System Status and Outlook Briefing Jan Oberholzer: Chief Operations Officer Rhulani Mathebula: Group Executive Generation (Acting) Segomoco Scheppers: Group Executive Transmission Megawatt Park: Franklin Auditorium 22 October 2020 Contents 1 Performance Review to September 2020 - COO 2 Progress with existing 9-Point Recovery Plan – GE: Gen 3 System Outlook: September 2020 – March 2021– GE: Trans 4 Conclusion 2 Overview and summary of Eskom system performance (1/2) The impact of COVID-19 reduced the energy demand and allowed for the execution of additional short-term maintenance to address emergent issues, including those that contributed to partial load losses (PLLs) The subsequent move to Levels 4, 3, 2 and 1 during July – September 2020 saw an increase in demand and lower EAF, significantly increasing OCGT usage, especially in July and August 2020 where load factors were approximately 10% Unfortunately, this increasing demand and low plant availability also meant that Eskom was forced to implement load shedding during July 2020, August 2020 and September 2020 The primary cause of the Jul/Aug/Sep 2020 load shedding was the high levels of unplanned losses throughout the Generation fleet (the winter plan assumed 11 000 MW unplanned losses): • Trips, other units forced off and late return of units (up to ~4 000 MW) • Camden not available due to ash dam constraints (~1 300 MW) • Koeberg unit 2 on cold reserve/outage (~700/920 MW) • Unavailability of non-commercial units at Medupi and Kusile (~1 700 MW) 3 Overview and summary of Eskom system performance (2/2) Planned maintenance (PCLF) with focus on reliability maintenance increased gradually and currently around 12% (between 5 500 MW and 6 000 MW) The power system is vulnerable and volatile with the risk of load shedding significantly reduced after the completion of the reliability maintenance by September 2021 Continued focus is placed on correcting new build defects, extending the life of operating units, reducing unplanned outages and managing coal quality and handling related issues Transmission network performance has seen a marked improvement with continued focus on maintenance Customers continue to experience less frequent interruptions as measured by SAIFI and better than targeted restoration time for network faults We continue to ask South Africans to reduce demand as a concerted collective effort can help to reduce or avoid loadshedding We regret that we are inconveniencing customers while we address system constraints 4 Nuclear Performance YTD Sep 2020 0 81.35% 1.74% UAGS Trips vs. target of 1 for Q1&2 FY21 EAF Actual YTD vs Forced Loss Rate vs. YTD Target of 80.57% YTD Target of 2.45% 98.75% 95% SGR Readiness vs LTO Readiness target plan vs target plan  Unit 2 refueling and maintenance outage completion  Steam Generator Replacement (SGR) - on track for 2021 installation - Three of the six SGs (for 1st unit) have been completed and delivered to the site. The remaining 3 are at various stages of completion 5 Koeberg Nuclear Power Station Recent noteworthy items related to Koeberg:  Unit 2 refueling and maintenance outage completion  Steam Generator Replacement (SGR) - on track for 2021 installation – Three of the six SGs (for 1st unit) have been completed and delivered to the site. The remaining 3 are at various stages of completion  The September earthquake in the Western Cape area, which measured 2.7 on the Richter scale had no impact the plant ‒ Koeberg is designed for an event of 7.0 on the Richter scale. Incremental plant improvements have increased the resilience of the plant to major external events. 6 New Plant: Overview Status in November 2018 Progress to date • Steercom between Eskom and MHPSA • Medupi Unit 3 has achieved five established consecutive months of improved performance since design modification • Design defects at Kusile and Medupi identified New plant • The availability and reliability of the synchronised units at Medupi, and Kusile • Technical solutions agreed between Eskom are steadily improving and MHI for the boiler defects at Medupi and Kusile • Units in Commercial Operation: Medupi Units 6, 5, 4, 3, 2 (3 970MW) and Kusile Unit 1 (800MW) • Medupi Unit 1 on track for target Commercial Operation: July 2021 • Kusile Unit 2 on track for target Commercial Operation: January 2021 • Kusile Unit 3 on track for target Commercial Operation: March 2021 • Currently, six units at Medupi, three units at Kusile are contributing energy to the National Grid 7 New Plant Major Design Defects: Medupi and Kusile Power Station Medupi Power Station Kusile Power Station  May 2020: Unit 3 reaches full 793 MW  Boiler plant modification outages to capacity after 75-day outage for boiler start mid 2021 for running units (1, 2 and plant modifications to design defects. 