Ensuring a secure, reliable and efficient Power System in a Changing - PowerPoint PPT Presentation

Ensuring a secure, reliable and efficient Power System in a Changing Environment Delivering a Secure Sustainable Power System 17 th August 2011

Outline Agenda Chair: Dick Lewis, Manager, Grid Operations Planning 10.00 a.m. Registration (Tea and Coffee) 10.30 a.m. Introduction and welcome Fintan Slye, Director Operations Overview of previous studies – Context 10.40 a.m. Jon O’Sullivan, Manager, Sustainable Power Systems Report on “Ensuring a Secure , Reliable and Efficient Power System” 11.00 a.m. Shane Rourke, Sustainable Power Systems 11.40 a.m. Programme & Advisory Council Yvonne Coughlan, Sustainable Power Systems 12.00 a.m. Questions from Audience 12.20 a.m. Closing comments followed by Lunch

European NREAP 2020 Wind Figures

Delivering a Secure Sustainable System All Island Grid Studies • Infrastructure Requirements All Island Grid Studies and Resource Assessment Facilitation of • Power System Operational Renewables Needs Studies Sustainable • Ensuring the needs of the Systems Report Power Systems future power system Report

Ireland and Northern Ireland Wind Statisitcs Northern Ireland Ireland Wind Capacity Factor Installed 1425 MW 314 MW 34% Maximum 32% 1259 MW 314 MW Output 30% Highest Instantaneous 52.3 % 50 % 28% % 26% Highest Daily 37% 29% 24% Energy 22% Annual Output 10% 7.2% % 2010 20% 2002 2003 2004 2005 2006 2007 2008 2009 2010 Capacity Factor

Operational Boundaries W0 W25 W50 W75 W100 WMAX SMAX WMIN SMIN

Operational Boundaries W0 W25 W50 W75 W100 WMAX SMAX WMIN SMIN

Key findings Loss of RoCoF capability and Frequency Stability largest infeed Fundamental issues protection Frequency Stability Short term Temporary loss of Conventional Generator frequency wind power due variations to network faults Reserve performance Fundamental issues that need further analysis Windfarms controllability and Power balance Voltage Stability Transient Stability fluctuations reactive power capability and frequency Voltage Control Network Loading regulation Issues that can be mitigated New operating procedures Small Signal including embedded windfarms Fault Levels Stability Non-issues according to modelling

Impact on Renewable Targets and Individual Wind Curtailment - 6000 MW Installed % Annual Energy from Wind % Individual Wind Curtailment 25 50 20 46 15 % % 42 10 38 5 34 0 60% 70% 80% 90% No Limit 60% 70% 80% 90% No Limit Wind+Import/ Demand+Export Wind+Import/ Demand+Export 0MW Exports 610MW Export 1000MW Export 0MW Exports 610MW Export 1000MW Export

Follow Up Analysis – System Services

Methodology Analysis builds on the results of the FoR – Using out-turn data and observed behaviour Three type of analysis carried out – Portfolio capability (theoretical maximum) – Actual availability (dispatch dependent) – Performance analysis Two timeframes considered: – Current: 2010 – Future: 2020

Portfolio evolution 2010 portfolio – 2011 GCS 2020 portfolio – credible evolution of current portfolio – Complementary to renewables targets – Sufficient investment to ensure capacity adequacy Technology Net capacity change (MW) Wind + 4400 Interconnection + 500 CCGT + 700 OCGT + 800 Conventional thermal - 2000

Portfolio evolution Portfolio breakdown - by generation type 16,000 14,000 6,113 12,000 46% Installed Capacity (MW) 1,731 19% 10,000 450 1,000 Wind 8,000 Interconnection Conventional 6,000 9,044 8,325 4,000 2,000 - 2010 2020

Areas of analysis • Synchronous Inertia Frequency Response • Operating Reserve • Reactive Power Capability Voltage Control • Dynamic Reactive Power • Generator Ramping Ramping Services • Wind Variability & Forecasting

Areas of analysis • Synchronous Inertia Frequency Response • Operating Reserve • Reactive Power Capability Voltage Control • Dynamic Reactive Power • Generator Ramping Ramping Services • Wind Variability & Forecasting

Example of Incident Generator Trip Normal Operating Period Recovery Period 50.2 50.1 50.0 50.0 Frequency (Hz) 49.9 49.8 49.7 Reserve 49.6 49.5 49.4 49.3 49.2 0 1 2 3 4 5 6 7 8 9 10 Time (mins)

