Energy regulator Nersa is inviting the South African public and other stakeholders to voice their views on the new load shedding stages for the country in November.<\/p>\n\n\n\n
The public hearings are the next step in processing the document that will ultimately go on to be the new governing rules for load shedding in the country.<\/p>\n\n\n\n
Nersa published the consultation document on the restructuring of load shedding on 11 August, and the window for written comments closed on 22 September.<\/p>\n\n\n\n
Public hearings will now be held on digital platforms on 2 November 2023, with access given only to those who register their interest to attend.<\/p>\n\n\n\n
Anyone who wants to comment or present their views on the new load shedding schedules will have to register their interest before 16h30 on 27 October<\/p>\n\n\n\n
This can be done through Mr Walter Mabunda at the following contact details:<\/p>\n\n\n\n
Once finalised, the new rules will ultimately be known as the\u00a0NRS 048-9 Code of Practice Edition 3<\/strong>.<\/p>\n\n\n\n The NRS 048-9 Code of Practice is primarily an electricity utility-driven and executed document that derives its mandate and authority, once approved by the National Energy Regulator of South Africa (Nersa), as part of the Electricity Regulations Act.<\/p>\n\n\n\n When the first edition of the NRS048-9 code was established in 2010, load shedding stages were capped at Stage 4 \u2013 representing 25% of the base load \u2013 requiring utilities to \u201cfind\u201d electricity load under emergency conditions.<\/p>\n\n\n\n The important changes<\/strong><\/p>\n\n\n\n The key change in the document comes in extending load shedding stages to stage 16 \u2013 but the structure of the new stages may be unfamiliar to what most South Africans have become accustomed to.<\/p>\n\n\n\n At present, most South Africans understand each stage of load shedding to reflect 1,000MW of power that is removed from the grid.<\/p>\n\n\n\n However, under the proposed structure, this is rather expressed as the percentage of demand<\/strong> assumed by the System Operator at the time the stage is called. The percentages range from 5% of demand at stage 1 to 80% at stage 16<\/strong>.<\/p>\n\n\n\n While these percentages are in-line with the current Code of Practice, the percentages in the code being used now refer to a percentage \u201creduction in load profile of the national non-curtailment load\u201d \u2013 not specifically demand.<\/p>\n\n\n\n The consultation paper also makes no mention of specific ranges (ie, +\/- 1,000MW) as is the case in the standing code \u2013 although this may change in the final document.<\/p>\n\n\n\n \u201cThe specific reduction in load required to stabilize the system under a national supply constraint will be dictated by the power system conditions that prevail at the time,\u201d Nersa said.<\/p>\n\n\n\n The proposed schedules also include the structure for customers who are part of the load curtailment programme.<\/p>\n\n\n\n The proposed stages are as follows:<\/p>\n\n\n\n According to the document, the responsibility for keeping the national electricity grid stable lies with the National Control Centre (NCC).<\/p>\n\n\n\n \u201cIf the NCC requires additional load reduction, utilities may assume this is in the best interest of the grid. The System Operator will undertake to understand, via network studies, the impact and management of the grid under lightly loaded conditions caused by high \u2013 above stage 8 \u2013 stages of load shedding,\u201d it said.<\/p>\n\n\n\n The\u00a0full consultation paper can be found here<\/strong><\/a>.<\/p>\n\n\n\nStage<\/strong><\/td> Reduction required through load shedding<\/strong><\/td> Reduction required through curtailment<\/strong><\/td><\/tr> 1<\/td> All stage 1 load scheduled by utilities
5% of demand<\/td>10% reduction in normal demand profile<\/td><\/tr> 2<\/td> All stage 2 load scheduled by utilities
10% of demand<\/td>10% reduction in normal demand profile<\/td><\/tr> 3<\/td> All stage 3 load scheduled by utilities
15% of demand<\/td>15% reduction in normal demand profile<\/td><\/tr> 4<\/td> All stage 4 load scheduled by utilities
20% of demand<\/td>20% reduction in normal demand profile<\/td><\/tr> 5<\/td> All stage 5 load scheduled by utilities
25% of demand<\/td>30% reduction in normal demand profile<\/td><\/tr> 6<\/td> All stage 6 load scheduled by utilities
30% of demand<\/td>30% reduction in normal demand profile<\/td><\/tr> 7<\/td> All stage 7 load scheduled by utilities
35% of demand<\/td>40% reduction in normal demand profile<\/td><\/tr> 8<\/td> All stage 8 load scheduled by utilities
40% of demand<\/td>40% reduction in normal demand profile<\/td><\/tr> 9<\/td> All stage 9 load scheduled by utilities
45% of demand<\/td>50% reduction in normal demand profile<\/td><\/tr> 10<\/td> All stage 10 load scheduled by utilities
50% of demand<\/td>50% reduction in normal demand profile<\/td><\/tr> 11<\/td> All stage 11 load scheduled by utilities
55% of demand<\/td>Reduction to essential loads or as instructed by SO<\/td><\/tr> 12<\/td> All stage 12 load scheduled by utilities
60% of demand<\/td>Reduction to essential loads or as instructed by SO<\/td><\/tr> 13<\/td> All stage 13 load scheduled by utilities
65% of demand<\/td>Reduction to essential loads or as instructed by SO<\/td><\/tr> 14<\/td> All stage 14 load scheduled by utilities
70% of demand<\/td>Reduction to essential loads or as instructed by SO<\/td><\/tr> 15<\/td> All stage 15 load scheduled by utilities
75% of demand<\/td>Reduction to essential loads or as instructed by SO<\/td><\/tr> 16<\/td> All stage 16 load scheduled by utilities
80% of demand<\/td>Reduction to essential loads or as instructed by SO<\/td><\/tr><\/tbody><\/table><\/div><\/figure>\n\n\n\n
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