3)  Design modifications roll-out include:  Boiler plant modifications on construction units (4, 5 and 6) to be done before June 2020: Unit 6 - Gas Air Heater and Commercial Operation Fabric Filter Plant  Unit 3 is currently on outage September 2020: Unit 1 - Gas Air Heater,  August 2021: Unit 3 – 30 day bag Fabric Filter Plant, Erosion Protection, replacement start Short Lead Items on Milling Plant  June 2021: Unit 1 – 75 day outage start ‒ October 2020: Unit 4 - Gas Air Heater, Fabric Filter Plant, Erosion Protection,  September 2021: Unit 2 – 75 day outage Short Lead Items on Milling Plant start ‒ January 2021: Unit 2 – 75 day outage  January 2022: Unit 3 – 75 day outage completion start ‒ May 2021: Unit 5 – 75 day outage start 8 Overview of Transmission Performance – Sept ’20 SM<1 of 1.32 vs YTD target of 1.75 95.9% Maintenance Completion 2 Major Incidents vs YTD target of 92.3% vs YTD target of 1  Performance improvement attained YTD with SM<1 losses  Major Incidents resulted due to abnormal plant failures which impacted large load customers  High levels of maintenance completion has been sustained notwithstanding initial challenges due to COVID-19 lockdown  Asset condition risks require increased asset renewal investment going forward for future operational sustainability  Ongoing theft and vandalism has impacted operations creating risks for interruption incidents 9 Distribution performance : 30 September 2020 Electrification SAIDI SAIFI 63 909 38.1 14.8 vs. vs. vs. 31 105 target 38.0 tolerance 19.6 tolerance Planned Maintenance Refurbishment Restoration time Completed* Spent * 88.5 97.0% 93.3% vs. *YTD target *YTD target 90% target  Planned maintenance - initially delayed by Lockdown L5 protocols; maintenance activities has since ramped up with a recovery to 88.5% of the YTD target. Plans are in place to recover on the backlog  Refurbishment expenditure is at 97% of the YTD target. Higher levels of investment is however required to sustain technical performance and consequent reliability of supply to customers  Network Risk: Theft and vandalism remains a major challenge to operations and the reliability of supply to customers. Eskom has engaged on several security system enhancement projects to stem the tide 10 Generation performance for YTD Sep FY2021 239 67.9% UAGS Trips vs. 224 target for Q2 FY21 18.6% EAF Actual YTD vs. Unplanned load losses 70.0% internal target 3 608 MW vs. 18.5% target for FY21 for FY21 Partial Load Losses vs. 3 150 MW target for FY21 10.0% R1.37bn Planned maintenance Open Cycle Gas vs. 8.0% target Q2 FY21 Turbines cost vs budget of R561.1m Technical Targets are awaiting approval by DPE and are therefore subject to change. Figures as at end September 2020 11 FY21 EAF performance in recent months is lower than the similar period last year, however, UCLF has improved slightly and more planned maintenance is being executed Generation monthly and YTD performance Contributing factors Percentage (%) OCLF UCLF PCLF EAF • EAF improved in May and June 2020, with a 1 1 1 1 1 2 2 2 2 2 1 1 2 2 5 4 4 4 2 4 reduction in PCLF and then decreased in 19 18 22 22 19 19 22 22 23 17 18 19 20 19 19 19 subsequent months as 28 26 28 29 maintenance increased 12 9 6 5 10 11 15 7 5 7 10 • 6 Camden units have 9 10 9 11 14 8 9 returned to service 10 8 following the shutdown of all the units due to Ash Dam Constraints • Gx fleet continues to experience challenges 71 71 72 69 71 72 68 68 68 66 67 69 66 68 in terms of reliability 63 64 65 65 60 61 and availability • During the year, a delicate balance was required to giving the plants opportunity for planned maintenance May’19 