State of the System – Winter 2025 Outlook Briefing 5 May 2025 Winter 2025 Outlook briefing Key takeaways and reflections for the Winter 2025 Outlook Group Dan Marokane Chief Executive Key takeaways and reflections for the Dan Marokane Winter 2025 Outlook Group Chief Executive Update on the Generation Recovery Plan Bheki Nxumalo Update on the Generation Recovery Plan Group Executive - Gx Update on Load Reduction and Demand Monde Bala Management initiatives Group Executive - Dx Eskom’s direction of travel to achieve long Dan Marokane term success Group Chief Executive 2 Key Takeaways • Significant improvements have been made since the Summer 2024/25 outlook (Sept 2024 – Mar 2025). However, we have seen some setbacks in operational excellence, as evidenced by the recent loadshedding requirements between Jan to Apr 2025. • Visible year on year performance improvement due to progress in the Generation Recovery Plan led to nine months of no loadshedding, however Jan –April 2025 saw loadshedding implemented on five occasions. • Despite the setbacks, Eskom supplied South Africa with more electricity and reduced loadshedding without excessive use of diesel – an improvement in operational performance. • A clear plan has been developed to address the root causes related to the recent loadshedding events, focusing on people, plant and processes. • Given the progress made to date with the state of fleet performance, Winter 2025 outlook is premised on: • Unplanned outage scenarios revised downwards – ranging between 13 GW to 15 GW (14 GW to 17 GW previous Winter) • No loadshedding expected if unplanned losses remain below 13 GW (at worst, 21 days of up to stage 2 if unplanned losses reach 15 GW2) • Load reduction remains necessary at times to protect the network and people in some areas with rampant illegal connections. We have embarked on campaigns with law enforcement to remove these connections. • Eskom continues to focus on key strategic areas to become an investable, sustainable and competitive company while ensuring long term security of supply. #WeCanEndLoadsheddingTogether 3 • 1: 2025 Budget speech; 2: Eskom may implement higher stages for shorter periods to minimize loadshedding on weekdays Reflections: Eskom’s performance has improved significantly since April 2024, setting a good base to build on 1 April 2024 – 31 March 2025 352 days1 >R16bn2 ~3.1GW of loadshedding free days In reduced diesel spend (1 April Reduction in unplanned load 2024 – 31 March 2025 vs same losses compared to previous period last year). This represents financial year a reduction of ~50% 61% EAF 12.8% PCLF 3.6% Sales growth For FY25, improvement For FY25, slight increase from Estimated Sales volume growth for from 54.55% for previous previous financial year’s 12%, FY25 (compared to FY24 actuals), financial year indicating an increase in planned driven by reduced loadshedding and maintenance activities as part of higher exports3. the Generation Recovery Plan. Acronyms: EAF – Energy Availability PCLF: Planned Capability Loss Factor (Planned maintenance) Sources: 1: Between 1 April 2024 – 31 March 2025 2: Eskom Power Alert: 28 March 2025 2: 20250310_REPORT_Daily Reports Cluster; 3: Mar 2025 Sales and Revenue report 4 Reflections: Number of loadshedding days were lower than expected over Summer period for the likely scenario, although more intense stages experienced between Jan and Mar 2025 Better than expected As expected Worse than expected Summer 2024/25 – 1 September 2024 to 31 March 2025 (212 days)1 Likely scenario expectations Actual performance Scenarios (Base Case + 1 000MW: 14 000MW UCLF) Number of LS days 21 Days 13 Days OCGT costs R 10.3bn R12.4bn2 Highest stage of LS Stage 1 Stage 6 (23 hrs) Month Peak Loadshedding Max Loadshedding stage Loadshedding Max Loadshedding Residual days days stage Forecast September 29 389 1 1 0 0 October 28 928 0 0 0 0 November 28 868 1 1 0 0 December 28 398 5 1 0 0 January 28 105 3 1 1 3 February 28 486 1 1 7 6 March 28 967 10 1 5 3 • Likely scenario anticipated 14 GW of unplanned losses, however due to success of the Generation Recovery Plan, actuals ~12.5 GW during the summer period • Actual planned maintenance of 6 670 MW3 on average over the summer period was in line with assumptions (~6 700 MW) Notes: 1: As per Summer 2024/2025 outlook. 