Energy Management and Planning in Greek Non Interconnected Islands

Transcription

1 Energy Management and Planning in Greek Non Interconnected Islands Andreas Vlachos Director, Long-term Energy Planning, RAE

2 Framework overview 2

3 Framework Overview Laws 3468/2006 (Provisions for Renewables), 4001/2011 (General provisions), 4414/2016 Ministerial Decisions Regulations for licensing Template RES PPAs per technology Regulatory Decisions Licensing (conventional and RES) Non Interconnected Islands (NII) Code Regulatory Decisions Code Manuals Methodologies 3

4 NII Market structure Units Conventional Generation Market Operator Producers RES Generation System Operator NII Operator Load Represent atives Customers 4

5 Management in autonomous NII systems Infrastructure, supervision and monitoring of electricity generation and electricity market Technical rules and procedures for the management, the operation and the development of electrical systems of NII Special provisions for RES NII management Code Costs of operation, settlements and trade between producers, suppliers and NII Operator Third party access and technical specifications of connection and participation in the market 5

6 NII management supervision Records Dispatching and Scheduling procedures NII market clearing and settlements Production data for RES/HECHP and HPS Registries Producers Stations - Units Load Representatives Contract for participation Producer participation (energy, capacity and ancillary services) Load Representative Guarantees Load Representative Metering Management Data Publication and Transparency NII IT system Supports all market and management procedures Data collection and communication with market participants Databases of all relevant information Auxiliary tools for system operation, analysis and monitoring Specification requirements and certification procedures Energy Control Centers Central in Athens & Local in Islands Organization and Interoperability Infrastructure and operational requirements 6

7 Scheduling and daily management 7

8 Classification of production units A1. Dispatchable units Fully controllable units (compulsory) Conventional thermal generation A2. Dispatchable RES units Fully controllable units with daily energy offer (compulsory) e.g. Hybrid Power stations B. Partially Dispatchable RES Units Partial controllable RES units with hourly schedules (compulsory) e.g. Solar thermal C. Non dispatchable Curtailed units RES units under curtailment e.g. wind, PV Hourly scheduling offers (optional) D. Non dispatchable Non curtailed units Small size RES (< 20 to 50 kw, depending on system s size) 8

9 Daily generation scheduling and dispatch (1) Central generation management processes: Rolling Day Ahead Scheduling (DAS) Dispatch Scheduling (DS) Real Time Economic Dispatch (RT-ED) Addresses: Conventional Thermal units RES and storage: Non-dispatchable, intermittent RES (Wind, PV) Dispatchable RES (HPS, solar thermal, small hydro, biomass) Dispatchable and controllable units operate under dispatch orders Balance responsible entities subject to uninstructed deviation penalties Non-dispatchable, intermittent sources are subject to curtailments If declaring an hourly schedule balance then responsible for the schedule 9

10 Daily generation scheduling and dispatch (2) D-1 D Real Time Unit Commitment Preliminary Production Schedule All 24h of Day D In two stages (intraday update) Updated unit Commitment and production Schedule Every 20 min 4 hours look ahead Dispatch orders Economic Dispatch Every 5 min Dispatch Orders RTD Deviations check DS DAS DAS - Update Participants declarations Operator Forecasts RES energy and hourly schedules updated declarations Operator forecasts units availability system conditions other information 10

11 Daily generation scheduling and dispatch (2) Objectives of RDAS, DS and RTD Maximize RES penetration Minimize operating costs of conventional units Safeguard security of operation (reserve requirements) Fundamental Constraints Energy balance (meet load demand) Security of operation (active power reserve requirements) Technical constraints of dispatchable units (min./ max., ramp rates, on/off times) Rules related to market participation and priority dispatching of RES on the day- ahead and intraday scheduling (declarations, curtailments ) Main results Hourly commitment and production schedule of conventional units Hourly production schedule of disp. RES & HECHP ( of daily energy or hourly declarations) Production profile of non-disp. RES/HECHP units Hourly absorption schedule of HPS and other stations 11

12 Penetration of RES/ HECHP & hybrid stations Dispatching priority rules Special rules for the integration and operation of RES/HECHP & HPS (excluding small power stations 20 to 50 kw, depending on system s size): Priority in energy absorption by the NII Operator, by the following order: RES & controllable units of HSP HEHCP Thermal units *Priority does not apply for must run thermal units, for security of operation Retain reserves for ensuring a minimum level of penetration of non - dispatchable RES units (reserves coefficient equal to 35% or 30% of demand) Specific rules in DAS settlement, in case of necessary power-cuts and unit shut-down: Equal treatment of all RES/HECHP (proportional curtailment) units differentiation per category for technical reasons Priority to RES providing reserves and controllable units of HPS shut-down of thermal units not necessary for the security of the NII system Determination of necessary reserves for non-dispatchable RES/HECHP units, by study conducted by NII Operator, based on technology, geographical dispersion, operating conditions etc. 12