Apr’19 Jul’19 Feb’20 Apr’20 May’20 Oct’19 Jul’20 Jun’19 Jan’20 Jun’20 Aug’19 Sep’19 Mar’20 Aug’20 Sep’20 FY21 YTD Nov’19 FY20 YE Dec’19 and the having the plants available to support the system YTD Figures as at 30 Sep 2020 12 Lower demand during Level 5 lockdown allowed for increased short term maintenance (ST PCLF) but related restrictions meant that some reliability outages (LT PCLF) had to be delayed to later in the year ST PCLF LT PCLF 11 000 10 000 9 000 8 000 7 000 6 000 5 000 4 000 3 000 2 000 1 000 0 2020/04/01 2020/09/30 As at end 30 Sep 2020 13 Partial Load Losses, Full Load Losses, the Camden Ash Dam constraints, slips and major incidents have been the major contributors to the increase in total unplanned losses Build-up of Unplanned Losses for FY2021 Sept YTD from major contributors 24 298MW 248MW 9706MW 22 Other Losses OCLF Major Events 1027MW 0.6 0.7 20 3598MW 8133MW 2,4 18 16 14 8,2 12 478MW 590MW 22,2 10 1.1 905MW 1,4 18,6 8 2561MW 5.9 2,1 6 4 3,1 2 2,7 0 FLLs BTLs Trips Outage Slip PLLs Total UCLF Camden Coal OCLF Other Total Shutdown OCLF Unplanned Key insights  Partial Load Losses (PLLs) continues to be the biggest contributor to UCLF for FY2021 YTD  7 Events (DV2, HN7, KD5, ML2, TT2, TT5 and TT6) contributed more than 300GWh each towards Major Events (300GWh is equivalent to a 600MW unit being off for approximately 3 weeks).  246 Full load loss events account for 3.1% UCLF and 86 BTL events account for 2.1% UCLF  266 UCLF related trip events account for 1.4% UCLF, 63 Outage Slips account for 1.1% UCLF YTD Figures as at end Sep 2020 14 Coal Fleet Yearly EAF Performance shows that the performance has continually been declining EAF % PCLF % EUF % Capex (R’ Bn) Key Insights 100 93 91 93 93 93 • Yearly Coal EAF has been 88 90 90 85 87 87 83 steadily declining since 80 80 84 FY2010 with an improvement 80 in FY2017 and FY2018. 70 76 75 75 72 70 • The improvement could partly 68 67 60 63 be related to increased 61 50 14 maintenance in FY2016 and 13 FY2017. 40 12 11 11 10 9 10 9 10 • Performance shows a direct 9 8 30 relation between EAF and 20 EUF, i.e. the drop in 12 13 8 10 9 10 10 10 10 availability, results in higher 10 6 5 6 utilisation of the available 0 plants capacity. FY2011 FY2010 FY2012 FY2013 FY2014 FY2015 FY2016 FY2017 FY2018 FY2019 FY2020 FY2021 YTD Sep • In recent availability has significantly reduced resulting in the need to run the available coal plant hard to meet the system demand. • Energy Availability (EAF) Factor for a plant is the percentage of the maximum energy that it can supply to the grid (after • The load factor has been factoring for planned and unplanned shutdowns) • Load Factor (LF) measures how hard the plant is running against its maximum possible output (i.e. when EAF is 100%). declining with years • Energy Utilisation Factor (EUF) measures how hard the plant is running when it is available (using the actual EAF). 15 Benchmarking EUF % Benchmarking EUF % All Coal Sizes 2000 - 2018 67 VGB Units - Current Year (excl. Eskom Units) Energy Utilization Factor (EUF %) 95 85 75 65 55 45 VGB Worst Quartile VGB Median VGB Best Quartile Eskom Worst Quartile Eskom Median Eskom Best Quartile 35 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 Calendar Years 16 Something Important to Note 17 Contents 1 Performance Review to September 2020 - COO 2 Progress with existing 9-Point Recovery Plan – GE: Gen 3 System Outlook: September 2020 – March 2021– GE: Trans 4 Conclusion 18 The plan covers load losses, coal stock, people issues and preparation for adverse circumstances and is aligned to the Maintenance Recovery project 1 New Build (addressed above) 2 6 Full load losses and Unit Trips trips Human Capital 3 7 Units on long-term OCTG Usage forced outages 4 8 Partial losses, Boiler Reduce emissions tube leaks 5 9 Outage duration and Coal Management slips 11 Unit Trips Stream Status in November 2018 Progress to date 1 2 • With the exception of August • FY20 official trip 2020, FY2021 monthly coal performance was 231 station official UAGS trips have compared to a target of remained lower than FY2020 376 New plant trips for 5 out of 6 months. • Current YE performance • 11 of 15 coal stations have based on linear projection