment). Only energy suppliers have access to the relevant commands to set the time switching settings on a smart meter. Distributors will have no ability to control, or be involved, with the tariff arrangements applied to any meters on their network. This will lead to a removal of the diversification of switching times in their areas that they were previously able to manage through Group Codes that were randomly associated with the RTS infrastructure. E.g. there are 5 published SSCs operating in the Scottish Mainland LMA with a different group code association to each. This means approximately a 5th of the portfolio, on these arrangements, switch concurrently thus providing a smoothing of the load in that region to protect the network from peak demand. We want to establish a method of recreating this capability within the Smart Programme.”

    This issue has been raised to consider the matter of Radio Teleswitching Systems (RTS) and its overall management in the Smart world.

    The DCUSA SIG discussed this issue on the 27 May 2016 and made a recommendation to the DCUSA Panel on 15 June 2016 for a DCUSA SIG Subgroup to be set up to consider this matter in more detail.

    The DCUSA SIG agreed that this issue should consider the changes required to Schedule 8 ‘Demand Control’ for Load Managed Areas (LMAs) with specific requirements such as the islands in North Scotland which are monitored and have specific weather correction and heat load switch correction and the rest of the energy industry where the primary function of RTS is switching.