ΑΠΟΦΑΣΗ ΤΟΥ ΚΛΑΔΟΥ ΕΝΕΡΓΕΙΑΣ ΥΠ’ ΑΡΙΘΜ. Ε-137/2023

(2019)5104525/16.07.2019 έγγραφο της DGEnergy προς τον ACER κα τον ENTSO-e με θέμα «Capacity Calculation and third countries». 9. Την υπ’ αριθ. 123/2021 απόφαση ΡΑΕ «Τροποποίηση της μεθοδολογίας συντονισμένου υπολογισμού της δυναμικότητας εντός της περιφέρειας υπολογισμού δυναμικότητας Νοτιοανατολικής Ευρώπης (SEE CCR), σύμφωνα με τα άρθρα 20 και 21 του Κανονισμού (ΕΕ) 2015/1222 της Επιτροπής, της 24ης Ιουλίου 2015, σχετικά με τον καθορισμό κατευθυντήριων γραμμών για την κατανομή της δυναμικότητας και τη διαχείριση της συμφόρησης.» (ΦΕΚ Β’ 1036/17.03.2021). 10. Το υπ’ αριθ. πρωτ. ΡΑΕ Ι-344478/26.01.2023 ηλεκτρονικό έγγραφο της ΑΔΜΗΕ Α.Ε. με θέμα «SEE CCM-proposal for amendment». 11. Το υπ’ αριθ. πρωτ. ΡΑΕ Ι-344498/26.01.2023 ηλεκτρονικό έγγραφο της ΑΔΜΗΕ Α.Ε. με θέμα «SEE CCM-proposal for amendment». 12. Το υπ’ αριθ. πρωτ. ΡΑΕ Ι-345466/10.02.2023 ηλεκτρονικό έγγραφο της ΑΔΜΗΕ Α.Ε. με την επίσημη μετάφραση της υπό σχετ. 10 πρότασης. 13. Τη Δημόσια Διαβούλευση της ΡΑΕ επί της ανωτέρω κοινής τροποποιημένης πρότασης των ΔΣΜ, η οποία έλαβε χώρα από 21.02.2023 έως και 14.03.20231 και επί της οποίας δεν υπεβλήθησαν σχόλια. 1 https://www.rae.gr/diavoulefseis/61886/ 2 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ 14. To γεγονός ότι βάσει των διατάξεων του Ν. 5037/2023 (ΦΕΚ Α’ 78/28.03.2023), η Ρυθμιστική Αρχή Ενέργειας μετονομάζεται σε Ρυθμιστική Αρχή Αποβλήτων, Ενέργειας και Υδάτων (ΡΑΑΕΥ) και όπου γίνεται αναφορά στην επωνυμία «Ρυθμιστική Αρχή Ενέργειας» ή «Ρ.Α.Ε.», νοείται η ΡΑΑΕΥ. 15. Την ηλεκτρονική αλληλογραφία (υπ’ αριθ. πρωτ. ΡΑAEY Ο-104638/05.09.2023) με την οποία επιβεβαιώνεται η ομόφωνη συμφωνία (unanimous agreement), μέσω ηλεκτρονικής ψηφοφορίας των Ρυθμιστικών Αρχών της SEE CCR περί της τροποποίησης της μεθοδολογίας συντονισμένου υπολογισμού της δυναμικότητας εντός της περιφέρειας υπολογισμού δυναμικότητας Νοτιοανατολικής Ευρώπης (SEE CCR), σύμφωνα με τα άρθρα 20 και 21 του Κανονισμού (ΕΕ) 2015/1222 της Επιτροπής, της 24ης Ιουλίου 2015, σχετικά με τον καθορισμό κατευθυντήριων γραμμών για την κατανομή της δυναμικότητας και τη διαχείριση της συμφόρησης. 16. Την υπ’ αριθ. πρωτ. ΡΑAEY Ο-104658/06.09.2023 επιστολή των Ρυθμιστικών Αρχών της SEE CCR προς τους ΔΣΜ της SEE CCR με κοινοποίηση στην Ευρωπαϊκή Επιτροπή και στον ACER, περί της τροποποίησης της μεθοδολογίας συντονισμένου υπολογισμού της δυναμικότητας εντός της SEE CCR. 17. Το γεγονός ότι σύμφωνα με τις διατάξεις της παρ. 1 του άρθρου 32 του ν. 4001/2011, οι πράξεις κανονιστικού χαρακτήρα που εκδίδονται από τη ΡΑΕ, δημοσιεύονται στην Εφημερίδα της Κυβερνήσεως. 18. Το γεγονός ότι από τις διατάξεις της παρούσας δεν προκαλείται δαπάνη σε βάρος του Κρατικού Προϋπολογισμού. Σκέφτηκε ως εξής: Επειδή, στο πλαίσιο επίτευξης της ενιαίας ευρωπαϊκής αγοράς ηλεκτρικής ενέργειας, εξεδόθη, κατ’ αρχήν, ο Κανονισμός (ΕΚ) υπ’ αριθ. 714/2009 του Ευρωπαϊκού Κοινοβουλίου και του Συμβουλίου της 13ης Ιουλίου 2009 σχετικά με τους όρους πρόσβασης στο δίκτυο για τις διασυνοριακές ανταλλαγές ηλεκτρικής ενέργειας και την κατάργηση του Κανονισμού (ΕΚ) αριθ. 1228/2003 (σχετ. 5). Επειδή, στο άρθρο 19 «Ρυθμιστικές Αρχές» του Κανονισμού (ΕΚ) 714/2009, ρητώς ορίζεται ότι: «Κατά την άσκηση των καθηκόντων τους, οι Ρυθμιστικές Αρχές εξασφαλίζουν τη συμμόρφωση προς τον παρόντα Κανονισμό και προς τις κατευθυντήριες γραμμές που θεσπίζονται σύμφωνα με το άρθρο 18. Εφόσον ενδείκνυται για την επίτευξη των σκοπών του παρόντος Κανονισμού, οι ρυθμιστικές αρχές συνεργάζονται μεταξύ τους καθώς και με την Επιτροπή και τον Οργανισμό σύμφωνα με το κεφάλαιο IX της οδηγίας 2009/72/ΕΚ.». Επειδή, στη συνέχεια, με εξουσιοδότηση που προβλέπεται στο άρθρο 18 του Κανονισμού (ΕΚ) 714/2009 και σύμφωνα με το άρθρο 290 ΣΛΕΕ, εξεδόθη από την 3 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ Επιτροπή ο υπ’ αριθ. 2015/1222 Κανονισμός (ΕΕ) της 24ης Ιουλίου 2015 (εφεξής «Κανονισμός» σχετ. 6), με τον οποίο καθορίζονται κατευθυντήριες γραμμές σχετικά με τη διαζωνική κατανομή της δυναμικότητας και τη διαχείριση της συμφόρησης στην αγορά της επόμενης ημέρας και στην ενδοημερήσια αγορά στα Κράτη Μέλη. Επειδή, στόχος του ανωτέρω Κανονισμού είναι, μεταξύ άλλων, ο συντονισμός και η εναρμόνιση του τρόπου υπολογισμού και της κατανομής της δυναμικότητας των διασυνδέσεων, προκειμένου να υλοποιηθεί η ενιαία σύζευξη της αγοράς ηλεκτρικής ενέργειας επόμενης ημέρας (day-ahead electricity market) και της ενιαίας ενδοημερήσιας αγοράς ηλεκτρικής ενέργειας (intraday electricity market). Επειδή, προκειμένου για την ικανοποίηση του ανωτέρω στόχου, οι Διαχειριστές Συστήματος Μεταφοράς (ΔΣΜ), τα καθήκοντα των οποίων περιγράφονται γενικά στο άρθρο 8 του Κανονισμού, δύναται να υποβάλουν στις εθνικές Ρυθμιστικές Αρχές κοινή πρόταση σχετικά με τη μεθοδολογία συντονισμένου υπολογισμού της δυναμικότητας εντός της οικείας περιφέρειας, σύμφωνα με το άρθρο 20 του Κανονισμού. Επειδή, σύμφωνα με το άρθρο 20 του Κανονισμού «Υιοθέτηση της μεθόδου υπολογισμού δυναμικότητας με βάση τη ροή» προβλέπονται τα εξής: «1. Όσον αφορά το χρονικό πλαίσιο αγοράς επόμενης ημέρας και το χρονικό πλαίσιο ενδοημερήσιας αγοράς, η προσέγγιση που χρησιμοποιείται για την κοινή μέθοδο υπολογισμού δυναμικότητας βασίζεται στη ροή, εκτός εάν πληρούνται η προϋπόθεση κατά την παράγραφο 7. 2. Εντός δέκα μηνών από την έγκριση της πρότασης για περιφέρεια υπολογισμού δυναμικότητας σύμφωνα με το άρθρο 15 παράγραφος 1, όλοι οι ΔΣΜ σε κάθε περιφέρεια υπολογισμού δυναμικότητας υποβάλλουν πρόταση σχετικά με κοινή μεθοδολογία συντονισμένου υπολογισμού της δυναμικότητας εντός της εκάστοτε περιφέρειας. Η πρόταση υπόκειται σε διαβούλευση σύμφωνα με το άρθρο 12. […] 4.Το αργότερο έξι μήνες αφότου τουλάχιστον όλα τα συμβαλλόμενα στην Ενεργειακή Κοινότητα μέρη από την Νοτιοανατολική Ευρώπη συμμετέχουν στην ενιαία σύζευξη επόμενης ημέρας, τουλάχιστον οι ΔΣΜ από την Κροατία, τη Ρουμανία, τη Βουλγαρία και την Ελλάδα υποβάλλουν από κοινού πρόταση σχετικά με την υιοθέτηση κοινής μεθοδολογίας υπολογισμού δυναμικότητας με βάση τη ροή για το χρονικό πλαίσιο αγοράς επόμενης ημέρας και το χρονικό πλαίσιο ενδοημερήσιας αγοράς. Στην πρόταση προβλέπεται ημερομηνία εφαρμογής της κοινής μεθοδολογίας υπολογισμού δυναμικότητας με βάση τη ροή, το αργότερο δύο έτη από τη συμμετοχή στην ενιαία σύζευξη επόμενης ημέρας όλων των συμβαλλόμενων στην Ενεργειακή Κοινότητα μερών από την Νοτιοανατολική Ευρώπη. Οι ΔΣΜ από τα κράτη μέλη που έχουν σύνορα με άλλες περιφέρειες ενθαρρύνονται να ενταχθούν οι πρωτοβουλίες για την εφαρμογή της κοινής μεθοδολογίας υπολογισμού δυναμικότητας με βάση τη ροή στις εν λόγω περιφέρειες. […] 4 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ 7. Οι ΔΣΜ επιτρέπεται να ζητήσουν από κοινού από τις αρμόδιες ρυθμιστικές αρχές να εφαρμόζουν την προσέγγιση με βάση τη συντονισμένη καθαρή δυναμικότητα μεταφοράς σε περιφέρειες και σύνορα ζώνης προσφοράς πλην εκείνων που αναφέρονται στις παραγράφους 2 έως 4, αν οι ενδιαφερόμενοι ΔΣΜ είναι σε θέση να αποδείξουν ότι, υπό την παραδοχή του ίδιου επιπέδου επιχειρησιακής ασφάλειας στη σχετική περιφέρεια, η εφαρμογή της κοινής μεθόδου υπολογισμού δυναμικότητας με βάση τη ροή δεν θα ήταν επί του παρόντος αποδοτικότερη από την προσέγγιση με βάση τη συντονισμένη καθαρή δυναμικότητα μεταφοράς. …» Επειδή, σύμφωνα με το άρθρο 21 του Κανονισμού «Μεθοδολογία υπολογισμού δυναμικότητας» προβλέπονται τα εξής: «1. Η πρόταση κοινής μεθόδου υπολογισμού δυναμικότητας για περιφέρεια υπολογισμού δυναμικότητας που προσδιορίζεται σύμφωνα με το άρθρο 20 παράγραφος 2 περιλαμβάνει τουλάχιστον τα ακόλουθα στοιχεία για κάθε χρονικό πλαίσιο υπολογισμού δυναμικότητας: α) μεθοδολογίες για τον υπολογισμό των εισροών στον υπολογισμό της δυναμικότητας, οι οποίες να περιλαμβάνουν τουλάχιστον τις ακόλουθες παραμέτρους:

1. i)μέθοδο για τον προσδιορισμό του περιθωρίου αξιοπιστίας, σύμφωνα με το άρθρο 22·
2. ii)μεθοδολογίες για τον προσδιορισμό των ορίων επιχειρησιακής ασφάλειας, των απρόβλεπτων συμβάντων σε σχέση με τον υπολογισμό της δυναμικότητας και τους περιορισμούς κατανομής που επιτρέπεται να εφαρμοστούν, σύμφωνα με το άρθρο 23· iii) μέθοδο για τον προσδιορισμό κλείδων μετατόπισης παραγωγής, σύμφωνα με το άρθρο 24·
3. iv)μεθοδολογία για τον προσδιορισμό των διορθωτικών μέτρων που πρέπει να λαμβάνονται υπόψη κατά τον υπολογισμό δυναμικότητας, σύμφωνα με το άρθρο 25. β) λεπτομερή περιγραφή της προσέγγισης υπολογισμού δυναμικότητας που περιλαμβάνει τα ακόλουθα:
4. i)μαθηματική περιγραφή της εφαρμοζόμενης προσέγγισης δυναμικότητας με διαφορετικές εισροές υπολογισμού δυναμικότητας· υπολογισμού
5. ii)κανόνες για την αποφυγή αθέμιτης διάκρισης μεταξύ εσωτερικών και διαζωνικών ανταλλαγών προκειμένου να διασφαλίζεται η συμμόρφωση με το σημείο 1.7 του παραρτήματος I του κανονισμού (ΕΚ) αριθ. 714/2009· iii) κανόνες ώστε να λαμβάνεται υπόψη, κατά περίπτωση, ήδη κατανεμημένη διαζωνική δυναμικότητα·
6. iv)κανόνες για την προσαρμογή των ροών ισχύος στα κρίσιμα στοιχεία δικτύου ή της διαζωνικής δυναμικότητας λόγω των διορθωτικών μέτρων σύμφωνα με το άρθρο 25· 5 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ
7. v)στην περίπτωση της προσέγγισης με βάση τη ροή, μαθηματική περιγραφή του υπολογισμού των συντελεστών διανομής της μεταφοράς ισχύος και του υπολογισμού των διαθέσιμων περιθωρίων για τα κρίσιμα στοιχεία δικτύου·
8. vi)στην περίπτωση της προσέγγισης με βάση τη συντονισμένη καθαρή δυναμικότητα μεταφοράς, τους κανόνες για τον υπολογισμό της διαζωνικής δυναμικότητας, συμπεριλαμβανομένων των κανόνων για την αποδοτική ανταλλαγή του δυναμικού ροής ισχύος των κρίσιμων στοιχείων δικτύου μεταξύ διαφόρων συνόρων ζωνών προσφοράς· vii) όταν οι ροές ισχύος στα κρίσιμα στοιχεία δικτύου επηρεάζονται από διαζωνικές ανταλλαγές ισχύος σε διαφορετικές περιφέρειες υπολογισμού δυναμικότητας, τους κανόνες επιμερισμού των δυνατοτήτων ροής ισχύος των κρίσιμων στοιχείων δικτύου μεταξύ των διαφορετικών περιφερειών υπολογισμού δυναμικότητας, για την εξυπηρέτηση των εν λόγω ροών. γ) μέθοδο για την επικύρωση διαζωνικής δυναμικότητας, σύμφωνα με το άρθρο 26. …» Επειδή, κατά τις παρ. 5 και 7 του άρθρου 9 του Κανονισμού «Έγκριση των όρων και προϋποθέσεων ή μεθοδολογιών», η πρόταση των ΔΣΜ για την κοινή μεθοδολογία υπολογισμού δυναμικότητας, κατά το άρθρο 20 του Κανονισμού, υπόκειται στην έγκριση όλων των ρυθμιστικών αρχών της οικείας περιφέρειας. Επειδή, κατά τις παρ. 10, 11 και 13 του άρθρου 9 του Κανονισμού προβλέπεται ότι: «[…] 10. Όταν για την έγκριση όρων και προϋποθέσεων ή μεθοδολογιών σύμφωνα με την παράγραφο 7 ή για την τροποποίηση σύμφωνα με την παράγραφο 12 απαιτείται απόφαση από περισσότερες της μίας ρυθμιστικές αρχές, οι αρμόδιες ρυθμιστικές αρχές διαβουλεύονται και συνεργάζονται στενά και συντονίζονται μεταξύ τους, με στόχο την επίτευξη συμφωνίας. Κατά περίπτωση, οι αρμόδιες ρυθμιστικές αρχές λαμβάνουν υπόψη τη γνώμη του Οργανισμού. Οι ρυθμιστικές αρχές ή, κατά περίπτωση, ο Οργανισμός, λαμβάνουν αποφάσεις σχετικά με όρους και προϋποθέσεις ή μεθοδολογίες που υποβλήθηκαν σύμφωνα με τις παραγράφους 6, 7 και 8, εντός έξι μηνών από την παραλαβή των όρων και προϋποθέσεων ή μεθοδολογιών από τον Οργανισμό ή τη ρυθμιστική αρχή ή, κατά περίπτωση, από την τελευταία εμπλεκόμενη ρυθμιστική αρχή. Η περίοδος ξεκινά την επομένη από την υποβολή της πρότασης στον Οργανισμό σύμφωνα με την παράγραφο 6, στην τελευταία εμπλεκόμενη ρυθμιστική αρχή σύμφωνα με την παράγραφο 7 ή, κατά περίπτωση, στη ρυθμιστική αρχή σύμφωνα με την παράγραφο 8. 11. Όταν δεν κατέστη δυνατόν οι ρυθμιστικές αρχές να καταλήξουν σε συμφωνία εντός της περιόδου που αναφέρεται στην παράγραφο 10, ή κατόπιν κοινού αιτήματός τους, ή κατόπιν αιτήματος του Οργανισμού σύμφωνα με το άρθρο 5 παράγραφος 3 τρίτο εδάφιο του κανονισμού (ΕΕ) 2019/942, ο Οργανισμός εκδίδει απόφαση σχετικά 6 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ με τους υποβληθέντες όρους και προϋποθέσεις ή μεθοδολογίες εντός έξι μηνών, σύμφωνα με το άρθρο 5 παράγραφος 3 και το άρθρο 6 παράγραφος 10 δεύτερο εδάφιο του κανονισμού (ΕΕ) 2019/942. […] 13. Ο Οργανισμός, ή όλες οι αρμόδιες ρυθμιστικές αρχές από κοινού, ή η αρμόδια ρυθμιστική αρχή, όπου είναι υπεύθυνοι για την έγκριση όρων και προϋποθέσεων ή μεθοδολογιών σύμφωνα με τις παραγράφους 6, 7 και 8, μπορούν αντιστοίχως να ζητήσουν προτάσεις τροποποίησης των εν λόγω όρων και προϋποθέσεων ή μεθοδολογιών και να καθορίσουν προθεσμία για την υποβολή των προτάσεων αυτών. Οι ΔΣΜ ή ΝΕΜΟ που είναι αρμόδιοι για την κατάρτιση πρότασης για όρους και προϋποθέσεις ή μεθοδολογίες δύνανται να προτείνουν τροποποιήσεις στις ρυθμιστικές αρχές και στον Οργανισμό. Οι προτάσεις για την τροποποίηση των όρων και προϋποθέσεων ή μεθοδολογιών υποβάλλονται σε διαβούλευση σύμφωνα με τη διαδικασία που καθορίζεται στο άρθρο 12 και εγκρίνονται σύμφωνα με τη διαδικασία που καθορίζεται στο παρόν άρθρο. […]» Επειδή, το Ευρωπαϊκό Κοινοβούλιο και το Συμβούλιο της Ευρωπαϊκής Ένωσης εξέδωσαν τον Κανονισμό (ΕΕ) 2019/943 σχετικά με την εσωτερική αγορά ηλεκτρικής ενέργειας (σχετ. 3), με τον οποίο καταργήθηκε ο Κανονισμός (ΕΚ) 714/2009 του Ευρωπαϊκού Κοινοβουλίου και του Συμβουλίου σχετικά με τους όρους πρόσβασης στο δίκτυο για τις διασυνοριακές ανταλλαγές ηλεκτρικής ενέργειας και την κατάργηση του Κανονισμού (ΕΚ) αριθ. 1228/2003 (σχετ. 5). Επειδή, στο σημείο