2: YTD as at 30 Mar (weekly OCGT spend report) Acronyms: UCLF – Unplanned Loss Capability Factor. Sources: 3: Generation Daily Report - SharePoint 5 Reflections: The continued improvement in Generation plant performance has resulted in the suspension of loadshedding for 9 months Overview of loadshedding intensity and frequency between Sep 2023 and Mar 2025 Stage 1 Stage 2 Stage 3 Stage 4 Stage 5 Stage 6 # of days at various stages¹ 2023/24 Summer outlook period 2024 Winter outlook period 2024/25 Summer outlook period 2025 Winter 30 30 29 outlook 28 6 2 26 period 8 2 4 20 3 5 4 15 2 9 4 13 13 13 17 8 No loadshedding for 9 months 7 12 12 12 5 2 7 3 7 1 3 0 0 0 0 0 0 0 0 0 1 3 1 2 1 1 2 1 1 1 2 Jan-24 Feb-24 Apr-24 Jun-24 Jan-25 Feb-25 Apr-25 Sep-23 Oct-23 Mar-24 Sep-24 Oct-24 Mar-25 Dec-23 May-24 Dec-24 Nov-23 Jul-24 Aug-24 Nov-24 ▪ An average of 11.6 GW unplanned losses between Sept 2024 and Dec 2024 has resulted in no loadshedding required within the period ▪ Unplanned losses reached 10.9 GW in Nov 2024, the lowest average monthly level achieved since August 2021 (~10.7 GW) ▪ Increased unplanned losses experienced between Jan and Mar 2025 have unfortunately resulted in loadshedding. This is considered a temporary setback, and we continue to focus on the Generation Recovery Plan with the required adjustments Source: Eskom, as at 30 April 2025; 2023/2024 Load Shedding and Curtailment events Notes: 1: Indicates maximum stage per day 6 Reflections: Loadshedding was required in five instances since the start of 2025 As at 25 April 2025 31 Jan 2025 to 2 Feb 2025 (Stage 3) 3 Full unit failures totaling 4 665 MW at various stations, required stage 3 loadshedding days over the weekend to replenish emergency reserves1 22 Feb 2025 – 26 Feb 2025 (Stage 2 – Stage 6) 5 Multiple trips at various stations totaling ~4 400MW and low solar power generation days (high cloud cover) required stage 2-6 loadshedding 7 Mar 2025 – 9 Mar 2025 (Stage 3) 3 Multiple units offline due to unplanned losses (~4 500MW) and outage slip (~1400 days MW), required stage 3 loadshedding over the weekend to replenish emergency reserves Five incidents of 19 Mar 2025 – 20 Mar 2025 (Stage 2) loadshedding 2 Unit losses at various stations totalling ~2 000 MW, including supply reduced from (14 days in total between days imports (i.e. Cahora Bassa), and depleting emergency reserves, required stage 2 stage 2 and 6)2 loadshedding to be implemented Winter outlook 24 April 2025 (Stage 2) 1 Unplanned losses from full unit failures at various stations totalling ~2 160 MW, required day stage 2 loadshedding to be implemented • We are maintaining our focus on the Generation Recovery Plan and Demand Management initiatives to minimise loadshedding requirements over the Winter 2025 period • In the event the need arises, our approach is to minimise the impact of loadshedding on the economy through implementing loadshedding over weekends or outside business hours where possible 7 Footnote 1. Reserves referring to water and diesel 2. If UCLF is above the base of 13 000 MW, the risk for loadshedding becomes very high as emergency reserves rapidly decrease. Days calculated over calendar dates. Despite the setbacks, Eskom supplied South Africa with more electricity and reduced loadshedding without excessive use of diesel – an improvement in operational performance Diesel OCGTs utilisation performance FY23-FY25 (Eskom + IPPs) Actual diesel OCGT production (GWh) Loadshedding / curtailment (hours) Key Insights 1. More energy was produced in FY2025 by Loadshedding / Actual diesel OCGT Eskom than in the previous two years curtailment (hours) production (GWh) 2. Diesel open cycle gas turbines were utilised -45% the least in FY2025 compared to the two 7,000 6,367 6,000 previous Financial years (45% reduction in 6,000 5,557 