Methodologies and Technical Decisions

For the effective implementation of the Balancing Market, the Balancing Market Rulebook is supplemented by methodologies decided by the Regulatory Authority for Energy (RAE), following a proposal by IPTO.

Methodology of Determination of the zonal and systemic Balancing Capacity needs for (a) Frequency Containment Reserve, (b) automatic Frequency Restoration Reserve and (c) manual Frequency Restoration Reserve. The Methodology is available in Greek.

The Baseline Calculation Methodology is used for the Settlement of the Dispatchable Load Portfolio and the Dispatchable Intermittent RES Units Portfolios. The methodology is available in English. 

No VERSION RAE's DECISION  GG Β' TRACK CHANGES
1 Demand Response Baseline_v1 798/2020 1924/19.05.2020  
2 Baseline Calculation Methodology_v3 480/2022 2810/06.06.2022 Baseline Calculation Methodology_v3-v1

Methodology for the calculation of Activated Balancing Energy and Adjusted Dispatch Instruction. The Methodology is available in Greek. 

Methodology for the calculation of Variable Cost Parameters for Thermal Production Units based on Techno-Economic data. The Methodology is available in Greek. 

Methodology for estimating the HETS Losses. The Methodology is available in Greek.

The Terms and Conditions of Balancing Services Providers according to Article 18 of Commission Regulation (EU) 2017/2195. Detailed description of Balancing Services Provider pre-selection procedures. The methodology is available in English.

No VERSIONS RAE's DECISION GG Β' TRACK CHANGES
1 Terms & Conditions BSPs_v1 1033/2020 3493/24.08.2020  
2 Terms & Conditions BSPs_v2 481/2022 3668/13.07.2022 Terms & Conditions BSPs_v2-v1

The Terms and Conditions for Balance Responsible Parties are issued in accordance with the Balancing Market Rulebook, as well as article 18 of Commission Regulation (EU) 2017/2195 and shall apply on Balance Responsible Parties within the control area of the HETS Operator. The methodology is available in English.

No VERSIONS RAE's DECISION GG Β' TRACK CHANGES
1 Terms & Conditions BRPs_v1 1032/2020 3558/28.08.2020  
2 Terms & conditions BRPS_v2 488/2022 3823/21.07.2022 Terms & conditions BRPS_v2-v1

The Methodology "Rules for suspension and restoration of market activities" includes the rules for suspension and the restoration of market activities in accordance with Article 36 of Commission Regulation (EU) 2017/2196. The Methodology is available in Greek.

This methodology "Rules for the settlement in case of market activities" sets the rules for the settlement in the event of suspension of the market activities in accordance with Article 39 of Commission Regulation (EU) 2017/2196. The methodology is available in English.

No VERSION RAE's DECISION GG Β'
1 Settlement in market Suspension_v1 1008/2020 3227/04.08.2020

The Day-Ahead and the Intra-Day Markets do not take into account the technical constraints of the Balancing Service Entities, whereas the Balancing Market (both the Integrated Scheduling Process and the real time Balancing Energy Market) does so. In case the Market Schedule (DAM and IDM schedule) of any Balancing Service Entity violates its technical constraints, this specific Market Schedule is infeasible, as the ISP Schedule and the Balancing Market Schedule will necessarily differ from the Market Schedule. In such cases, the difference in relation to the Market Schedule will not be considered as Balancing Energy, but as an Imbalance.

The Infeasible Market Schedule Calculation Methodology determines the Dispatch Periods during which, due to a Market Schedule being infeasible, the difference between the energy injected / offtaken by the Balancing Service Entities and the corresponding Market Schedule is considered as Imbalance. The Methodology is available in Greek.

No VERSION RAE's DECISION GG B' TRACK CHANGES
1 Μη εφικτό ΠΑ_v1 1363/2020 4596/19.10.2020  
2 Μη εφικτό ΠΑ_v2 1458/2020 4800/31.10.2020 Μη εφικτό ΠΑ_v2-v1

For the operation of the electricity market, the HETS Operator additionally applies the following methodologies.