(28)του σκεπτικού του Κανονισμού (ΕΕ) 2019/943 αναφέρεται ότι: «Η δυναμικότητα μεταφοράς στην οποία θα εφαρμόζεται το κριτήριο της ελάχιστης δυναμικότητας του 70 % στην προσέγγιση καθαρής δυναμικότητας μεταφοράς (NTC) είναι η μέγιστη μεταφορά ενεργού ισχύος που παραμένει εντός των ορίων ασφάλειας λειτουργίας και λαμβάνει υπόψη καταστάσεις συμφόρησης. Ο συντονισμένος υπολογισμός αυτής της δυναμικότητας λαμβάνει επίσης υπόψη ότι οι ροές ηλεκτρικής ενέργειας κατανέμονται κατά τρόπο άνισο μεταξύ επιμέρους συνιστωσών και δεν προσθέτει απλώς δυναμικότητες διασυνδεδεμένων γραμμών. Η εν λόγω δυναμικότητα δεν λαμβάνει υπόψη βροχοειδείς ροές, εσωτερικές ροές ή το περιθώριο αξιοπιστίας, τα οποία λαμβάνονται υπόψη εντός του υπόλοιπου 30 %.». Επειδή, κατά το άρθρο 16 «Γενικές αρχές κατανομής δυναμικότητας και διαχείρισης της συμφόρησης» του ως άνω Κανονισμού: «[…]