5,000 utilisation vs FY2024) 5,000 3. Loadshedding in FY2025 (in hours and days 4,000 of loadshedding) was lower than the 4,000 previous two years 3,000 3,000 4. This means that Eskom, through improving 2,000 its generation performance, was able to 2,000 provide electricity to SA without an 1,000 1,000 overreliance on diesel 175 5. This is a clear sign of improved operational 0 0 FY2023 FY2024 FY2025 performance 6. OCGTs are part of the energy mix and are Loadshedding used to manage peak demand periods to 280 329 -96% 13 Days¹ avoid or minimise loadshedding Energy sent out² 191 307 184 576 +6% 195 702 (Eskom only) % Improvement Source: Eskom, as at 31 March 2025; Note 1. The loadshedding days refer to days on which there was loadshedding or curtailment on any part of the day; 2. Excluding IPPs and Imports, Eskom only energy Acronyms: OCGTs - Open Cycle Gas Turbines; IPP – Independent Power Producer Winter 2025 Outlook - No loadshedding expected for unplanned outages below 13 000 MW, stage 2 expected if unplanned outages reach 15 000 MW Change to outlook Winter 2025 – 1 April to 31 August 2025 (153 days) Scenarios Base Case: Base Case + 1000MW: Base Case + 2000MW: 13 000 MW UCLF 14 000 MW UCLF 15 000 MW UCLF Number of LS days 0 Days 1 Day 21 Days OCGT costs R 0.7bn R 2.1bn R 4.8bn Highest stage of LS - Stage 1 Stage 2 Month Peak Max Max Max Loadshedding Loadshedding Loadshedding Residual loadshedding loadshedding loadshedding days days days Forecast stage stage stage April 27,739 0 - 1 1 2 8 2 May 29,259 0 - 0 - 5 1 June 30,777 0 - 0 - 0 - July 30,872 0 - 0 - 5 1 August 29,599 0 - 0 - 3 1 • Our Winter 2025 unplanned breakdown assumptions are revised downwards by 1 000 MW- 2 000 MW against Winter 2024 assumptions, due to improved plant reliability. This results in maximum stage 2 loadshedding expected1 (compared to the previous Winter forecast, which predicted up to stage 5) • Stage 2 incident in April 2025 was due to two units that failed to return as committed, exacerbated by Medupi 5 trip. This pushed the UCLF momentarily beyond 15 000 MW indicated in our winter 2025 outlook • It is important to note that the Weekly System Status reports are not a loadshedding forecasts, but reflects potential reserve shortfalls without considering the available short-term reserve and demand side levers Note: 1: Eskom may have to implement higher stages for shorter periods to minimize loadshedding on weekdays; 2: Average daily planned outages as per Capacity Plan 17 April 2025 BEFORE STERF.; 3. Generation Daily 9 Winter 2025 Outlook briefing Key takeaways and reflections for the Winter 2025 Outlook Group Dan Marokane Chief Executive Key takeaways and reflections for the Dan Marokane Winter 2025 Outlook Group Chief Executive Update on the Generation Recovery Plan Bheki Nxumalo Update on the Generation Recovery Plan Group Executive - Gx Update on Load Reduction and Demand Monde Bala Management initiatives Group Executive - Dx Eskom’s direction of travel to achieve long Dan Marokane term success Group Chief Executive 10 Generation continues to drive the Recovery plan initiatives which have resulted in improved performance Implementation complete Implementation in progress 3 World class performance 70%1 2 Execute excellence 65%1 EAF 1 Set up for success EAF Actions for FY25 onwards Actions for FY24 ▪ Return of Medupi 4 from long term forced ▪ Set-up the enabling structures ❑Successful execution of Koeberg 1 outage ▪ Turnaround plans ❑Sustain excellent Medupi performance ▪ Commercial operation of Kusile 5 ▪ Generation recovery office ❑Embed principles of Operational ▪ Synchronisation of Kusile 6 Excellence ▪ Continuous focus on current and future ▪ Key enablers ▪ Guard performance at current flagship ❑Address internal skills gaps skills stations ❑Prevent outage slips ▪ Ensure successful implementation of Koeberg 2 steam generator and long-term ▪ Medupi, Lethabo, Matimba and Peaking ❑Return of Kusile 1, 2 and 3 operating projects (synchronized to the grid on ▪ Focus on the Priority stations ❑Synchronisation of Kusile 5 30 Dec 