Pursuant to RAE's Decision no. 14/2014 (Government Gazette Β 270/07.02.2014) for the calculation of the cost of providing Public Utility Services at the Non-Interconnected Islands, the Weighted Average Market Price is calculated according to RAE's Letter no. Ο-85181/02.12.2020 and RAE's Letter no O-92976/22.02.2022, for each month as the sum of the cost  (€) of the following transactions corresponding to the Load Representatives for the domestic consumption (excluding exports), divided by the total measured quantity of energy consumption (MWh), which corresponds to the consumption in the Interconnected System:

  1. Transactions of the Day Ahead Market.
  2. Transactions of the Intra Day Market,
  3. Imbalance Settlement of the Balancing Market,
  4. Settlement of the Uplift accounts, in accordance with the Balancing Market Rulebook (UA-1, UA-2, UA-3),
  5. Charges of the Load Representatives regarding the Transitory Flexibility Remuneration Mechanism, in accordance with the HETS Code or any charges related to capacity mechanisms in force.  
  6. Any other charge arising from a market mechanism provided in the current legislation to be imposed exclusively on Load Representatives of the Interconnected System. 

The Weighted Average Market Price is published each month under the section Reports at IPTO's website.

For the effective implementation of the Balancing Market, IPTO issues the following Technical Decisions, which regulate details in technical issues with non-regulatory content. The Technical Decisions are issued following a public consultation and are posted on the website of IPTO. In the event of any contradiction between the provisions of the Balancing Market Rulebook and the corresponding Technical Decisions, the provisions of the Rulebook shall prevail.

The Technical Decision "Procedures of registration with the HETS Operator Registry" provides detailed description of application, submission and registration procedures in the HTS Operator Registries. The procedures are analytically presented in section Registration Procedures.  

The Technical Decision is available in English. 

 

No VERSIONS TRACK CHANGES
1 Technical Decision Procedures of Registration_v1  
2 Technical Decision Procedures of Registration_v2 Technical Decision Procedures of Registration_v2-v1
3 Technical Decision Procedures of Registration_v3 Technical Decision Procedures of Registration_v3-v2

 

The Technical Decision "Dispatch Instructions" includes all relevant procedures for issuing and sending Dispatch Instructions. The Technical Decision is available in Greek.

The Technical Decision "Manual FRR" includes details on the implementation of the manual FRR (mFRR) process. The Technical Decision is available in Greek. Additional information is included on a Technical Manual, also available in Greek.

The Technical Decision "Automatic FRR" includes details on the implementation of the automatic FRR (aFRR) process. The Technical Decision is available in Greek. Additional information is included on a Technical Manual, also available in Greek.

The Technical Decision "Balancing Market Settlement" includes details and examples of calculations regarding the clearing of the Balancing Energy Market, the Balancing Capacity Market and the Imbalances. The Technical Decision is available in Greek.

The Technical Decision 'Integrated Scheduling Process' includes details on the implementation of the Integrated Scheduling Process (ISP). The ISP is a process carried out by TSOs that use Central Dispatch Systems. The process aims at covering the forecasted generation/demand imbalances and procuring the required reserves. Consequently, the ISP results involve:

  • procurement of the Balancing Capacity needed to cover the forecasted reserves requirement for FCR and FRR (aFRR and mFRR),
  • scheduling of the commitment of BSEs in a way that meets the constraints of the HETS and the BSEs, and
  • procurement of Balancing Energy needed to cover the forecasted generation/demand imbalances and provision for an indicative production schedule of the BSEs.

The ISP is solved as a co-optimization problem taking into account the Balancing Energy and Balancing Capacity Offers of the BSEs as well as their respective constraints, the HETS constraints and the HETS Operator needs, in order to minimize the cost of Balancing Energy and Balancing Capacity procurement

 

No VERSIONS TRACK CHANGES
1 Technical Decision ISP_v2  
2 Technical Decision ΙSP_v3 Technical Decision ΙSP_v3-v2

The Technical Decision "Technical limits on bidding and clearing prices" defines the numerical values of the Minimum and Maximum Prices of Balancing Capacity and Balancing Energy Offers, which are imposed for technical reasons. The Technical Decision is available in English.