1. Τα περιφερειακά συντονιστικά κέντρα διενεργούν συντονισμένο υπολογισμό δυναμικότητας σύμφωνα με τις παραγράφους 4 και 8 του παρόντος άρθρου, όπως 7 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ προβλέπεται στο άρθρο 37 παράγραφος 1 στοιχείο α) και στο άρθρο 42 παράγραφος
2. Τα περιφερειακά συντονιστικά κέντρα υπολογίζουν τις διαζωνικές δυναμικότητες τηρώντας τα όρια ασφάλειας λειτουργίας του συστήματος, με τη χρήση δεδομένων από τους διαχειριστές συστημάτων μεταφοράς, συμπεριλαμβανομένων δεδομένων για την τεχνική διαθεσιμότητα διορθωτικών μέτρων, εξαιρέσει της περικοπής φορτίου. Όταν τα περιφερειακά συντονιστικά κέντρα καταλήγουν στο συμπέρασμα ότι όλα τα διαθέσιμα διορθωτικά μέτρα στην περιφέρεια υπολογισμού δυναμικότητας ή μεταξύ των περιφερειών υπολογισμού δυναμικότητας δεν επαρκούν για την επίτευξη της γραμμικής πορείας δυνάμει του άρθρου 15 παράγραφος 2 ή των ελάχιστων δυναμικοτήτων που προβλέπονται στην παράγραφο 8 του παρόντος άρθρου, τηρώντας παράλληλα τα όρια ασφάλειας λειτουργίας του συστήματος, μπορούν, ως μέτρο έσχατης ανάγκης, να καθορίζουν συντονισμένες δράσεις που θα μειώσουν αντίστοιχα τη διαζωνική δυναμικότητα. Οι διαχειριστές συστημάτων μεταφοράς μπορούν να αποκλίνουν από συντονισμένες δράσεις όσον αφορά τον συντονισμένο υπολογισμό δυναμικότητας και τη συντονισμένη ανάλυση ασφάλειας μόνο σύμφωνα με το άρθρο 42 παράγραφος
3. […]
4. Το μέγιστο επίπεδο δυναμικότητας των διασυνδέσεων και των δικτύων μεταφοράς που επηρεάζονται από τη διασυνοριακή δυναμικότητα, διατίθεται στους συμμετέχοντες στην αγορά που πληρούν τα πρότυπα ασφάλειας για την ασφαλή λειτουργία του δικτύου. Η αντίρροπη συναλλαγή και η ανακατανομή, συμπεριλαμβανομένου της διασυνοριακής ανακατανομής, χρησιμοποιούνται για τη μεγιστοποίηση των διαθέσιμων δυναμικοτήτων, ώστε να επιτευχθεί η ελάχιστη δυναμικότητα που προβλέπεται στην παράγραφο
5. […]
6. Οι διαχειριστές συστήματος μεταφοράς δεν περιορίζουν τον όγκο της δυναμικότητας διασύνδεσης που καθίσταται διαθέσιμος σε συμμετέχοντες στην αγορά ώστε να επιλύσουν το πρόβλημα της συμφόρησης εντός της δικής τους ζώνης προσφοράς ή ως μέσο διαχείρισης των ροών που προκύπτουν από εσωτερικές συναλλαγές σε ζώνες προσφοράς. Με την επιφύλαξη της εφαρμογής των παρεκκλίσεων των παραγράφων 3 και 9 του παρόντος άρθρου και της εφαρμογής του άρθρου 15 παράγραφος 2, η παρούσα παράγραφος θεωρείται ότι τηρείται, όταν τα ακόλουθα ελάχιστα επίπεδα διαθέσιμης δυναμικότητας διαζωνικού εμπορίου επιτυγχάνονται: α) για σύνορα που χρησιμοποιούν μια προσέγγιση με βάση τη συντονισμένη καθαρή δυναμικότητα μεταφοράς, ελάχιστο όριο δυναμικότητας είναι το 70 % της δυναμικότητας μεταφοράς που τηρεί όρια ασφαλούς λειτουργίας αφού αφαιρεθούν τα απρόβλεπτα, κατά τα οριζόμενα βάσει των κατευθυντήριων γραμμών για την κατανομή της δυναμικότητας και τη διαχείριση της συμφόρησης που 8 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ εκδόθηκαν βάσει του άρθρου 18 παράγραφος 5 του κανονισμού (ΕΚ) αριθ. 714/2009· […] Μια συνολική ποσότητα ίση προς το 30 % μπορεί να χρησιμοποιείται για περιθώρια αξιοπιστίας, βροχοειδείς και εσωτερικές ροές σε κάθε κρίσιμο στοιχείο δικτύου. […]». Επειδή, o Κανονισμός (ΕΚ) 713/2009 του Ευρωπαϊκού Κοινοβουλίου και του Συμβουλίου, ο οποίος θέσπισε τον Οργανισμό Συνεργασίας των Ρυθμιστικών Αρχών Ενέργειας (ACER) καταργήθηκε με το άρθρο 46 του Κανονισμού (ΕΕ) 2019/942 (σχετ. 4), οι δε παραπομπές στον καταργούμενο κανονισμό νοούνται ως παραπομπές στον τελευταίο αυτόν Κανονισμό και διαβάζονται σύμφωνα με τον πίνακα αντιστοιχίας του Παραρτήματος ΙΙ. Επειδή, στην παρ. 3 του άρθρου 5 του Κανονισμού (ΕΕ) 2019/942 προβλέπεται ότι: «[…]
7. Όταν μία από τις ακόλουθες νομικές πράξεις προβλέπει την εκπόνηση προτάσεων για όρους και προϋποθέσεις ή μεθοδολογίες για την εφαρμογή των εν λόγω κωδικών δικτύου και κατευθυντήριων γραμμών, περί των οποίων απαιτείται κανονιστική έγκριση από τις αρμόδιες ρυθμιστικές αρχές της εκάστοτε περιφέρειας, οι εν λόγω ρυθμιστικές αρχές λαμβάνουν απόφαση με ομοφωνία σχετικά με τους κοινούς όρους και προϋποθέσεις ή μεθοδολογίες που θα εγκριθούν από κάθε μία από τις εν λόγω ρυθμιστικές αρχές: […] β) οι κώδικες δικτύου και οι κατευθυντήριες γραμμές που έχουν εκδοθεί πριν από την 4η Ιουλίου 2019 και μεταγενέστερες αναθεωρήσεις αυτών των κωδικών δικτύου και των κατευθυντηρίων γραμμών, […] Οι ρυθμιστικές αρχές δύνανται να παραπέμψουν τις προτάσεις προς έγκριση στον ACER σύμφωνα με το άρθρο 6 παράγραφος 10 δεύτερο εδάφιο στοιχείο β) και ακολουθούν το άρθρο 6 παράγραφος 10 δεύτερο εδάφιο στοιχείο α) σε περίπτωση που δεν είναι δυνατόν να ληφθεί απόφαση με ομοφωνία όπως αναφέρεται στο πρώτο εδάφιο. Ο διευθυντής ή το ρυθμιστικό συμβούλιο, ιδία πρωτοβουλία ή μετά από πρόταση ενός ή περισσοτέρων από τα μέλη του, δύναται να απαιτήσει από τις ρυθμιστικές αρχές της συγκεκριμένης περιφέρειας να παραπέμψουν την πρόταση στον ACER προς έγκριση. Το αίτημα αυτό αφορά μόνο τις περιπτώσεις όπου πρόταση συμφωνημένη σε περιφερειακό επίπεδο θα έχει απτό αντίκτυπο στην εσωτερική αγορά ενέργειας ή στην ασφάλεια του εφοδιασμού και πέρα από την περιοχή. […]» Επειδή, κατά την παρ. 10 του άρθρου 6 του Κανονισμού (ΕΕ) 2019/942 προβλέπεται ότι: «[…]
8. Ο ACER είναι αρμόδιος να εκδίδει ατομικές αποφάσεις σχετικά με ρυθμιστικά ζητήματα που έχουν επιπτώσεις στις διασυνοριακές συναλλαγές ή στη διασυνοριακή ασφάλεια του συστήματος, για τα οποία απαιτείται κοινή απόφαση δύο τουλάχιστον ρυθμιστικών αρχών, όταν αυτές οι αρμοδιότητες έχουν εκχωρηθεί στις ρυθμιστικές αρχές σύμφωνα με μία από τις ακόλουθες νομοθετικές πράξεις:[…] β) κώδικες δικτύου και κατευθυντήριες γραμμές που εκδίδονται πριν από την 4η Ιουλίου 2019 και μεταγενέστερες αναθεωρήσεις αυτών των κωδικών δικτύου και των κατευθυντηρίων γραμμών, […] 9 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ Ο ACER είναι αρμόδιος να εκδίδει ατομικές αποφάσεις όπως προβλέπεται στο πρώτο εδάφιο στις ακόλουθες περιπτώσεις: α) εφόσον δεν κατέστη δυνατό να επιτευχθεί συμφωνία των αρμόδιων ρυθμιστικών αρχών εντός έξι μηνών μετά την παραπομπή της υπόθεσης στην τελευταία από τις εν λόγω ρυθμιστικές αρχές· ή εντός τεσσάρων μηνών σε περιπτώσεις δυνάμει του άρθρου 4 παράγραφος 7 του παρόντος κανονισμού ή του άρθρου 59 παράγραφος 1 στοιχείο γ) ή του άρθρου 62 παράγραφος 1 στοιχείο στ) της οδηγίας (ΕΕ) 2019/944· ή β) βάσει κοινής αιτήσεως των αρμόδιων ρυθμιστικών αρχών. […]» Επειδή, κατά το άρθρο 6 παρ. 1γ του Κεφαλαίου Γ του ν. 4425/2016 (σχετ.1), προβλέπεται ότι: «
9. Πέραν των αρμοδιοτήτων που προβλέπονται στην κείμενη νομοθεσία και ιδίως στις διατάξεις του ν. 4001/2011, η ΡΑΕ: … γ) Ασκεί τις αρμοδιότητες των ρυθμιστικών αρχών που προβλέπονται στον Κανονισμό (ΕΕ) 2015/1222 και προβλέπουν ιδίως […] την έγκριση των λοιπών όρων και προϋποθέσεων ή μεθοδολογιών και την εκτέλεση όλων των καθηκόντων, λειτουργιών και αρμοδιοτήτων, κατά τα αναλυτικά προβλεπόμενα στον Κανονισμό αυτό.». Επειδή, περαιτέρω, κατά το άρθρο 17 παρ. 7 του Κεφαλαίου Γ του ίδιου ν. 4425/2016 (σχετ.1), προβλέπεται ότι: «
10. Ο Διαχειριστής του ΕΣΜΗΕ έχει τις αρμοδιότητες που προβλέπονται στους Κανονισμούς (ΕΕ) 2019/943, […] και 2015/
11. Η άσκηση των αρμοδιοτήτων του Διαχειριστή συντείνει, ιδίως, στην επίτευξη του στόχου σύγκλισης της ελληνικής αγοράς ηλεκτρικής ενέργειας με τις αντίστοιχες ευρωπαϊκές και στην ολοκλήρωση της ενιαίας εσωτερικής αγοράς ηλεκτρικής ενέργειας της ΕΕ, σύμφωνα με τις απαιτήσεις της ευρωπαϊκής νομοθεσίας.». Επειδή, με την υπό σχετ. 7 Απόφαση της ΡΑΕ, εγκρίθηκε η πρόταση των Διαχειριστών Συστημάτων Μεταφοράς (ΔΣΜ) της περιφέρειας υπολογισμού δυναμικότητας Νοτιοανατολικής Ευρώπης (SEE CCR), η οποία αφορά στη μεθοδολογία συντονισμένου υπολογισμού της δυναμικότητας εντός της οικείας περιφέρειας, σύμφωνα με τα άρθρα 20 και 21 του Κανονισμού. Περαιτέρω, η πρόταση αυτή τροποποιήθηκε με την υπό σχετ. 9 Απόφαση της Αρχής. Επειδή, με τα υπό σχετ. 10 και 11 έγγραφα, υπεβλήθησαν στη ΡΑΕ από την ΑΔΜΗΕ Α.Ε., εκ μέρους των ΔΣΜ της SEE CCR, η κοινή τροποποιημένη πρόταση τους για τη μεθοδολογία συντονισμένου υπολογισμού της δυναμικότητας εντός της οικείας περιφέρειας, σύμφωνα με τα άρθρα 20 και 21 και την παρ. 13 του άρθρου 9 του Κανονισμού, καθώς και το διάγραμμα ροής της εν λόγω μεθοδολογίας. Επειδή, οι τροποποιήσεις της μεθοδολογίας προτείνονται από τους Διαχειριστές, προκειμένου να ενσωματώσουν σε αυτήν αφενός τις προβλέψεις του Άρθρου 16 του Κανονισμού (ΕΕ) 2019/943, ήτοι τις απαιτήσεις για την επίτευξη του στόχου της 10 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ ελάχιστης διαθέσιμης δυναμικότητας για διαζωνικό εμπόριο, αφετέρου δε προβλέψεις για την εισαγωγή των ΔΣΜ των τρίτων χωρών (κράτη που δεν έχουν ενταχθεί στην ΕΕ) ως τεχνικών αντισυμβαλλόμενων, σε συμφωνία με τις κατευθυντήριες οδηγίες της Γενικής Διεύθυνσης Ενέργειας της Ευρωπαϊκής Επιτροπής (DG Energy) προς τον ACER και τον ENTSO-e. (σχετ. 8) Επειδή, ειδικότερα, η τροποποιημένη μεθοδολογία λαμβάνει υπόψη την αποτελεσματική δομή του δικτύου και τα σύνορα μεταξύ της SEE CCR και των τρίτων χωρών, υπό τη θεώρηση της σύναψης συμβάσεων μεταξύ ΔΣΜ (ΔΣΜ-ΔΣΜ συμβάσεις) προκειμένου για τη συμπερίληψη των τρίτων χωρών ως τεχνικών αντισυμβαλλόμενων. Συνεπώς, η μεθοδολογία αυτή θα ισχύει και για των/τους ΔΣΜ των τρίτων χωρών, εάν ο/οι ΔΣΜ υπογράψει/ουν συμφωνία με όλους τους ΔΣΜ της SEE CCR σύμφωνα με την οποία θα πρέπει να συμμορφώνονται με το περιεχόμενο της μεθοδολογίας και να αποδέχονται όλα τα δικαιώματα και τις υποχρεώσεις που προκύπτουν από αυτήν. Επειδή, επιπροσθέτως, προς συμμόρφωση με τις διατάξεις του άρθρου 16

(8)του Κανονισμού (ΕΕ) 2019/943, οι ΔΣΜ της SEE CCR περιλαμβάνουν τροποποιήσεις στη μεθοδολογία για την παρακολούθηση του διαθέσιμου περιθωρίου για διασυνοριακό εμπόριο κατά τον υπολογισμό της δυναμικότητας για το χρονικό πλαίσιο της Αγοράς Επόμενης Ημέρας. Ο φορέας συντονισμένου υπολογισμού δυναμικότητας (CCC) θα διασφαλίζει ότι η υπολογισμένη καθαρή δυναμικότητα μεταφοράς ικανοποιεί τις ελάχιστες απαιτήσεις δυναμικότητας σύμφωνα με το άρθρο 16