fewer UAGS trips in F2021 than is 461 official trips. F2020. • Tutuka was the largest • Komati’s last UAGS trip was on contributor to official trips Unit trips 22 May 2020 (BU has 2 units in and showed the biggest service) improvement by March ’20 • Lethabo’s longest run without a • The implementation plans UAGS trip across 6 units in for the Top 4 Power F2021 was 104 days Stations have been • 3 Stations had zero UAGS in assessed & in execution Sept ‘20 Komati, Matimba and with KPIs to monitor Medupi progress, official trip investigation support and improvements to unit testing 20 Units on long term forced outages 3 Stream: Units on long term forced outages Assessment phase Progress in line with plan Progress at risk Returned Description Status/progress • High Pressure steam pipe failure on 10 October 2018 Lethabo • The High Pressure pipework completed , busying with extensive Unit 5 Returned commissioning (600MW) Duvha • On 23 August 2017, turbine tripped on generator stator Unit 4 earth fault – returned on 06 Nov 2018 but was shut down Returned (600MW) again to address a Generator H2 leak Grootvlei • Auxiliary steam range pipe burst on 26 January 2018 Unit 2 • Also experienced generator issues Returned (200 MW) • Initial delay due to funding constraints Kriel • Stator earth fault on 03 May 2018 Unit 2 Returned (600MW) Matla • Cold reheat non return valve leak experienced on 05 February Returned Unit 5 2019 (575MW) Duvha • Generator Stator fault on 17 Jul 2019 Returned Unit 1 • Stator rewind completed, busy with commissioning activities (600MW) Duvha Unit 3 • Board Investment & Finance Committee cancelled project Project Cancelled (600MW) Kendal Unit 5 • Emission plant refurbishment outage that will include a major RTS April 2021 (640MW) General Overhaul 21 Partial load losses and Boiler tube leaks Stream Status in November 2018 Progress to date • Year to Date partials were 4 • Several PLL improvements contracts with long 4 215MW supply lead times are either finalized or in the Partial losses procurement phase, this includes plant areas such (PLLs) and Boiler • Boiler tube failure reviews in progress as cooling towers and feedwater heaters tube leaks • The Boiler Tube Leak Reduction Programme reviews have been completed for all stations. Implementation of corrective actions is currently in progress. • To reduce boiler tube leaks adequate funding and maintenance space is required to ensure the correct extent of repairs during outages. 12 Month Actual Partial Load Loss performance Gains made during the lock-down period have 6117 6000 been sustained for the 6 month period from April 5620 5769 2020 5313 5012 It is expected that the partial load loss performance will deteriorate during the summer 3675 3626 3526 3679 3742 months. The risk of partial load losses increases 3391 due to the hotter weather conditions and rain Sustaining and improving partial load loss performance requires investment in identified key plant areas that negatively affect the performance of stations 22 Outage duration and slips Stream Status in November 2018 Progress to date 5 • Engineers identified to • 90% Reliability Maintenance Recovery (RMR) be redeployed to power Implementation Committees have been stations activated • Developed plan to focus • Teams assigned to ensure outage scope Outage on ERI performance – assurance & outage planning. duration and enabling contracts, skills, • Outages in execution slips spares and quality • RMR Team now integrated with all the management & outages in execution focusing on critical paths Maintenance Recovery Upfront Outage Execution planning readiness quality 23 Human Capital Stream Status in November 2018 Progress to date 6 • Identified critical vacancies and • 1 384 of the 1 852 critical positions skills gaps at power station identified under special dispensation management, operations and were filled by April 2020 maintenance areas • In the process of filling the GE Generation position following resources optimisation in August 2020 • Three Cluster Managers have been appointed • Power Station General Managers appointed and in the process of filling 4 new positions created with the appointment of the cluster managers Human Capital • Two