While this measure has been welcomed by the main players in the market, there are drawbacks. For example, as the aim is to encourage future/future investments, it does not support existing operational generation facilities, which are required to continue to operate their electricity production exclusively on the centralised market without the use of PDOs in the long term. From this point of view, GEO 74/2020 introduces separation – or even discrimination – between production facilities that were commissioned before and after 1 June 2020. Given that the arguments put forward in favour of geo 74/2020 distribution included the need to act quickly in the context of the COVID-19 outbreak and to address the resulting short-term economic contraction, it is questionable whether GEO 74/2020 will be able to achieve this target as long as all energy producers in service from 1 June 2020, are excluded from its use. In exceptional circumstances, contracts agreed by market participants may be of a different type than EFET for a temporary period of 6 months from the conclusion of the first transaction on that market, but such contracts must be published on the OPCOM website. 2.5.4 The current OPCOM platform allows producers and suppliers to conclude two types of agreements: concluded EPAs and open EPAs. 2.5.15 The contract regulates all aspects of the sale/purchase of electricity, with the exception of the delivery profile, price and delivery time. 2.1.6 In accordance with the ANRE (see below for ANRE in paragraph 3.1.2), electricity generation based on the type of resources within the national energy system was distributed in 2013 as follows: hydropower at 28.3%; nuclear 20.6%; Wind 7.1%; solid 29%; liquid 0.2% and gas 14.7% 4 ANRE, report on the results of the electricity market monitoring of December 2013, December 2013 (called 9 December 2014). . . .