(8)του Κανονισμού (ΕΕ) 2019/943, χρησιμοποιώντας διορθωτικά μέτρα (remedial actions) που δεσμεύονται για τον σκοπό αυτό από τους ΔΣΜ της SEE CCR ή ενδεχομένως προτείνονται από τον CCC. Επειδή, η ΑΔΜΗΕ Α.Ε. με το υπό σχετ. 12 έγγραφό της υπέβαλε στη ΡΑΕ επίσημη μετάφραση στην ελληνική γλώσσα του υπό σχετ. 10 εγγράφου. Επειδή, ακολούθως, η ΡΑΕ, από 21.02.2023 έως και 14.03.2023 έθεσε την υπό σχετ. 10 πρόταση των ΔΣΜ της SEE CCR σε δημόσια διαβούλευση, κατά τη διάρκεια της οποίας δεν υπεβλήθησαν σχόλια (σχετ. 13). Επειδή, οι Ρυθμιστικές Αρχές της SEE CCR μετά από ενδελεχή αξιολόγηση της τροποποιημένης μεθοδολογίας θεώρησαν ότι η μεθοδολογία αυτή πληροί τις απαιτήσεις του Κανονισμού και περιέχει μία αποδεκτή προσέγγιση, η οποία διέπεται από σαφήνεια και ακρίβεια καθώς και ότι η τροποποίηση αυτής βελτιώνει την ποιότητα του περιεχομένου και της δομής της. Ωστόσο, οι Ρυθμιστικές Αρχές της SEE CCR αιτήθηκαν από τους οικείους ΔΣΜ να τις κρατάνε ενήμερες σχετικά με τη φάση υλοποίησης αυτής, καθώς και την κατάσταση των συμφωνιών μεταξύ των ΔΣΜ της SEE CCR και των τεχνικών αντισυμβαλλόμενων. Επειδή, περαιτέρω, οι οικείες Ρυθμιστικές Αρχές πραγματοποίησαν αλλαγές λεκτικού περιεχομένου στην πρόταση των Διαχειριστών (αλλαγές στη διατύπωση και τυπογραφικά λάθη). 11 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ Επειδή, στη συνέχεια, οι Ρυθμιστικές Αρχές της SEE CCR κατόπιν της ηλεκτρονικής ψηφοφορίας, συμφώνησαν ομόφωνα (unanimous agreement) μέσω του South-East Europe Energy Regulators’ Regional Forum (SEE ERRF), ως συλλογικού οργάνου των Ρυθμιστικών Αρχών της οικείας περιφέρειας, επί της τροποποίησης της μεθοδολογίας συντονισμένου υπολογισμού της δυναμικότητας εντός της οικείας περιφέρειας, σύμφωνα με τα άρθρα 20 και 21 του Κανονισμού (σχετ. 15). Επειδή, ακολούθως, με την υπό σχετ. 16 επιστολή γνωστοποιήθηκε προς τους ΔΣΜ της SEE CCR με κοινοποίηση στην Ευρωπαϊκή Επιτροπή και στον ACER η ανωτέρω ομόφωνη συμφωνία των Ρυθμιστικών Αρχών της SEE CCR περί της μεθοδολογίας συντονισμένου υπολογισμού της δυναμικότητας εντός της οικείας περιφέρειας, δυνάμει των άρθρων 20 και 21 και σύμφωνα με την παρ. 10 του άρθρου 9 του Κανονισμού, προκειμένου ο ACER να μην προχωρήσει στην έκδοση απόφασης της παρ. 11 του άρθρου 9 του Κανονισμού. Επειδή, κατά το άρθρο 22 του ν. 4001/ 2011 «Η ΡΑΕ, στο πλαίσιο των αρμοδιοτήτων της, παρακολουθεί και εποπτεύει τη λειτουργία της αγοράς ενέργειας… συμπεριλαμβανομένης της έκδοσης κανονιστικών και ατομικών πράξεων, ιδίως για την …ανάπτυξη της εσωτερικής αγοράς ενέργειας της Ευρωπαϊκής Ένωσης…» και κατά το άρθρο 32 του ίδιου νόμου «1. Οι πράξεις και αποφάσεις της ΡΑΕ, … δημοσιοποιούνται με ανάρτηση στην επίσημη ιστοσελίδα της. Οι κανονιστικού χαρακτήρα αποφάσεις της ΡΑΕ δημοσιεύονται επιπλέον στην Εφημερίδα της Κυβερνήσεως….». Κατόπιν των ανωτέρω και σύμφωνα με αυτά: ΑΠΟΦΑΣΙΖΕΙ Στο πλαίσιο των αρμοδιοτήτων της κατά τα άρθρα 9 (παρ. 5, 7 και 10), 20 και 21 του Κανονισμού (ΕΕ) 2015/1222, άρθρο 6 του Ν. 4425/2016 (ΦΕΚ Α΄ 185) και άρθρα 22 και 32 του Ν. 4001/2011 (ΦΕΚ Α΄ 179) και σύμφωνα με την ομόφωνη συμφωνία των Ρυθμιστικών Αρχών της SEE CCR: Την τροποποίηση της μεθοδολογίας συντονισμένου υπολογισμού της δυναμικότητας εντός της περιφέρειας υπολογισμού δυναμικότητας Νοτιοανατολικής Ευρώπης (SEE CCR), σύμφωνα με τα άρθρα 20 και 21 του Κανονισμού (ΕΕ) 2015/1222 της Επιτροπής, της 24ης Ιουλίου 2015, σχετικά με τον καθορισμό κατευθυντήριων γραμμών για την κατανομή της δυναμικότητας και τη διαχείριση της συμφόρησης και σύμφωνα με την ανωτέρω ομόφωνη συμφωνία των Ρυθμιστικών Αρχών της SEE CCR. Το περιεχόμενο της ως άνω τροποποιημένης μεθοδολογίας περιλαμβάνεται στο συνημμένο της παρούσας απόφασης κείμενο, το οποίο αποτελεί αναπόσπαστο μέρος αυτής. Η παρούσα Απόφαση κοινοποιείται στην εταιρεία «Ανεξάρτητος Διαχειριστής Μεταφοράς Ηλεκτρικής Ενέργειας Α.Ε.» και με διακριτικό τίτλο «ΑΔΜΗΕ Α.Ε.» για τις σχετικές της ενέργειες σύμφωνα με τον 12 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ Κανονισμό (ΕΕ) 2015/1222 και στο Περιφερειακό Κέντρο Συντονισμού της SEE CCR υπό την ονομασία SEleNe CC (Southeast Electricity Network Coordination Center), αναρτάται στην επίσημη ιστοσελίδα της Ρ.Α.A.Ε.Y. και δημοσιεύεται στην Εφημερίδα της Κυβερνήσεως. Αθήνα, 7 Σεπτεμβρίου 2023 Ο Αντιπρόεδρος του κλάδου Ενέργειας της Ρ.Α.Α.Ε.Υ. Δημήτριος Φούρλαρης 13 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of the Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management August 2023 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management TSOs of the SEE CCR, taking into account the following: Whereas

(1)This document (hereafter referred to as “common capacity calculation methodology”, or “this methodology”) is a common proposal developed by all Transmission System Operators (hereafter referred to as “TSOs”) within the South East Europe Capacity Calculation Region (hereafter referred to as “SEE Capacity Calculation Region” or “SEE CCR”), on the common capacity calculation performed for the capacity allocation within the day-ahead and intraday market timeframes. This proposal is required by Article 20

(2)and developed in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on Capacity Allocation and Congestion Management (hereafter referred to as the “CACM Regulation”).

(2)This proposal (hereafter referred to as the “common capacity calculation methodology Proposal”) takes into account the general principles and goals set in the CACM Regulation as well as Regulation (EC) No 714/2009 of the European Parliament and of the Council of 13 July 2009 on conditions for access to the network for cross-border exchanges in electricity and repealing Regulation (EC) No 1228/2003 (hereafter referred to as “Regulation (EC) No 714/2009”).

(3)Τhis methodology takes into account the general principles and goals set in the CACM Regulation, while respecting the principles set in the Regulation (EU) 2019/943 of the European Parliament and of the Council of 5 June 2019 on the internal market for electricity (recast) (hereafter referred to as “Regulation (EU) 2019/943”). In addition, this methodology takes into account the effective structure of the grid and the borders between SEE and non-EU countries (hereafter referred to as “Third Countries”)by establishing TSO-TSO based contractual frameworks to include Third Countries as Technical Counterparties. Therefore, this methodology takes into account Technical Counterparties' grid elements.

(4)This methodology takes into account the general principles and goals set in CACM Regulation. Ensuring optimal use of the transmission infrastructure and operational security, which are among the objectives of capacity allocation and congestion management cooperation, laid down by Article 3 of CACM Regulation, requires the inclusion of Third Countries’ grid elements in the capacity calculation process of SEE CCR. CACM Regulation’s objectives cannot be achieved in any other way but by including Third Countries’ grid elements. This inclusion is in line with Article 13 of Commission Regulation (EU) 2017/1485 of 2 August 2017 establishing a guideline on electricity transmission system operation (hereafter referred to as “SOGL Regulation”), providing that EU TSOs must establish “cooperation concerning secure system operation” with non-EU TSOs belonging to the same synchronous area via an agreement with these non-EU TSOs. In order to comply with the requirement laid down by EU Regulation, this methodology includes Third Countries as Technical Counterparties. TSOs of SEE CCR will conclude to an agreement with relevant Technical Counterparties. In order to be taken into consideration in the capacity calculation process and enter into a TSO-TSO based contractual framework, Technical Counterparties must fulfil the conditions laid down by Article 1.3 of the “All TSOs’ proposal for a common grid model methodology in accordance with Article 17 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management”, applicable to TSOs from jurisdictions outside the area referred to in Article 1

(2)of the CACM Regulation. The agreement between SEE CCR TSOs and the Technical Counterparty will include the CCC methodology’s provisions and ensure that the Technical Counterparty is contractually bound by the same obligations as the ones binding upon TSOs of the SEE CCR by virtue of EU Regulations. Such agreement will govern mutual obligations and responsibilities of the Technical Counterparty with TSOs of SEE CCR in relation to the capacity calculation process. 2 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(5)The goal of the CACM Regulation is the coordination and harmonization of capacity calculation and allocation in the day-ahead and intraday cross-border markets. To facilitate these aims the TSOs in the Capacity Calculation Region shall calculate in a coordinated manner the available cross-border capacity.