power station managers suspended due to poor performance of stations, two acting ones returned to previous jobs • Senior Technical Plant managers appointed in April 2020 • Tier 1 Manager positions have been filled • 204 of Eskom qualified Learner Plant Operators have been appointed to date • Engineering resources have been deployed to power stations to build technical capacity and experience • 9 400 people relinked to business units 24 Eskom dashboard for Corona Virus 6 Dash-board for CORONAVIRUS (SARS-CoV-2) COVID-19 Updated 14/10/2020 Cumulative Total Cases Number of people Employees 1 678 who have tested Contractors 315 1 993 positive for COVID-19 Number of people Employees 1 555 who have recovered from COVID-19 and Contractors 309 1 864 are back at work Number of people Employees 27 who have died due to COVID-19 related Contractors 2 29 illness/es 25 OCGT usage is over budget by just over R800m 7 • OCGTs utilised this week, after three weeks of no R1.37bn OCGT usage • Average tank levels are currently at 98% Open Cycle Gas Turbines • Increased diesel storage cost vs budget of R561.1m capacity to be finalised by end October 2020 26 There has been significant progress in the reduction of emissions Stream Status in November 2018 Progress to date 8 • Eskom delays to • Focus on 5 of the 87 generation units implementing emission where emissions are high - a potential risk retrofit projects within to 3 153 MW committed timelines could • Contracts have been placed for Kendal lead to medium term risk Electrostatic Precipitators (ESP) and High of 9 000 MW Frequency Power Supply (HFPS) • Lethabo and Tutuka HFPS have been • Non-compliance with delivered on site and outages to install Atmospheric Emission them are in progress Reduce Licence limits could lead to a • Tutuka Dual Flue Gas Conditioning pilot Emissions short term risk of 6 633 MW plant equipment has been delivered on site and being installed • Tutuka Fabric Filter Plant for 3 units tender adjudication in progress • Performance for the past two years has been poor at 0.48kg/MWh sent out, this is mainly due to Kendal’s poor performance • 2020/21 year to date performance showed promising improvement at 0.35kg/MWh sent out Continuous engagement with Department of Environment, Forestry and Fisheries (DEFF) 27 Emissions poor performance has been mainly due to Kendal power station (1/2) Stream Progress to date 8 • Repaired and improved performance on the dust handling plant on all units and achieved compliance on units 1 and 2 • The tender for unit 5 & 6 refurbishment went out in March • The tender for the Kendal HFPS will be placed within the next month Reduce • Performance improved slightly year on year from 1.96kg/MWh sent out YTD Emissions Sept 2019/20 to 1.06kg/MW hour sent out YTD Sept 2020/21 • The latest strike action impacted negatively on ash handling but the station is focusing on addressing the set back 28 Emissions poor performance has been mainly due to Kendal power station (2/2) Stream Progress to date 8 • We have done the following: • In addition to outages taken in the first half of the calendar year, outages are provided for repairs and optimisation of plant to ensure improved performance. • The integrated emission reduction plan was completed and approved by DEFF. • The operating procedure provides for load losses to be taken to ensure compliance on unit 1 and 2 and to demonstrate duty of care on Reduce the remaining operating units. Emissions • Currently doing the following: • Unit 5 is on long duration outage for ESP field replacement and DHP repairs and High Frequency power supply (HFPS), return to service date is April 2021. • Unit 6 outage will go on outage in 2021, contracts have been placed for ESP refurbishment and HFPS • The following is on the plan: • Resolving coal quality issues • Increased focus on the repair and operation of the dust handling plant Coal Management 9 Stream: Fix coal stockpiles Progress to date • No power station below the Grid Code requirement or below the Challenge Eskom prescribed minimum level • Significant improvements with the stock days recovery were achieved. All Power Stock pile Stations are at their Eskom prescribed Expected Levels levels • 58.3 days