No VERSIONS TRACK CHANGES
1 Technical limits on bidding and clearing prices_v1  
2 Technical limits on bidding and clearing prices_v2 Technical limits on bidding and clearing prices_v2-v1

 

Α. Technical Limits for bidding prices and clearing prices for Balancing Energy

Timeframe

Balancing Energy

€/MWh

minimum

maximum

1st Period

-4.240

+4.240

2nd Period

-9.999

+9,999

3rd Period:

-15.000

+15.000

4th Period

-99.999

+99.999

1st Period:           From the launch of the new markets until the introduction of Complementary Regional Intraday Auctions (CRIDAs).

2nd Period:          From the implementation of Complementary Regional Intraday Auctions (CRIDAs) until inclusion of the IPTO in one of the European platforms, MARI or PICASSO.

3rd Period:           From the date of the integration of the IPTO in one of the European platforms (MARI or PICASSO) and up to a maximum of 48 months from the deadline for the implementation of the European MARI and PICASSO platforms, as defined in Articles 20 and 21 of the EBGL.

4th Period:           48 months after the deadline for the implementation of the European MARI and PICASSO platforms.

 

Β. Technical Limits for bidding prices and clearing prices for Balancing Capacity

Timeframe

Balancing Capacity

€/MW - hour

minimum

maximum

1st Period

0

+3,000

2nd Period

0

+9,999

1st Period:           From the launch of the new Markets until the implementation of Continuous Intra-Day Trading (XBID).

2nd Period:          From the implementation of Continuous Intra-Day Trading (XBID) onwards.

The Technical Decision Procedure and Prequalification Tests of Balancing Service Providers describes the process of all necessary Prequalification Tests Balancing Service providers and Entities should undertake for their participation in the Balancing Market.

 

For the effective implementation of the Balancing Market, the Balancing Market Rulebook is supplemented by special approvals and parameters provided for in this Rulebook, which are approved by the Regulatory Authority for Energy (RAE) following a proposal by IPTO.

Interested parties that wish to register in the HETS Operator Registry shall submit a registration fee, as described in section Registration Procedures. The Registration fee is determined by decision of RAE.

Registration Fee in HETS Operator Registry
One-off charge for Balancing Service Providers or/and Balance Responsible Parties: 2.000€
One-off charge for Balancing Market Generating Units: 2.500€
*The registration fee is paid only once, in case the interested party bears both the attribute of a Balancing Service Provider and Balance Responsible Party.

For the calculation of the Instructed Energy, a tolerance limit is set per category of Balancing Service Entity at 2%. The Decision of RAE is available in Greek.

The Balancing Energy Deficit Premium price in €/MWh is determined by RAE, following a proposal by IPTO. RAE's Decision No 1226/2020 (GG Β' 4033/21.09.2020) is available in Greek.

If during an Imbalance Settlement Period energy from Contracted Units or Supplementary Energy from Emergency Imports was injected, or Load Cuts were performed, the upward Balancing Energy Price for manual FRR may be increased at least up to the level of   2.100 /MWh for the specific Imbalance Settlement Period. In the event that the upward Balancing Energy Price for manual FRR receives a value greater than € 2,100 / MWh, then the value of the Balancing Energy Deficit Premium price is zero (0).

RAE's Decision 476/2022 (GG Β' 3124/20.06.2022) determines the numerical values of the parameters for non-Compliance Charges regarding the Consequences of non-timely commitment according to article 96 of the Balancing Market Rulebook.

PARAMETER

NUMERICAL VALUE

UNCBS

0,4 €/MW

kNP

1,5

kBC

1,1

TOLcommit

3%

 

RAE's Decision 495/2022 determines the numerical values of the parameters for non-Compliance Charges regarding the Consequences of significant deviation from the Registered Characteristics according to article 97 of the Balancing Market Rulebook.