(6)Article 21

(1)of the CACM Regulation constitutes the legal basis for this proposal and defines several specific requirements that the common capacity calculation methodology Proposal should take into account: “1. The proposal for a common capacity calculation methodology for a capacity calculation region determined in accordance with Article 20

(2)shall include at least the following items for each capacity calculation time-frame: (

1. a)methodologies for the calculation of the inputs to capacity calculation, which shall include the following parameters: (
2. i)a methodology for determining the reliability margin in accordance with Article 22; (
3. ii)the methodologies for determining operational security limits, contingencies relevant to capacity calculation and allocation constraints that may be applied in accordance with Article 23; (iii) the methodology for determining the generation shift keys in accordance with Article 24; (
4. iv)the methodology for determining remedial actions to be considered in capacity calculation in accordance with Article 25; (
5. b)a detailed description of the capacity calculation approach which shall include the following: (
6. i)a mathematical description of the applied capacity calculation approach with different capacity calculation inputs; (
7. ii)rules for avoiding undue discrimination between internal and cross- zonal exchanges to ensure compliance with point 1.7 of Annex I to Regulation (EC) No 714/2009; (iii) rules for taking into account, where appropriate, previously allocated cross-zonal capacity; (
8. iv)rules on the adjustment of power flows on critical network elements or of cross-zonal capacity due to remedial actions in accordance with Article 25; (
9. v)for the coordinated net transmission capacity approach, the rules for calculating cross-zonal capacity, including the rules for efficiently sharing the power flow capabilities of critical network elements among different bidding zone borders; (
10. vi)where the power flows on critical network elements are influenced by cross-zonal power exchanges in different capacity calculation regions, the rules for sharing the power flow capabilities of critical network elements among different capacity calculation regions in order to accommodate these flows. (
11. c)a methodology for the validation of cross-zonal capacity in accordance with Article 26.”

(7)Article 14 of the CACM Regulation, with reference to the day ahead timeframe, defines the following: “

1. (…) TSOs shall calculate cross- zonal capacity for (…) (a) “day-ahead, for the day-ahead market“ and “
2. For the day-ahead market time-frame, individual values for cross-zonal capacity for each dayahead market time unit shall be calculated.”, and “
3. For the day-ahead market time-frame, the capacity calculation shall be based on the latest available information. The information update for the day-ahead market time-frame shall not start before 15:00 market time two days before the day of delivery”.

(8)Article 14 of the CACM Regulation, with reference to the intraday ahead timeframe, defines the following: “

1. (…) TSOs shall calculate cross- zonal capacity for (…) (b) intraday, for the intraday market;” and“
2. All TSOs in each capacity calculation region shall ensure that cross-zonal capacity is recalculated within the intraday market time-frame based on the latest available information. The frequency of this recalculation shall take into consideration efficiency and operational security”

(9)Article 20

(1)of the CACM Regulation defines the approach to use in the common capacity calculation methodologies as “flow-based approach” after the conditions Article 20

(4)are met and

(4)specifies 3 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management that: “No later than six months after at least all South East Europe Energy Community Contracting Parties participate in the single day-ahead coupling, the TSOs from at least Croatia, Romania, Bulgaria and Greece shall jointly submit a proposal to introduce a common capacity calculation methodology using the flow-based approach for the day-ahead and intraday market time-frame“. So, the common capacity calculation methodology Proposal is based on coordinated net transmission capacity approach.

(10)Article 2

(8)of the CACM Regulation defines the “coordinated net transmission capacity approach” as “the capacity calculation method based on the principle of assessing and defining ex ante a maximum energy exchange between adjacent bidding zones”.

(11)In the context of this proposal, the definition of “coordinated capacity calculator” is important and is defined in Article 2

(11)of the CACM Regulation as: “the entity or entities with the task of calculating transmission capacity, at regional level or above”.

(12)Article 9

(9)of the CACM Regulation requires that the proposed timescale for the implementation and the expected impact of the common capacity calculation methodology Proposal on the objectives of the CACM Regulation is described. The impact is presented below (point

(13)) of this Whereas Section.

(13)The common capacity calculation methodology Proposal generally contributes to the achievement of the objectives of Article 3 of the CACM Regulation: Article 3(

1. a)of the CACM Regulation aims at promoting effective competition in the generation, trading and supply of electricity. The common capacity calculation methodology Proposal serves the objective of promoting effective competition in the generation, trading and supply of electricity by defining a set of harmonized rules for capacity calculation and congestion management, which contributes to the effectiveness of the single day-ahead and intraday coupling. Establishing common and coordinated processes for the capacity calculations within the day-ahead and intraday market timeframes contributes to achieve this objective. Article 3(
2. b)of the CACM Regulation aims at ensuring optimal use of the transmission infrastructure. The common capacity calculation methodology Proposal contributes to achieve the objective of ensuring optimal use of the transmission infrastructure by using last available inputs based on the best possible forecast of transmission systems at the time of each capacity calculation, updated in a timely manner. Article 3(
3. c)of the CACM Regulation aims at ensuring operational security. The common capacity calculation methodology Proposal contributes to achieve the objective of ensuring operational security by coordinating the capacity calculation with updated inputs for the day-ahead and intraday market timeframe at regional level to ensure its reliability. Article 3(
4. d)of the CACM Regulation aims at optimizing the calculation and allocation of cross- zonal capacity. By coordinating the timings for the delivery of inputs, calculation approach and validation requirements of the common capacity calculation between TSOs and the coordinated capacity calculator, the common capacity calculation methodology proposal contributes to achieve the objective of optimizing the calculation and allocation of cross-zonal capacity. Article 3(
5. g)of the CACM Regulation aims at contributing to the efficient long-term operation and development of the electricity transmission system and electricity sector in the Union. By using the best possible forecast of the transmission systems at the time of each capacity calculation within the SEE CCR, the results of the coordinated capacity calculation contribute to determine the most limiting branches within this region, thus supporting TSOs for a more efficient development of the electricity transmission system.

(14)In conclusion, the common capacity calculation methodology Proposal contributes to the general 4 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management objectives of the CACM Regulation to the benefit of all market participants and electricity end consumers.

(15)Article 16

(8)of the Regulation (EU) 2019/943 complements the principles of the CACM Regulation, with the introduction of a requirement for a minimum level of capacity to be offered to the market: “Transmission system operators shall not limit the volume of interconnection capacity to be made available to market participants as a means of solving congestion inside their own bidding zone or as a means of managing flows resulting from transactions internal to bidding zones. Without prejudice to the application of the derogations under paragraphs 3 and 9 of this Article and to 6 the application of Article 15

(2), this paragraph shall be considered to be complied with where the following minimum levels of available capacity for cross-zonal trade are reached: (a) for borders using a coordinated net transmission capacity approach, the minimum capacity shall be 70 % of the transmission capacity respecting operational security limits after deduction of contingencies, as determined in accordance with the capacity allocation and congestion management guideline adopted on the basis of Article 18

(5)of Regulation (EC) No 714/2009; (b) for borders using a flow-based approach, the minimum capacity shall be a margin set in the capacity calculation process as available for flows induced by cross-zonal exchange. The margin shall be 70 % of the capacity respecting operational security limits of internal and cross-zonal critical network elements, taking into account contingencies, as determined in accordance with the capacity allocation and congestion management guideline adopted on the basis of Article 18

(5)of Regulation (EC) No 714/2009. The total amount of 30 % can be used for the reliability margins, loop flows and internal flows on each critical network element.”

(16)The common capacity calculation methodology is based on forecast models of the transmissions system. Therefore, the outcomes are subject to inaccuracies and uncertainties. The aim of the reliability margin is to cover a level of risk induced by these forecast errors. Nevertheless, in order to limit the impact of these uncertainties on available cross-zonal capacities, an overall limitation of reliability margin is needed and uncertainties exceeding this limitation should be managed in other ways. This methodology applies a temporary range for reliability margin, by using the reliability margin values already in operation in the existing capacity calculation initiatives. The first real calculation can only be done after some operational experience is gained with the application of this methodology.

(17)Articles 15

(1), 15

(2)and 15

(4), and Article 16

(9)of the Regulation (EU) 2019/943 introduce possible temporary exemptions to comply with the minimum level of capacity set in the Article 16

(8)of the Regulation (EU) 2019/943 through action plans and derogations.

(18)Article 16

(4)of the Regulation (EU) 2019/943 gives a framework for the consideration of costly remedial actions in the capacity calculation: “The maximum level of capacity of the interconnections and the transmission networks affected by cross-border capacity shall be made available to market participants complying with the safety standards of secure network operation. Counter-trading and redispatch, including cross-border redispatch, shall be used to maximise available capacities to reach the minimum capacity provided for in paragraph 8. A coordinated and non-discriminatory process for cross-border remedial actions shall be applied to enable such maximisation, following the implementation of a redispatching and counter-trading cost-sharing methodology.”