Frequency Response: Inertia (daily range) Daily Synchronous Inertia range (2010) 60,000 50,000 40,000 Synchronous Inertia (MWs) 30,000 20,000 10,000 0 01-Jan-10 01-Feb-10 01-Mar-10 01-Apr-10 01-May-10 01-Jun-10 01-Jul-10 01-Aug-10 01-Sep-10 01-Oct-10 01-Nov-10 01-Dec-10 Max Daily Inertia Min Daily Inertia

Frequency Response: Inertia Inertia Duration Curves 60,000 Inertia 2010 50,000 Synchronous Inertia (MW s) 40,000 30,000 20,000 10,000 0 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Percentage of hours in the year

Frequency Response: Inertia Inertia Duration Curves 60,000 Inertia 2010 Inertia 2020 50,000 Synchronous Inertia (MW s) 40,000 30,000 20,000 Insecure region 10,000 0 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Percentage of hours in the year

Example of Incident Generator Trip Normal Operating Period Recovery Period 50.2 50.1 50.0 50.0 Frequency (Hz) 49.9 49.8 49.7 Reserve 49.6 49.5 49.4 49.3 49.2 0 1 2 3 4 5 6 7 8 9 10 Time (mins) Inertia

Frequency Response: Operating Reserve Automatic generator response to frequency deviation – Timescales: Primary, Secondary, Tertiary … – Primary the most onerous Grid Code requirement (Primary): at least 5% Reg Cap Portfolio has 8% capability overall – Some generators with >> 5% – Other generators with < 5%

Operating Reserve – Capability Number of generators: contracted POR vs GC required POR 19 27% 25 36% Zero POR POR < 5% POR = 5% POR > 5% 5 7% 21 30%

Operating Reserve – Capability (Ireland only) Primary Operating Reserve capability (by date of commissioning) - Ireland 35.00% 30.00% Primary Opearting Reserve (% Registered Capacity) 25.00% 20.00% 15.00% 10.00% 5.00% 0.00% * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * 1970s 1980s 1990s 2000s 2010s

Operating Reserve – Performance Performance improvements observed since the introduction of HAS Preliminary analysis of 2010 low frequency disturbances – Generators in Ireland classified based on Primary Operating Reserve performance vs declared capability Achieved 80% response No of generators Good: > 80% events 7 Note: Average: > 40%, < 80% events 10 Ireland only Poor: < 40% events 11 Unknown / limited data 23

Areas of analysis Key Findings • Synchronous Inertia Frequency Response • Operating Reserve Reduced Synchronous Inertia Reserve capabilities • Reactive Power Capability less than Grid Code Voltage Control • Dynamic Reactive Power Poor Generator Reserve Performance • Generator Ramping Ramping Services • Wind Variability & Forecasting

Areas of analysis • Synchronous Inertia Frequency Response • Operating Reserve • Reactive Power Capability Voltage Control • Dynamic Reactive Power • Generator Ramping Ramping Services • Wind Variability & Forecasting

Areas of analysis • Synchronous Inertia Frequency Response • Operating Reserve • Reactive Power Capability Voltage Control • Dynamic Reactive Power • Generator Ramping Ramping Services • Wind Variability & Forecasting

Voltage Control – Reactive Power Source NGT UK

Reactive Power – Portfolio Capability Synchronous Reactive Power 7,000 6,000 "Required" Contracted 5,000 4,000 3,000 2,000 1,000 0 Lagging Leading

Reactive Power Availability – Synchronised Reactive Power Duration Curves (Lagging) 6,000 2010 outturn 5,000 2020 base case Reactive Power Capability (Mvar) 4,000 3,000 2,000 1,000 0 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Percentage of hours in the year

Reactive Power Availability Reactive Power Duration Curves (Lagging) 6,000 2010 outturn 2020 base case 5,000 2020 with wind contribution Reactive Power Capability (Mvar) 4,000 3,000 2,000 1,000 0 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% Percentage of hours in the year

Reactive Power Available – 2010 vs 2020 Table shows average Mvar availability (i.e. from on-line generation) in 2010 and 2020 (with percentage increase/decrease) Lagging Mvar Leading Mvar 2010 3510 1570 2020 (conventional) 2650 (-24%) 1310 (-16%) 2020 (Tx wind) 3240 (-8%) 2000 (+21%) 2020 (all wind) 3830 (+9%) 2480 (+58%)

Reactive Power – Windfarm Control Wind Generation (MW) with voltage control from Control Centres 302 Yes Yes - derogation 168 No Not required 947 Not required (DSO) 274 40

Areas of analysis Key Findings • Synchronous Inertia Frequency Response • Operating Reserve Portfolio shortfall for leading RP (30%) Synchronous RP will • Reactive Power Capability reduce (25%) Voltage Control • Dynamic Reactive Power Only ¼ of windfarms provide RP control • Generator Ramping Ramping Dynamic RP is Services • Wind Variability & Forecasting critical for stability