2024) ▪ Tutuka, Duvha, Majuba, Matla, Kendal, ❑Review plant shutdown dates based on Arnot, Kriel system requirements ▪ Kusile removed from priority list ▪ Execution of Koeberg 1 Outage ▪ Source external specialized skills Continuous execution of Culture transformation and Strategic Levers as per the Generation recovery plan Note: 1. Month to date for March 2024 and March 2025 11 There is a consistent reduction in unplanned load losses on the back of disciplined execution of maintenance Eskom Gx actual performance on unplanned losses1 Actual avg. unplanned losses FY25 Actual avg. Unplanned losses FY26 GW Setbacks experienced between Jan and Mar due to increase in unplanned -5,0 losses 18,0 16,2 16,0 16,5 15,9 15,8 16,2 14,5 13,7 14,6 14,7 14,9 14,2 12,8 12,0 11,7 11,0 11,9 11,6 10,9 12,1 14,0 13,1 14,2 12,9 Apr- May- Jun-23 Jul-23 Aug- Sep- Oct- Nov- Dec- Jan-24 Feb-24 Mar- Apr- May- Jun-24 Jul-24 Aug- Sep- Oct- Nov- Dec- Jan-25 Feb-25 Mar-25 Apr-25 23 23 23 23 23 23 23 24 24 24 24 24 24 24 24 MTD 2023 Winter outlook period 2023/24 Summer outlook period 2024 Winter outlook period 2024/25 Summer outlook period • Downward trend observed in unplanned losses, specifically driven by five of the priority 8 stations (Tutuka, Kendal, Majuba, Duvha and Kusile) • Unplanned losses of ~13.7 GW between Jan and Mar 2025 was as a result of a lethal combination of undesirable events e.g. clustering of boiler tube leaks (BTL), several other breakdown incidents (PLLs, trips), higher than normal rainfall and delayed returns from planned outages (~1.2 GW) • Comparing the unplanned losses in May 2023 (18 GW) vs April 2025 MTD (12.9 GW) shows an improvement of approximately 5 GW, which further illustrates that the reduction in loadshedding is materially on the back of improved plant performance • Eskom plant availability for FY25 averaged 61% (significant improvement from 54.6% for FY24) and achieving above 65% in July and August 2024 Source: State of the system outlooks; Eskom GPSS daily report (All stations) as of 21 April 2025; S&P BI analysis; Note 1. UCLF+OCLF, Numbers vary marginally over reports as data is refined;; Acronyms: PLL: Partial 12 load losses, Gx – Generation, UCLF – Unplanned Capability Loss Factor; OCLF – Other Capability Loss Factor; MTD – Month-to-date The additional ~794 MW capacity expected by May 2025 will contribute to security of supply Key insights Units on long term outage - return to service dates Despite some delays, three units are still expected to return to service by the end May: Koeberg U1 Kusile U1, 2, 3, 5 Tutuka 1,2, 4, 5 Koeberg 2 Kusile 6 1st Sync Medupi U4 1st Sync • Koeberg U2 was synchronized to the grid on 900 MW ~ 2 880 MW ~ 1 500 MW ~930 MW ~ 800 MW ~794 MW 30 December 2024 • Koeberg U1 is currently on outage for the second phase of long-term operations projects and is expected by July 2025 • Kusile U6 was successfully synchronized Nov 2023 Dec 2023 May 2024 Dec 2024 Mar 2025 May 2025 to the grid on 23 March 2025 at 16h45. The focus is now on ensuring the unit achieves commercial operation by end of • Units 3, 1 and 2 • Unit 1 completed September 2025 have been on 12 Jan 2024 • Kusile U2 & U3 outages have been returned to the completed to reinstate main stacks and grid and are • Unit 2 returned on FGD. Kusile U1 is currently on outage providing power 27 December 2023. and will return in June connected to the main up to 2 160 MW stack • Unit 5 • Unit 4 Returned • Medupi U4 is expected to synchronize by commercial on 22 April 2024 May 2025 operation • Unit 5 returned on Over and above the commissioning of new units achieved on 30 26 June 2024 and returning units from long term outages, June 2024 continued operation of five coal stations1 up to 2030 is crucial to support with security of supply 13 Note: Data as at 30 April 2025. 