WS1B - Whole Electricity System Planning & T-D Data Exchange
If you would like to learn more about the products planned for 2019, please refer to the Phase 4 Project Initiation Document (PID) 2020. Alternatively, should you wish to be notified when new products are launched, subscribe to the Open Networks mailing list.
Product 5: Whole System FES - Signposting of Potential Network Capacity Requirements
This Workstream 1B Product 5 report summarises the results of a fact-finding survey on how the capacity of GB electrical networks is currently evaluated and shared with stakeholders to articulate network needs. The reasoning behind current DNO methodologies for evaluating and reporting network capacity is explained to provide a deeper understanding to subsequently inform good practice to drive consistency and a possible standardised approach.
If you would like to learn more about the products planned for 2020, please refer to the Phase 3 Project Initiation Document (PID) 2019. Alternatively, should you wish to be notified when new products are launched, subscribe to the Open Networks mailing list by clicking here.
Product 1 – Investment Planning
Progress on two of the four sub-deliverables for Product 1 is summarised below.
This covered the further development of funding options for regional Networks Options Assessment (NOA). The product team has looked to develop the options presented in the Open Networks WS1 P1 2018 report. After engaging with the ENA’s Electricity Regulation Managers Group (ERG), it was agreed that the ERG will take this work forward with Ofgem as part of its RIIO-2 stakeholder engagement. The product team will provide ongoing support but it is not anticipated that further development will be needed within Open Networks.
This looked to incorporate the regional voltage methodology developed in 2018 into the NOA 2019/20 methodology. A High Voltage Case Study for the Pennine region was published as part of the Open Networks WS1 P1 2018 report in December 2018. The Case Study explored how to deliver a regional NOA-style assessment of distribution schemes that might provide economic and efficient solutions for high voltage issues on the transmission system. In line with sub-deliverable d), the ESO has further developed a High Voltage Management Process which also enables commercial providers to propose solutions. The methodology for the High Voltage Management Process takes lessons-learnt from the Pennine Case Study as well as feedback the ESO received as part of the Request for Information (RFI) for the Mersey region. The methodology outlines how the ESO will work with stakeholders to identify high voltage issues in the transmission system, the causes, requirements and preferred options to solve these issues. This methodology is now included as Section 6 of the Network Options Assessment (NOA) Methodology 2019/20. The ESO consulted on this methodology alongside the main NOA Methodology in May 2019; the feedback received can be found in Appendix G of the NOA Methodology.
Work is continuing on the two other Product 1 sub-deliverables, a) and c). Sub-deliverable a) is developing the Regional NOA process including the costing and cost-benefit assessment processes for different types of solution. Sub-deliverable c) is identifying and proposing the network code changes that are needed to support the work.
Product 2 – Whole Electricity System FES
Whole Systems FES End of Year Report
The Workstream 1B objective is to take a whole electricity system approach to optimise existing processes across the Transmission and Distribution boundary by identifying synergies and developing more efficient processes for key network operator activities such as investment planning, operational planning and forecasting.
The report details the work carried out to progress each of the sub-deliverables 1 to 4, describing new processes, templates and agreed approaches that will support data exchange and ongoing FES delivery by each of the network companies.
The full End of Year report can be accessed here.
As part of sub-deliverable a) for this product, this document shows when network companies are proposing to publish scenarios through 2019.
The Whole Electricity System Future Energy Scenarios (FES) product of Workstream 1B has made good progress in relation to its deliverables in the first half of 2019. The product team identified and implemented a number of tactical improvements to improve DNO / ESO / TO liaison to feed into FES 2019. In April 2019, each network company reviewed the FES 2019 starting year data which was the first step in providing DNOs with the opportunity to provide feedback to the ESO’s FES team. DNOs also provided GSP (Grid Supply Point) and postcode data to allow better mapping of generation and demand to GSPs. This will improve the regional outputs within FES 2019 and create a more accurate view of generation and demand at GSPs. The GB FES for 2019 has now been published by National Grid ESO and can be viewed here.
The product team are currently developing information exchange processes to support 2020 delivery of Whole Electricity System FES. To facilitate the 2020 FES cycle, non-disclosure agreements (NDAs) will be put in place between NGESO and the DNOs. Whilst this provides a pragmatic approach to ensure the 2020 FES cycle can be supported, in the second half of 2019 the product team will begin exploring the need for grid code change to facilitate the data exchange and ongoing FES delivery for the longer term. Towards the end of the year we will be hosting a webinar where we will be seeking stakeholder feedback on our proposals. This will be signposted on our Events page.