13 Penetration of RES/ HECHP & hybrid stations: Particular issues and rules for HPS Controllable units of a HPS: Daily energy offer to DAS, which is allocated hourly by the NII Operator Priority over thermal units (excluding must run) Obligation for providing guaranteed energy/power Obligation for providing reserves The NII Operator may request part or all of the guaranteed energy. Guaranteed power of HSP Provided either by the controllable units or by joint operation of controllable and RES units (controllable units provide necessary reserves) RES units of HPS provide power in priority order for: 1: Storage, 2: Participation in the provision of guaranteed power 3: Direct injection to the grid (as long as there are no other RES curtailments) The planning of RES storage of the HPS is left to the Producer. Energy absorption from the Grid is possible: Upon request of NII Operator to deliver the guaranteed power and energy For absorption of third party RES (not of HPS) from the grid that would be curtailed ( subject to storage constraints) 13

14 Penetration of RES/ HECHP & hybrid stations: Operating policy of a HPS Daily energy scheduling Request for guaranteed power and energy from the NII Operator Typical dispatch of the HPS s daily energy offer at the peak of the daily load curve Typical energy absorption from grid in base load ensuring guaranteed energy at the peak Daily energy offer from HPS according to available energy and the request of NII Operator Load declaration from HPS, if required for ensuring guaranteed energy HPS s production scheduling Hourly absorption scheduling from grid, if demand has been declared Hourly dispatch of controllable units to cover energy balance 14

15 Management & control PRODUCERS SUPPLIERS Central Energy Control Center (ECC) Load/RES/reserves forecast Operations DAS/DS Registries Data collection Settlements & clearance system Power adequacy mechanism NII consumers telemetry center Local Energy Control Center (ECC) AGC Load- frequency regulation RT-ED HV grid supervision & control* Emergency situations Power stations & units Generation telemetry center HV grid SCADA* Generation SCADA *only for systems with HV grid 15

16 Generation development and Planning 16

17 NII systems short term planning: Emergencies Typical emergencies in NII systems Capacity inadequacy due to unexpected short term demand growth in peak periods Forced outages submarines cables interconnecting islands of the same NII system Forced outages of units NII Operator s counter measures Activation of demand response measures - interuptibility contracts Dispatching backup generation units Transfer of portable generation units from other NII systems, without endangering systems power adequacy Suggestion to RAE for licensing additional capacity NII Operator s preventive measures Brief report regarding the power adequacy for each NII system - Submission to RAE, 3 times a year (Jan. Apr. Sep.) Emergency Response Plan - Submission to RAE for approval - updated every 5 year The Code provides with all relevant procedures and time lines 17

18 NII systems Long term planning: Generation Development Plan Conducted by NII Operator annually, distinctly for each NII system, with a horizon of 3 to 5 years. Approval by RAE. Scope, the identification of: the necessary capacity of power units for installation the major grid development projects Objectives: The uninterrupted supply of electricity to consumers of NII systems The secure and reliable operation of every system by ensuring a minimum level of power adequacy The minimization of total production cost of conventional units (fixed & variable) The maximization of RES penetration (including HECHP & HPS) - Country s targets in the context of European and national commitments The elimination of environmental impacts Principles The balance of demand plus required reserves ( largest single contingency - largest unit, interconnection) from dispatchable units Determination of type and characteristics of new power (for participation in capacity mechanism) 18

19 NII systems long term planning: Capacity mechanism Scope Recovery of capital cost of the necessary capacity investments in order to ensure power adequacy in each NII system Mechanism participants Conventional units Dispatchable units of HPS with guaranteed power Determination of power to be remunerated Considering monthly and annual non-availability Considering type of units required according to the generation development plan Methodology for cost allocation to the load representatives Allocation coefficients, based on power consumption proportionally to the peak system load 19

20 NII systems long term planning: RES penetration Studies conducted by the NII Operator (submitted to RAE for approval), every 2 years RES/HECHP development in each NII system (penetration margins) Improvement of dispatching rules Studies main specifications Hourly simulation of NII system s operation Alternative scenarios of RES/HECHP generation mix and dispatching rules, considering: Demand evolution, technical features of units NII systems planning development or interconnections Available RES technologies, features and potential Actual data and gained experience Impacts between technologies The results of the studies are specified by RES/HECHP category Identification of the necessary infrastructures for the grid 20

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