PARAMETER

NUMERICAL VALUE

UNCDCe,char

6 €/MW

DCTOL for the Maximum Available Capacity

3%

DCTOL for the Technically Minimum Generation

6%

ADC 

  N/xwhere N is the total number of Dispatch Days during the current month, which significant unfavorable deviation from the Registered Characteristics is observed

x

2

NDC

0

 

RAE's Decision 477/2022 (GG Β' 3173/22.06.2022) determines the numerical values of the parameters for non-Compliance Charges regarding the Consequences of non-compliance with manual FRR Test Instructions according to article 98 of the Balancing Market Rulebook.

PARAMETER

TECHNOLOGY

NUMERICAL VALUE

UNCTDINST

 

(Mean compensation value of the entity for the mFRR Balancing Capacity for the relevant direction, for the previous 30 days, in €/MW) 

x

(Number of Dispatch Periods during which the entity has been awarded mFRR Balancing Capacity for the relevant direction, for the previous 30 days)

TOLUDTDINST

 

3%

TOLΟDTDINST

Dispatchable Generation Units

3%

TOLΟDTDINST 

Dispatchable RES Unit Portfolios and Dispatchable Load Portfolios

50%

ATDI

 

N2semester

BTDI

 

1

 

RAE'S Decision 478/2022 (GG Β' 3127/20.06.2022) determines the numerical values of the parameters for non-Compliance Charges for significant deviation from Dispatch Instructions according to article 99 of Balancing Market Rulebook.

PARAMETER

TECHNOLOGY

NUMERICAL VALUE

UNCNPBE

 

3,5 €/MWh

ANPBE

 

1

TOLBE

Dispatchable Load Portfolios and Dispatchable Intermittent RES Units Portfolios which offer more Balancing Energy than the Dispatch Instruction

20%

TOLBE

Dispatchable Load Portfolios and Dispatchable Intermittent RES Units Portfolios which offer less Balancing Energy than the Dispatch Instruction

3%

TOLBE

Rest Entities

3%

 

RAE's decision 479/2022 (GG Β' 3173/22.06.2022) determines the numerical values of the parameters for non-Compliance Charges for significant systematic demand imbalances according to article 100 of the Balancing Market Rulebook.

PARAMETER

NUMERICAL VALUE

UNCBALADEV

54 €/MWh

UNCBALRMSDEV

360 €/MWh

TOLld,ADEV=

min{max[3,3%, α * + c], 10%}

α = 0,5

b = -0,075

c = -0,3

TOLld,RMSEV=

min{max[3,3%, α * + c], 12%}

α = 0,52

b = -0,08

c = -0,3

 

RAE's Decision 496/2022 determines the numerical values of the parameters for non-Compliance Charges for significant systematic imbalances in the production of RES Units Portfolios according to article 101 of the Balancing Market Rulebook.

PARAMETER

NUMERICAL VALUE

UNCBALRADEV

10 €/MWh

Logo

Description automatically generated with medium confidence

maxTOLADEV = 100%

minTOLADEV = 20%

α1ADEV = 0,35

α2ADEV = -0,009

α3ADEV = 0,28

UNCBALRRMSDEV

210 €/MWh

Logo

Description automatically generated with medium confidence]

maxTOLRMSDEV = 100%

minTOLRMSDEV = 20%

α1RMSDEV = 0,4

α2RMSDEV = -0,009

α3RMSDEV = 0,28

 

RAE's Decision 497/2022 determines the numerical values of the parameters for non-Compliance Charges for systematic failure to attain a feasible Market Schedule according to article 102 of the Balancing Market Rulebook.

PARAMETER

NUMERICAL VALUE

UNCNAMSr

0 €/MWh

ANAMS

0

TOLr,e

0%

 

RAE's Decision No 1328/2020 determines the numerical values of non-Compliance Charges for non-submission or unlawful submission of Balancing Energy and Capacity Offers  according to articles 96 and 98 of the Balancing Market Rulebook.

DESCRIPTION

PARAMETER

NUMERICAL VALUE

Unitary non-Compliance Charge for non-submission or unlawful submission of Balancing Energy Offers

UNCBEO

0 €/MWh

Unitary non-Compliance Charge for non-submission or unlawful submission of Balancing Capacity Offers

UNCBRO

0 €/MWh

 

RAE's Decision No 1359/2020 determines the numerical values of non-Compliance Charges for significant unfavorable deviation from the Registered Characteristics of a Balancing Service Entity according to article 97 of the Balancing Market Rulebook.

