Options for the Design of European Electricity Markets in 2030

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Closes 14 May 2021

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8. How could European Day-Ahead and Intraday markets be improved to further facilitate market access of RES and Distributed Energy Resources in 2030?
9. Are there any best practices which could be used as an example for RES and DER participation in DA and ID markets?
10. What do you consider to be the main barriers for the participation of RES into balancing markets?
11. Which kind of support scheme has the least distortive effect on the participation of RES in balancing markets?
12. What do you consider as best practice to the ensure effective provision of voltage control and other non-frequency Ancillary Services by RES?
13. How could market design mitigate the side effects of the interaction of negative prices and RES supported technologies?
14. What do you consider to be the key market design barriers limiting the uptake of demand response?
15. What do you consider to be the best practices for the facilitation of demand response?
16. Do you see benefits in increasing the number of intraday auctions?
17. If so, what would be an adequate number of intraday auctions per day?
18. Would you still see a role for cross-zonal intraday continuous trading in case an adequate number of intraday auctions would be implemented?
19. What potential benefits or drawbacks do you foresee in combining day-ahead and intraday auctions?
20. Would you recommend any alternative solution to combining day-ahead and intraday auctions which could achieve similar objectives?
21. How could markets for forward transmission capacity be improved to support the energy transition?
22. Do you see value in developing new durations of long-term transmission capacity products mirroring products for forward electricity trading?
23. Do you see other means to improve the forward markets and hedging possibilities besides long-term transmission rights?
24. Which potential benefits or drawbacks do you foresee with the co-optimisation of energy and balancing capacity?
25. Would you recommend any other solution which could achieve similar objectives?
26. Do you think that the implementation of co-optimisation or other market features could increase market complexity to a level which may be detrimental for the entrance of new players?
27. How can TSO procurement of balancing services evolve to be a better fit for the new power system of 2030?
28. Do you have concrete examples of best practices in theprocurement of balancing services?
29. For system with limited congestions and reactive balancing approaches, would you foresee any benefits to implementing real-time markets managed by the relevant TSO?
30. Are there any other Balancing Markets enhancement which you would recommend?
31. Would you support the simplification of products traded in the DA and ID auctions to speed up the implementation of ongoing and future market evolutions?
32. If yes, which DA and ID market evolution would you consider to be a priority and which specific products could be discarded?
33. Which potential benefits or drawbacks do you see with the alternative pricing methodologies described in section 2.4.2?
34. Would you recommend any other solution to improve the performance of DA and ID coupling algorithms?
35. Which potential benefits or drawbacks do you foresee by allowing more time for the algorithm optimisation?
36. Would you be in favour of keeping an hourly auction in day-ahead followed by 15 min intraday auctions?
37. Would you recommend any other solution to adapt market coupling procedures?
38. Do you think the zonal market model including the planned evolutions of the Clean Energy Package is suitable for the 2030 power system?
39. What is the most important feature of the current zonal market design that must be adapted to make it future proof?
40. Which potential benefits or drawbacks do you foresee with introduction of the PST and cross-border/internal HVDC in the allocation phase of transmission capacities alongside the market coupling?
41. Which potential benefits or drawbacks do you foresee with the introduction of several Flow-Based domains in the allocation phase of transmission capacities?
42. Do you see the Dispatch hubs model as a promising option to be further analysed in the future? If so, which variant: Redispatch potential bids or market bids appears the most promising?
43. Do you foresee any challenge in the implementation/operation of the dispatch hubs model?
44. Do you consider more locational information in the balancing timeframe to be a solution worth requiring further analysis?
45. Would you recommend any alternative solution to solve intra-zonal congestion in the balancing timeframe?
46. Do you think experience with nodal models can be useful in Europe, and how?
47. What other advantages or disadvantages do you foresee with nodal models in a European context than those mentioned here?
48. How could the increasing participation of distributed energy resources to the balancing market be handled in nodal pricing models?
49. Under which conditions do you think a nodal market could be a relevant solution for some countries?
50. Do you foresee other challenges or solutions than those mentioned in section 3.6 with respect to the interaction between zonal and nodal solutions?
51. How can distortions and inc/dec gaming in market-based redispatch be addressed/mitigated?
52. What type of alternatives (e.g. capacity-based payments) exist to efficiently make use of distributed flexibility sources?
53. What recommendations do you have for the development of local flexibility markets based on existing initiatives?
54. Should EU legislation attempt to define some fundamental common principles (e.g. degree of integration with existing wholesale markets, products standardisation, etc.)?
55. Do you agree that all three models described above (enhanced energy only markets, strategic reserves, capacity mechanisms) could be suitable for European countries in 2030
56. Is there any additional market model which would be suitable for European countries in 2030 to ensure resource adequacy?
57. Do you see capacity mechanisms with flexibility requirements as a promising option for further analysis?
58. What are in your view the main potential advantages and drawbacks of capacity mechanisms with flexibility requirements?
59. Do you consider the capacity subscriptions model as a promising option for further analysis?
60. In your view, what are the main potential advantages and drawbacks of the capacity subscriptions model?
61. Which potential benefits or drawbacks do you foresee with the implementation of scarcity pricing in your market?
62. Do you have any specific suggestions on how scarcity pricing could be implemented?
63. What type of RES supports is more fit for purpose for the 2030 power system?
64. What other market design elements can facilitate investments in RES to achieve EU climate objectives?
65. What are the best practices for the design of RES tenders?
66. How should capacity mechanisms consider the participation of RES?
67. Do you see potential for the development of new frequency ancillary services?
68. Which non-frequency ancillary services are more suited for market-based procurement?
69. Do you have suggestions on how to best ensure that market participants provide the necessary system inertia to the system?
70. Would you recommend any other solution for ancillary services in 2030?
71. Is there any other key market design area not addressed in this paper which deserves particular attention to enable the achievement of European energy and climate goals for 2030?

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