as at 08 October 2020 *Excl. Medupi & Kusile • The plan is to manage the Total System average stock to not less than 37 days  In the light of the COVID-19 pandemic, mines, transporters and other suppliers in the coal supply value chain are operational. Should the suppliers' employees be Risks infected, supply from the respective mines would be at risk, however the risk is being managed • Good progress regarding initiatives to reduce coal quality related OCLF since July 2020. Focused initiatives to reduce of load losses from. Kriel and Matla has Coal Quality contributed to reduction of coal related OCLF. The YTD Sept FY21 coal related OCLF is 0.59% 30 Reliability Maintenance Recovery Programme Apr’20 – Sept’20 24 Formal risk reviews conducted and more than 600 risks recorded. Six formal risk mitigation projects kicked-off (Procurement, Engineering, Working Capital, OEMs Etc.) Fixed Term Contracts: 334 applications, 48 interviews, 11 appointments - all African (including 2 females) Project teams deployed on 11 Power Stations with ~220 plus dedicated resources. Core support team with ~60 resources rolled out. Outage CAPEX approved till FY23 including long lead orders A number of Power Station units running more than 100 days without a trip. Current morale in Generation is improving slowly A number of outages (9) have been identified by the project as KPI’s to open the breaker with 80% plus and higher readiness with significant impact on MW’s contribution. 80% assures a reliable return for a unit Average EAF 65%, PCLF increased from 9.6% to 14.66%. UCLF reduced from 23% to 19% . The ratio between PCLF, UCLF and OCLF must first be corrected. Step change in EAF expected in April to August 2021 31 Generation Reliability Maintenance Plan (April 2020 to March 2021) Of the 68 unit outages totaling 32794 MW that is in the maintenance plan from April 2020 to March 2021, 18 are completed, whilst 12 are executing and 38 are scheduled Generating Units, MW Generating Units, # 8587 Completed 18 Completed Executing Executing 18316 38 5891 Scheduled 12 Scheduled A further 12 short-term outages were undertaken from April to September 2020 Generating Units, MW Generating Units 640 1 Completed Completed Executing Executing 4383 11 Generation has committed to implement the maintenance & refurbishment plans to recover existing plant availability & reliability with the risk of loadshedding still prevalent in the 18 months ahead • 9 key reliability maintenance outages totalling 5 192 MW (or >11% capacity) will receive focused support through the Reliability Maintenance Recovery Programme up to winter of 2021 • The return of Camden units (by end Oct’20) and Kendal unit 5 (end Mar’21) will add more than 1600 MW (>3% of capacity) that has not been available for the most of the financial year • The partial load loss reduction programme has a remaining opportunity in excess of 1000MW to be recovered for the remainder of the financial year • Focus groups will drive Rain Readiness plans, safe operation of Ash Disposal facilities, Emission and Water management risks to protect against incurring further capacity loss • In the medium term the investment in cost plus mines will secure the coal supply and quality requirements within a controlled cost base 33 Contents 1 Performance Review to September 2020 - COO 2 Progress with existing 9-Point Recovery Plan – GE: Gen 3 System Outlook: September 2020 – March 2021 – GE: Trans 4 Conclusion 34 System Status Outlook  The majority of the coal power stations are operating past the midway of their operational life, resulting in high amounts of breakdowns.  The drive to implement the reliability maintenance and refurbishment projects in order to address the unreliability is under way to get the plant performance back to acceptable levels by late 2021.  The public is therefore cautioned to expect an increased risk of loadshedding during this period. 