(19)Article 16

(3)of the Regulation (EU) 2019/943 describes the capacity calculation process and attributes 5 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management the role of coordinated capacity calculator to the regional coordination centres: “Regional coordination centres shall carry out coordinated capacity calculation in accordance with paragraphs 4 and 8 of this Article, as provided for in point (a) of Article 37

(1)and in Article 42

(1). Regional coordination centres shall calculate cross-zonal capacities respecting operational security limits using data from transmission system operators including data on the technical availability of remedial actions, not including load shedding. Where regional coordination centres conclude that those available remedial actions in the capacity calculation region or between capacity calculation regions are not sufficient to reach the linear trajectory pursuant to Article 15

(2)or the minimum capacities provided for in paragraph 8 of this Article while respecting operational security limits, they may, as a measure of last resort, set out coordinated actions reducing the cross-zonal capacities accordingly. Transmission system operators may deviate from coordinated actions in respect of coordinated capacity calculation and coordinated security analysis only in accordance with Article 42

(2). By 3 months after the entry into operation of the regional coordination centres pursuant to Article 35

(2)of this Regulation and every three months thereafter, the regional coordination centres shall submit a report to the relevant regulatory authorities and to ACER on any reduction of capacity or deviation from coordinated actions pursuant to the second subparagraph and shall assess the incidences and make recommendations, if necessary, on how to avoid such deviations in the future. If ACER concludes that the prerequisites for a deviation pursuant to this paragraph are not fulfilled or are of a structural nature, ACER shall submit an opinion to the relevant regulatory authorities and to the Commission. The competent regulatory authorities shall take appropriate action against transmission system operators or regional coordination centres pursuant to Article 59 or 62 of Directive (EU) 2019/944 if the prerequisites for a deviation pursuant to this paragraph were not fulfilled. Deviations of a structural nature shall be addressed in an action plan referred to in Article 14

(7)or in an update of an existing action plan.”

(20)The final definition of the capacity calculation inputs (the reliability margin, the list of critical network elements, the generation shift key, and remedial actions) shall be reviewed and redefined if needed after the implementation of this methodology once some operational experience is obtained. The SEE TSOs shall make ex-post analysis of these input parameters regularly and, if considered necessary, they will request to change them. If any change leads to an adaption of this methodology, SEE TSOs will amend this methodology according to Article 9

(13)of the CACM Regulation.

(21)To avoid undue discrimination between internal and cross-zonal exchanges (and the underlying discrimination between market participants trading inside or between bidding zones), this methodology introduces important measures. The SEE TSOs shall monitor only the elements significantly impacted by cross-zonal power exchanges. As mid-term and long-term measures, the SEE TSOs shall investigate a higher sensitivity threshold for the elements significantly impacted by cross-zonal power exchanges and consider future investments in the transmission grid.

(22)Despite coordinated application of capacity calculation, SEE TSOs remain responsible for maintaining operational security. For this reason, each SEE TSO shall validate and have the right to correct crosszonal capacity relevant to the TSOs bidding zone border for reasons of operational security during the validation process. The validation process may lead to reductions of cross-zonal capacities. Thus, transparency, monitoring and reporting as well as exploration of alternative solutions in order to prevent similar cases in the future, is necessary.

(23)Transparency and monitoring of capacity calculation is essential for ensuring its efficiency and understanding. This methodology establishes significant requirements on TSOs to publish the information required by stakeholders to analyses the impact of capacity calculation on market functioning. Furthermore, this methodology establishes significant reporting requirements in order for the stakeholders, regulatory authorities and other interested party to verify either the transmission 6 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management infrastructure is operated efficiently and in the interest of consumers. SUBMIT THE FOLLOWING DAY-AHEAD AND INTRADAY COMMON CAPAPACITY CALCULATION METHODOLOGY TO NATIONAL REGULATORY AUTHORITIES OF THE SEE CCR: 7 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management Article 1 Subject matter and scope The common capacity calculation methodology shall be considered as a SEE TSOs methodology in accordance with Article 21 of the CACM Regulation and shall cover the day-ahead and intraday common capacity calculation methodology for the SEE CCR bidding zone borders. Article 2 Definitions and interpretation

(1)For the purposes of the day-ahead and intraday common capacity calculation methodology, the terms used in this document shall have the meaning of the definitions included in Article 2 of the CACM Regulation, of Regulation (EC) No 714/2009, in Article 2 of the Commission Regulation (EU) No 543/2013 of 14 June 2013 on submission and publication of data in electricity markets and amending Annex I to Regulation (EC) No 714/2009 of the European Parliament and of the Council, in Article 2 of the Directive 2009/72/EC of the European Parliament and of the Council of 13 July 2009 concerning common rules for the internal market in electricity and repealing Directive 2003/54/EC.

(2)In addition, the following definitions, abbreviations and notations shall apply:

1. ‘AAC’ means the already allocated capacities, which is the capacity allocated as an outcome of the latest capacity calculation in the SEE CCR;
2. ‘ANC’ means the already nominated capacities, which is the nomination of the already allocated capacities;
3. ‘ATC’ means the available transmission capacity, which is the transmission capacity that remains available for the allocation procedure and which respects the physical conditions of the transmission system;
4. ‘CCC’ means the coordinated capacity calculator of the SEE CCR as defined in Article 2

(11)of the CACM Regulation; 5. ‘CCR’ means the capacity calculation region as defined in Article 2

(3)of the CACM Regulation; 6. ‘CGM’ means the common grid model as defined in Article 2

(2)of the CACM Regulation;

1. ‘CGMM’ means the common grid model methodology, pursuant to Article 17 of the CACM Regulation;
2. ‘CNE’ means a critical network element;
3. ‘CNEC’ means a critical network element with a contingency;
4. ‘CNTC approach’ means the coordinated net transmission capacity defined in Article 2

(8)of the CACM Regulation;

1. ‘D-1’ means the day before the day of delivery;
2. ‘D-2’ means two days before the day of delivery;
3. ‘D-2 CGM’ means the common grid model built for each market time unit two days before the day of delivery for the day-ahead capacity calculation time-frame in accordance with Article 17 of the CACM Regulation;
4. ‘D-1 CGM’ means the common grid model built for each market time unit one day before the day of delivery for the intraday capacity calculation time-frame in accordance with Article 17 of the CACM Regulation;
5. ‘GR-BG border’ means bidding zone border between Greece and Bulgaria;
6. ‘BG-RO border’ means bidding zone border between Bulgaria and Romania;
7. ‘FCA Regulation’ means the Commission Regulation (EU) 2016/1719 of 26 September 2016 establishing a guideline on forward capacity allocation;
8. ‘GSK’ means the generation shift key as defined in Article 2

(12)of the CACM Regulation; 8 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

1. ‘HVDC’ means a high voltage direct current network element;
2. ‘Imax’ means the maximum admissible current;
3. ‘LTA’ means the long-term allocated capacity, which is capacity allocated as an outcome of the longterm capacity calculation in the SEE CCR;
4. ‘LTN’ means the long term nominated capacities, which is the long-term nomination of the long-term allocated capacity;
5. ‘MTU’ means a market time unit; the definition for ‘market time’ is provided at Article 2

(15)of the CACM Regulation;

1. ‘NTC’ means the Net Transmission Capacity which is the maximum energy exchange for commercial purposes between adjacent bidding zones for each market time unit in a specific direction;
2. ‘PST’ means a phase-shifting transformer;
3. ‘PTDF’ means power transfer distribution factor
4. ‘RA’ means a remedial action as defined in Article 2

(13)of the CACM Regulation;

1. ‘RAC’ means the RAs coordination;
2. ‘RM’ means the reliability margin as defined in Article 2

(14)of the CACM Regulation;

1. ‘SEE CCR’ means the SEE capacity calculation region as established by the definition of capacity calculation regions pursuant to Article 15 of the CACM Regulation;
2. SEE TSOs are Independent Power Transmission Operator (‘ADMIE’), Electricity System Operator EAD (‘ESO EAD’) and National Power Grid Company Transelectrica S.A. (‘Transelectrica’);
3. ‘SO GL’ means the System Operation Guideline (Commission Regulation (EU) 2017/1485 of 2 August 2017 establishing a guideline on electricity transmission system operation);
4. ‘TTC’ means the Total Transmission Capacity which is the maximum exchange) complying with the operational security limits between adjacent bidding zones for each market time unit in a specific direction.
5. ‘UD’ means the unintended deviation;
6. ‘UN’ means the uncertainties.

(3)In this day-ahead and intraday capacity calculation methodology, unless the context requires otherwise: a. the singular indicates the plural and vice versa; b. headings are inserted for convenience only and do not affect the interpretation of this methodology; and c. any reference to legislation, regulations, directives, orders, instruments, codes or any other enactment shall include any modification, extension or re-enactment of it when in force. Article 3 Application of this methodology

(1)This common capacity calculation methodology solely applies to the day-ahead and intraday common capacity calculation within the SEE CCR. Common capacity calculation methodologies within others capacity calculation regions or for others time-frames are not in scope of this methodology.

(2)This methodology shall also apply to third country TSO(s), if such TSO(

1. s)have signed an agreement with all SEE TSOs that they shall comply with this methodology and accept all the rights and obligations stemming from it. In such case the reference to SEE TSO(
2. s)and SEE CCR in this methodology shall also include such third country TSO(
3. s)9 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management Article 4 Cross-zonal capacities for the day-ahead market

(1)Based on Article 20

(4)of CACM Regulation, for the day-ahead market time-frame, individual values for crosszonal capacity for each day-ahead market time unit shall be calculated using the CNTC approach.