Product 3 - Real Time Data Exchange & Priority of Actions
To enable the effective utilisation of distribution connected resources for balancing and network operation in operational timescales, NGESO and DSOs will need an ongoing exchange of information to share service requirements and to identify any ongoing network limitations. Product 3 is taking the outputs of ongoing trials to better define the information transfers that will be needed to enhance transmission/distribution system coordination and control. It is evaluating how these information transfers would change for the future worlds that are being assessed under Workstream 3.
Much of this work on information and data transfer is being informed by Regional Development Programmes that have been running between network companies to trial different approaches for managing distribution connected resources. The NGESO-WPD Regional Development Programme is exploring the deployment of distribution level services in a relatively straightforward network environment where there are relatively few service providers and few network constraints. The NGESO-UKPN Regional Development Programme is exploring the deployment of distribution level services in a more complex network environment where there are multiple service providers and multiple network constraints.
Through the first half of 2019, the responsibilities and requirements for information transfer to support the effective deployment of services under DSO Worlds A, B and D have been assessed. For each World, accountabilities have been identified, data requirements have been defined as have the preferred methods of operational data transfer. In addition, UK Power Networks have established a fully functional ICCP link with National Grid ESO exchanging over 100 real-time data points. The State Estimation running on UK Power Networks DMS platform is converging at Ninfield GSP and the distribution network below the GSP. Further data exchange is needed to ensure the accuracy of the DSO State Estimation is satisfactory for system operation. All the DNOs in the UK are in the process of establishing ICCP links with National Grid ESO.
The final report from the Product team detailing outputs from Product 3 in 2019 are included in the report, available here.
Product 4 - Data Exchange in Planning Timescales
2020 - Proposals for Implementation of Electronic Exchange of Network Planning Data
This report details the delivery of Sub Deliverables b(i) review the mechanisms currently used to share planning data between network companies, b(ii) identify what analysis software is used by network companies and how network models are transferred between companies, and b(iii) consider and recommend improvements to the mechanisms used to share data between network companies and from customers to network companies.
The report focuses on mechanisms for the exchange of planning data. The mechanisms for exchanging and providing data in an open manner is a much larger issue and network companies are developing their strategies and planning data exchange is forming just one element of these strategies.
The full report can be viewed here.
To facilitate the development of an efficient and coordinated electricity system, against the backdrop of a decarbonised SMART future, data exchange between network companies will be critical. The report ‘Data Exchange in Planning Timescales; Data Scope – Final Report’ details proposals for an enhanced level of data exchange between network companies that will be progressed through to Grid and Distribution Code modifications.
The Data Exchange in Planning Timescales; Data Scope - Final Report can be accessed here.
The scope and frequency of data exchange between transmission and distribution network companies is defined in the Grid Code. The Grid Code requirements have served the industry well for many years, however latterly the move away from large carbon intensive generation towards small renewable generation has changed the way these networks operate and interact. This Product aims to review the data exchange requirements in the light of these changes and propose new data exchange requirements that will facilitate coordinated and efficient planning of the networks in the future.
The Product team is delivering a proposal to enhance the scope and frequency of data exchange from distribution to transmission companies and vice versa. It is also reviewing the mechanisms of data transfer to propose new mechanisms that ensure efficient, accurate and accurate transfer of both network and demand data. Finally, the Product team will propose industry code modifications that will bring about the proposed changes.
The team has delivered an interim report that covers the early sub-deliverables that includes early proposals for the scope of distribution to transmission data transfer and initial proposals on data transfer mechanisms.
The early proposals to transfer distribution to transmission company data have subsequently been refined to a final proposal. An enhancement proposal for the transfer of data from transmission to distribution companies has been completed. A first draft of a Final Report, together with associated new data templates, will be published in September 2020.
A review of the current capability, within network companies, to transfer network and demand data electronically has been completed. The Product team is now considering what steps are required to deliver an electronic data transfer mechanism, possibly along the lines of a Common Information Model.
Initial work has begun to understand the extent of industry code changes. The code change requirements of Workstream 1B Products 1, 2, and 4 will be considered together to propose a coherent set of code modifications that address the data transfer needs in the planning timeframe.