1. Continued Operations stations will not operate past 2030 as per the DFFE communications – Arnot, Camden, Grootvlei, Hendrina, Kriel Generation needs to leverage and re-enforce the performance gains made in the last year, however Gx must also do things differently for sustained performance It must be acknowledged that there has been a marked improvement in plant availability such that chronic loadshedding has declined i.e. frequency and severity. However, there is an ongoing need to deepen continuous improvement to entrench a systems, people, process mindset. Things to be Re-enforced Things that will be done differently Entrench “Systems, People, Process” mindset Leadership development focus – Fast tracking/prioritizing the intervention to equip • Refocus both supervision on routines and on managers service providers • Drive the operational excellence program to Resources – Fast track resourcing to augment embed the culture at management /supervisory/technical to close the gaps based on identified station gaps Additional support required Procurement Challenges of long lead • Typically, change programs over several years call spares - Devise new and faster ways to effect for constant a re-focusing the teams procurement on long lead items. Now that we • New challenges may often require additional know the challenges in the outage space further support to overcome the culture change inertia engagements to happen with Central procurement Winter 2025 Outlook briefing Key takeaways and reflections for the Winter 2025 Outlook Group Dan Marokane Chief Executive Key takeaways and reflections for the Dan Marokane Winter 2025 Outlook Group Chief Executive Update on the Generation Recovery Plan Bheki Nxumalo Update on the Generation Recovery Plan Group Executive - Gx Update on Load Reduction and Demand Monde Bala Management initiatives Group Executive - Dx Eskom’s direction of travel to achieve long Dan Marokane term success Group Chief Executive 15 Despite supply exceeding demand, load reduction is necessary at times to protect the network and people Loadshedding Load Reduction Generation Transmission Distribution • When there is insufficient • When the customer demand is generation capacity to meet higher than what the local demand equipment can withstand • Loadshedding implemented to • Load reduction implemented to protect the country from a black protect equipment (transformers) out and people (explosions) Eskom is working together with SALGA and the Ministries to resolve the structural challenges facing the distribution industry WE NEED COMMUNITIES TO HELP US PROTECT OUR EQUIPMENT FROM CRIMINALITY 16 Load Reduction is primarily implemented in provinces with high levels of distribution energy losses Overview of network energy losses1 Overview of load reduction2 (% of total SA losses) (% of total Load Reduction) 13% 22% 29% 11% 30% 22% 9% 3% 3% 11% 20% 13% 3% 1% 7% 1% 6% 0% ▪ Load Reduction is a critical and essential proactive measure of asset protection to reduce load and prevent overloading ▪ Load Reduction is influenced by overloading (linked to theft and condition of distribution network infrastructure) ▪ Gauteng experiences the highest Load Reduction on average with combined morning and evening peak Load Reduction averaging 179 MW, followed by Mpumalanga (~132 MW) and Limpopo (~103 MW) ▪ Several interventions continue to be driven to minimise the impact of Load Reduction on South Africa Note: 1: As per FY24 Mar YE figures, of which ~70% are expected to be from theft; 2: Based on average MW reduced over FY25. Load Reduction data are estimates and will still undergo further validation; 17 Eskom is driving strategic initiatives to minimise load reduction over and beyond the Winter 2025 period, continued support from government and the public is required Technology Eskom is driving technological interventions • Roll out of ~7.2 million smart meters over the next 3 years to reduce losses and enable load limiting as opposed to load reduction • Accelerating Distributed Energy Resources (e.g. microgrids) to alleviate constraints on network Government Eskom is working closely with government where partnership is required, specifically on: support • Accelerating the role out of smart meters within municipalities • Reduction of technical and non-technical losses