35 System Outlook: Components of the Plan Four critical components make up the Plan and determine the need for OCGT generation usage and load shedding: Installed generation capacity: This includes new build non-commercial generators and dispatchable IPP OCGTs but excludes self-dispatch renewable generation Demand forecast: The residual demand forecast (total demand less demand supplied by renewable generation) is used PCLF: Planned generation outages for maintenance UCLF + OCLF (Unplanned unavailability): Unplanned generation outages 36 Capacity Outlook Summary: Oct 2020 – Mar 2021 Available Capacity Gas units Operating Reserves PCLF UCLF Peak Demand Installed Capacity 50000 45000 UCLF Summer UCLF 10000 MW 40000 35000 PCLF 30000 Operating Reserve Gas 25000 Available Capacity 20000 Oct Nov Dec Jan Feb Mar 2020 2021 To execute this plan OCGT usage is anticipated. The unplanned allowance is projected at 10000 MW from October 2020 – March 2021 37 Summary of the Plan All reliability maintenance required in the 18 month planning period has been accommodated in the plan. This has resulted in a “full” plan with little room to move, extend or add outages. Maintenance outage planning was done using a UCLF assumption of 10 000 MW for all months considered. This outage plan was stress tested with 3 scenarios by the System Operator to estimate the OCGT usage and level of load shedding. For the summer months of FY 2020/21, 12 000 MW, 13 000 MW & 14 000 MW of UCLF were used to stress test the Plan. For FY 2021/2022, 11 000 MW, 12 000 MW & 13 000 MW was used for winter and summer months. For the most part the System Operator will need to source operating reserves from Demand Response (DR) products as well as from emergency reserve sources such as Interruptible Load Shedding (ILS) and OCGTs. Even at relatively low (< 11 000 MW) levels of UCLF, the Plan requires extensive OCGT usage over weekdays, and low diesel usage most weekends. 38 Unplanned Outage Performance Summer 2020-21 Summer UCLF+OCLF Frequency (01-Sep-2020 to 31-Mar-2021) Tue 01-Sep-2020 to Sun 18-Oct-2020 Base Plan Assumption Base Plan + 1000MW Risk Base Plan + 2000MW Risk 35,0% 100 31,9% 90 30,0% 28,6% 80 25,0% 70 Frequency in % 60 20,0% 50 15,0% 13,5% 12,2% 40 10,0% 9,3% 30 20 5,0% 3,4% 10 1,0% 0,0% 0,0% 0,0% 0,0% 0,0% 0 6,000 to 7,000 5,000 to 6,000 7,000 to 8,000 8,000 to 9,000 9,000 to 10,000 10,000 to 11,000 11,000 to 12,000 12,000 to 13,000 13,000 to 14,000 14,000 to 15,000 15,000 to 16,000 Outage Level (MW) 39 Eskom Data Portal (1/2) • The Eskom Data Portal was launched publically on Eskom website on 4 September 2020. • The portal was developed in-house using only Eskom resources. • Hourly data, 24 hours after the fact, is available. • The data published includes: – Lockdown tracker – Weekly energy and peak demand – Demand forecasts – Station build up (different technologies dispatched to meet the demand) – Pumped storage & OCGT usage – Renewable output and statistics – Generation performance data (EAF, PCLF, UCLF, OCLF) – Emission data • On 14 October 2020 a facility was introduced that allows downloads of raw data for the past financial year and this current financial year-to-date as well as downloads of the data used for the graphs on the portal. • The next phase of the project will allow download of five year’s worth of raw data. 40 Eskom Data Portal (2/2) Weekly EAF, PCLF, UCLF, OCLF Hourly unplanned unavailability Weekly minimum, maximum and average 14 day rolling histogram of unplanned unplanned unavailability unavailability 41 Contents 1 Performance Review to September 2020 – COO 2 Progress with existing 9-Point Recovery Plan – GE: Gen 3 System Outlook: September 2020 – March 2021 – GE: Trans 4 Conclusion 42 Conclusion • Eskom is committed to recovering its operational performance and will not Summary of Eskom system performance compromise on reliability maintenance and mid-life refurbishment • This is in order to ensure South Africa has a reliable and sustainable generation plant fleet going forward • There will be heightened focus on sustained transmission and distribution network performance in order to manage other potential threats to the reliability of electricity supply • Eskom commits to keeping South Africa informed early in the event that loadshedding is necessary – a detailed schedule is being developed and will be synchronised with the national calendar • We appeal to customers to continue to use electricity sparingly to avoid or limit the probability of loadshedding 43 Thank you