DESCRIPTION

PARAMETER

NUMERICAL VALUE

Unitary non-Compliance Charge

UNCDCe,char

6 €/MW

Tolerance margin for Maximum Available Capacity

DCTOL

3%

Tolerance margin for Technically Minimum Generation

DCTOL

6%

 

RAE's Decision No 1360/2020 determines the numerical values of non-Compliance Charges for significant deviation from Dispatch Instructions according to article 99 of Balancing Market Rulebook.

DESCRIPTION

PARAMETER

NUMERICAL VALUE

Unitary non-Compliance Charge

UNCNPBE

2 €/MWh

Margin of tolerance

TOLBE

3%

 

RAE's Decision No 1361/2020 determines the numerical values of non-Compliance Charges for significant systematic demand imbalances according to article 100 of the Balancing Market Rulebook.

DESCRIPTION

PARAMETER

NUMERICAL VALUE

Unitary charge for the monthly normalized absolute deviation

UNCBALADEV

40 €/MWh

Tolerance margin for the monthly normalized absolute deviation

TOLADEV

3,3%

Unitary charge for the monthly normalized active value of deviations

UNCBALRMSDEV

160 €/MWh

Tolerance margin for the monthly normalized active value of deviations

TOLRMSDEV

3,3%

 

RAE's Decision No 1362/2020 determines the numerical values of non-Compliance Charges for significant systematic imbalances in the production of RES Units Portfolios according to article 101 of the Balancing Market Rulebook.

DESCRIPTION

PARAMETER

NUMERICAL VALUE

Unitary charge for the monthly normalized absolute deviation

UNCBALRADEV

10 €/MWh

Tolerance margin for the monthly normalized absolute deviation

TOLADEV

20%

Unitary charge for the monthly normalized active value of deviations

UNCBALRRMSDEV

210 €/MWh

Tolerance margin for the monthly normalized active value of deviations

TOLRMSDEV

20%

 

RAE's Decision No 1363/2020 determines the numerical values of non-Compliance Charges for systematic failure to attain a feasible Market Schedule according to article 102 of the Balancing Market Rulebook.

DESCRIPTION

PARAMETER

NUMERICAL VALUE

Unitary non-Compliance Charge

UNCNAMSr

0 €/MWh

Tolerance margin for the quantity of the infringement

TOLr,e

0%

 

The Safety Maximum Reservoir Level is the the maximum level per reservoir, above which the Dispatchable Hydro Generating Units connected to the Reservoir may submit mandatory hydro injection declarations to avoid overflow.

The Safety Minimum Reservoir Level is the minimum level per reservoir, above which the Dispatchable Hydro Generating Units connected to the Reservoir may submit declarations of maximum daily energy injection constraint. 

The height of the Safety Maximum Reservoir Level and the Safety Minimum Reservoir Level are determined for each Dispatchable hydro Generating Unit by RAE's Decision 1392/2020 (GG Β' 4703/23.10.2020).

The expenditure related to the obligations of the HETS Operator in accordance with the Balancing Market Rulebook, which are considered reasonable, efficient and proportionate, as well as their rate of return, shall be recovered by the Operator through a Balancing Market Fee payable by every Balancing Service Provider and Balance Responsible Party. 

The Balancing Market Fee consists of two components, the Imbalance Component and the Energy component, into which the Required Revenue is distributed as follows: 
a) 20% of the Required Revenues corresponds to the Imbalance Component, and
b) 80% of the Required Revenues corresponds to the Energy Component.

The unitary charges of the above-mentioned components are determined every year, upon proposal by the HETS Operator and approval by RAE. 

 

The approved unitary charges of the Balancing MArket Fee Components are presented in the table below.

 

Year of application Unitary Charge for Imbalance Component (UNBMFIMB) Unitary Charge for Energy Component (UNBMFEN) NRA's Decision Government Gazette
2022 0,20152     (€/MWh) 0,09471      (€/MWh) 1059/2021  Β'/6444.31.12.2021