within municipalities and auditing of networks • Acceleration of process adoption for Accelerating Distributed Energy Resources connection within municipalities Public Continued support from the public is crucial to minimise load reduction: programmes • Reduce load when the system is constrained • Practice energy efficiency • Participate in demand reduction programmes where applicable 18 The Distribution Demand Management Programme is being implemented to deliver ~1 GW over the winter period • Demand Side Management (DSM) - Incentive programme targeting Winter Outlook - Demand Management evening peak load management and energy efficiency through technological MW Capability intervention. 1200 1054 • Supplemental Demand Response (SDR)– Flexible evening peak load 1000 reduction programme, participating customers reduce load when called 800 upon. 600 • Interruptible agreements – Electricity agreements with participating 447 customers. 400 353 204 • Smart meters -Load Limiting – Emergency capability, limits customer 200 50 supply to form 60/40 Amps down to 5 Amps. 0 EEDSM (PC) DR _Supplemental DR _ Interuptible Smart Meters Total Projected Load Limiting The implementation of Demand Management provides the following benefits: Reduce the usage of diesel costs Optimise cost of energy through Optimising the national system profile via Mitigation tool to reduce the especially during evening peak transfer pricing during peak demand management products impact of load shedding times. periods. 10% of all Government Buildings (>1 000 m²) to display an Energy Performance Certificate (EPC). Eskom has committed to comply with EPC requirements. 19 Winter 2025 Outlook briefing Key takeaways and reflections for the Winter 2025 Outlook Group Dan Marokane Chief Executive Key takeaways and reflections for the Dan Marokane Winter 2025 Outlook Group Chief Executive Update on the Generation Recovery Plan Bheki Nxumalo Update on the Generation Recovery Plan Group Executive - Gx Update on Load Reduction and Demand Monde Bala Management initiatives Group Executive - Dx Eskom’s direction of travel to achieve long Dan Marokane term success Group Chief Executive 20 Our strategy pivots Eskom into a sustainable and competitive Company while leading the transformation of the Electricity Supply Industry Commercial mandate Social mandate Assist in lowering the cost of doing business in SA, enabling Our Mandate Providing Electricity in an efficient and sustainable manner Economic growth Our Vision Our Purpose Sustainable power for a better future Powering growth sustainably Shareholders Priorities Achieve Universal Access, Qualitatively transform energy Attain sovereign and regional energy Drive industrialisation and lead Assert SA, continental and global Availability, Affordability and demographics; elevate role of security innovation energy leadership Quality women and youth Eskom Strategic Objectives Pursue financial and operational Facilitate a competitive future Strive for net zero emissions by Modernise our power system sustainability energy industry 2050 • Recover and sustain EAF to 70% in • Define Eskom’s role in the energy • Accelerate TDP execution incl. • Drive Komati, Grootvlei, Hendrina, the long term transition and in the future alternative funding models Camden repowering and repurposing initiatives • Implement innovative solutions including • Operationalise Dx, establish NewCo • Strengthen Distribution network Distribution Agency Agreement to and operationalise Gx infrastructure incl. smart meters and • Collaborate with government on reduce municipal arrear debt & • Fine-tune Gx and Dx business models, microgrids rollout Minimum Emissions Standards and energy losses to improve customer centricity environmental compliance • Increase flexibility of power system • Rebase costs, maximise profitability • Drive clean energy project infrastructure • Participate in Distributed development through the establishment of Energy Resources (DERs) and • Strengthen leadership stability and • Develop and implement digitalisation drive eMobility RECo upskill & reskill employees for future strategy opportunities • Develop Eskom’s PSP/PPP model and unit Improve controls & governance Entrench a high-performance ethical Use data analytics to create value and Obtain unbundled tariffs approval Drive processes to address fraud, culture, innovation and agility enhance decision making (NERSA) socio-economic transformation corruption and criminality OUR VALUES: Zero Harm Integrity Innovation Sinobuntu Customer Satisfaction Excellence 21 Eskom is focusing on key strategic areas to become an investable, sustainable and competitive company while ensuring security of supply Key focus area Description ▪ Implementing operational recovery, strengthening governance to future proof the Turnaround organisation (ending loadshedding, reducing costs, investing in future expansion) and ▪ Enabling energy security, growth and long-term sustainability to the benefit of South loadshedding Africa and sub-Saharan Africa ▪ Providing employees with a vision and purpose to their work which creates an People and environment for success performance ▪ Re-focussing on people through leadership with a high challenge, high support culture ▪ Reversing complacency and taking action to address systemic issues ▪ Developing a meaningful pipeline of clean energy projects (~5.9 GW by 2030) Long term ▪ Accelerating the implementation of the Transmission Development Plan sustainability ▪ Restructuring of electricity tariffs and rolling out smart meters for effective revenue collection, while minimising the impact on consumers and the fiscus ▪ Pursuing Just Energy Transition strategy as a considered approach towards Balanced transitioning from high emitting sources of energy towards cleaner energy without transition jeopardising socio-economic welfare 22 In Conclusion • We have seen a positive trend in the reduction of unplanned load losses, leading to 352 loadshedding free days between 1 April 2024 and 31 March 2025 • The Winter 2025 unplanned losses outlook has been revised downwards (1 GW – 2 GW improvement), indicating no loadshedding to be expected if unplanned losses remain below 13GW • Through disciplined execution, dedication of our people and support from various stakeholders, our Generation Recovery Plan will continue to deliver good results • We again apologise for the few temporary setbacks. The performance has laid a good foundation to implement our strategy towards an investable, competitive and sustainable Eskom • Over the coming months, we will continue providing updates against the implementation of our strategic initiatives • We would like to thank all stakeholders, especially the Eskom Guardians for their hard work and dedication in moving Eskom towards success #WeCanEndLoadsheddingTogether 23 Question & Answer session Solar registration fees continue to remain zero for the majority of Eskom’s residential customers and include a free smart meter until March 2026 SSEG registration SSEG including PV installations are to be registered with the relevant supplier as per NERSA requirements. Connection Charges • Urban Residential and up to 50kVA: No registration fees and a saving of ~R9 132 on connection charges including a free SMART meter since March 2023 until March 2026. • Other SSEG: No increase as they are to pay last year’s connection charges from 1 April 2025. Applicable Tariffs ➢ Residential : Homeflex ➢ Urban : Miniflex ➢ Rural: Ruraflex ➢ Generators: Gen DUoS, Megaflex Gen or Ruraflex Gen Credits for exported energy • Gen-Wheeling, Gen-offset and net-billing rates. • Credits for energy exported on time-of-use on the customer bills. Non-residential or >50kVA additional scope • Once-off application and connection fees are payable to recover the cost of technical studies and compliance checks to ensure safe grid integration. • Payment for a smart meter which is compatible with the TOU tariff Note : Customers with a grid-tied generator connection must comply with NERSA's registration requirements, regardless of whether they export electricity to the grid or not. 25 25