(2)Each TSO of the SEE CCR shall provide the CCC without undue delay the following initial inputs: a. operational security limits and contingencies in accordance with Article 7; b. 𝑅𝑀𝑠 in accordance with Article 6; c. GSKs in accordance with Article 8; and d. RAs in accordance with Article 9.

(3)SEE TSOs, or an entity delegated by the SEE TSOs, shall send for each MTU of the day the LTA and LTN to the CCC, without undue delay. In accordance with article 81 of CACM Regulation, the delegating TSOs in such a case shall remain responsible for ensuring compliance with the obligations under the CACM Regulation.

(4)When providing the inputs, the TSOs of the SEE CCR shall respect the formats commonly agreed between the TSOs and the CCC of the SEE CCR, while respecting the requirements and guidance defined in the CGMM.

(5)The day-ahead capacity calculation is based on the unique D-2 CGM built in accordance with Articles 17 and 28 of CACM Regulation.

(6)For the day-ahead common capacity calculation in the SEE CCR, performed by the CCC, the high-level process flow includes six steps until the final CNTC domain for the day-ahead market time-frame is set: a. first, for the capacity calculation inputs as defined in Article 4

(2)and Article 4

(4)a quality check process shall be performed by the CCC; b. the second process step is to determine the relevant CNECs in accordance with Article 7a used during common capacity calculation; c. the third step is to determine the NTC values for each direction and border of SEE CCR in accordance with Article 11; d. the fourth step is to check if the previously-allocated cross-zonal capacities are fully covered by the NTC values in accordance with Article 11; e. after LTA assessment, the resulting cross-zonal capacities are validated by the TSOs of the SEE CCR; f. finally, the ATC values are calculated for day-ahead market time-frame taking into account the LTN values.

(7)As described before, for each SEE CCR border, direction and market time unit, the final available transmission capacity for the day-ahead market time-frame shall be defined as the difference between the computed NTC values and the already nominated capacities in the previous market time-frames.

(8)In accordance with Article 46 of CACM Regulation, the CCC and TSOs of the SEE CCR shall ensure that crosszonal capacity shall be provided to relevant entities before the day-ahead firmness deadline as defined in accordance with Article 69 of CACM Regulation. Article 5 Cross-zonal capacities for the intraday market 10 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(1)Based on Article 20

(4)of CACM Regulation, for the intraday market time-frame, individual values for crosszonal capacity for each remaining intraday MTU shall be calculated using the CNTC approach.

(2)Each TSO of the SEE CCR shall provide the CCC without undue delay the following initial inputs for the first intraday capacity calculation and subsequent re-calculations of intraday cross-zonal capacity: a. operational security limits and contingencies in accordance with Article 7; b. 𝑅𝑀𝑠 in accordance with Article 6; c. GSKs in accordance with Article 8; and d. RAs in accordance with Article 9.

(3)A first intraday common capacity calculation is performed in the end of D-1 for all MTUs of day D, and a second intraday capacity calculation is performed during intraday (i.e. day D), for the remaining MTUs of day D.

(4)SEE TSOs, or an entity delegated by the SEE TSOs, shall send for each market time unit the AAC and ANC to the coordinated capacity calculator, without undue delay. In accordance with article 81 of CACM Regulation, the delegating TSOs in such a case shall remain responsible for ensuring compliance with the obligations under the CACM Regulation.

(5)When providing the inputs, the TSOs of the SEE CCR shall respect the formats commonly agreed between the TSOs and the coordinated capacity calculators of the SEE CCR, while respecting the requirements and guidance defined in the CGMM.

(6)The capacity calculation is based on the unique D-1 and Intraday CGM built in accordance with Articles 17 and 28 of CACM Regulation.

(7)For the intraday common capacity calculation in the SEE CCR, performed by the CCC, the high-level process flow includes five steps until the final CNTC domain for the intraday market time-frame is set: a. first, for the capacity calculation inputs as defined in Article 4

(2)and Article 4

(4)a quality check process shall be performed by the CCC; b. the second process step is to determine the relevant CNECs in accordance with Article 7a used during common capacity calculation; c. the third step is to determine the NTC values for each direction and border of SEE CCR in accordance with Article 11; d. after NTC values computation, the resulting cross-zonal capacities are validated by the TSOs of the SEE CCR; e. finally, the ATC values are calculated for intraday market time-frame taking into account the ANC values.

(8)As described before, for each SEE CCR border, direction and market time unit, the final available transmission capacity for the intraday market time-frame shall be defined as the difference between the computed NTC values and the already nominated capacities in the previous market time-frames.

(9)Intraday cross-zonal capacity calculation shall be performed in the following sequence, by the time establish in Article 14

(5): a. Updating of cross-zonal capacities remaining after day-ahead CC for all intraday CC MTUs between 00:00 and 24:00 of day D and providing them as intraday cross-zonal capacities to relevant entity no later than 15 minutes before the intraday cross-zonal gate opening time; b. Calculation of intraday cross-zonal capacities for all intraday CC MTUs between 00:00 and 24:00 of day D. The cross-zonal capacities resulting from this calculation shall be published and submitted to relevant entity no later than 15 minutes before the target start of allocation at 22:00 D-1; 11 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management c. Re-calculation of intraday cross-zonal capacities for all intraday CC MTUs between 12:00 and 24:00 of day D. The cross-zonal capacities resulting from this re-calculation shall be published and submitted to NEMOs no later than 15 minutes before the target start of allocation at 10:00 D-1.

(9)The SEE TSOs shall review the frequency of re-calculations no later than one year after the implementation of the common capacity calculation methodology for the intraday market time-frame. Article 6 Reliability margin methodology

(1)The day-ahead and intraday common capacity calculation methodologies are based on forecast models of the transmission system. Therefore, the outcomes are subject to inaccuracies and uncertainties. The aim of the reliability margin is to cover a level of risk induced by these forecast errors.

(2)In accordance with Article 22

(2)and

(4)of the CACM Regulation, the 𝑅𝑀s cover the following forecast uncertainties: a. cross-zonal exchanges on bidding zone borders outside SEE CCR; b. generation pattern including specific wind and solar generation forecast; c. generation shift key; d. load forecast; e. topology forecast; f. unintentional flow deviation due to the operation of frequency containment reserves.

(3)SEE TSOs shall aim at reducing uncertainties by studying and tackling the drivers of uncertainty.

(4)For the capacity calculation performed for day-ahead market time-frame, the TSOs of the SEE CCR shall compute the RMs for the SEE CCR borders in accordance with Article 22 of the CACM Regulation and based on the analysis of the following data: - Unintended deviations of physical electricity flows within a MTU caused by the adjustment of electricity flows within and between control areas, to maintain a constant frequency; - Uncertainties which could affect capacity calculation and which could occur between D-2 and real time, for the MTU being considered.

(5)For the capacity calculation performed for intraday market time-frame, the TSOs of SEE CCR shall compute the RMs for the SEE CCR borders in accordance with Article 22 of the CACM Regulation and based on the analysis of the following data: - Unintended deviations of physical electricity flows within a MTU caused by the adjustment of electricity flows within and between control areas, to maintain a constant frequency; - Uncertainties which could affect capacity calculation and which could occur between the respective capacity calculation time and real time, for the MTU being considered.

(6)Regarding the UD for control-related reasons, deviations occur between the scheduled values and the actual values during the exchange of energy between neighboring control areas. This implies that at any moment the exchange between two control areas can be significantly higher than the scheduled exchanged, endangering the security of supply.

(7)Regarding the UN the CNTC methodology is based on different inputs provided by TSOs, they are based on best available forecast at the time of the capacity calculation for renewable energy sources, consumption, generation or available network elements and those could differ from the real-time situation.

(8)The RMs can be considered as an indirect input to the capacity calculation process since it refers to the 12 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management difference when the TTC and the NTC limits are reached for the constraint under investigation.

(9)The RMs determination is based on a probability distribution function of the deviations between the expected power flows at the time of the capacity calculation and realized power flows in real time.

(10)The RMs on the north Greek borders and south Romanian borders are calculated in a three-step approach: a. In a first step, for each MTU of the observatory period, the power flow on the north Greek borders and south Romanian borders, as expected at the time of capacity calculation is compared with the real time power flow observed on the same borders. All differences for all MTUs of a one-year observation period shall constitute the probability distribution function of deviations between the expected flows at the time of capacity calculation and realized flows in real time. The impact on the capacity shall be defined with the following equation: 𝐹𝑒𝑟𝑟 = 𝐹𝑟𝑒𝑎𝑙 − 𝐹𝐶𝐺𝑀 with 𝐹𝑒𝑟𝑟 𝐹𝑟𝑒𝑎𝑙 𝐹𝐶𝐺𝑀 Active power flow error due to UD and UN; Active power flow through the border in real time; Active power flow through the border in the relevant CGM; b. in a second step and in accordance with Article 22

(3)of the CACM Regulation the 95th percentiles of the probability distributions for the north Greek borders and south Romanian borders shall be calculated. This means that the TSOs apply a common risk level of 5% and thereby the RM values cover 95% of the historical forecast errors within the observation period. c. a possible third step could be to undertake an operational adjustment on the values derived previously, by modifying the computed RM values to a value within the range which will retain system security between 1% and 20% of the TTC calculated under normal weather conditions.

(11)The TSOs of the SEE CCR shall store for an unlimited period of time the differences between the realized and expected SEE CCR power flow in a database for statistical analyses. The probability distribution function and reliability margin values shall be stored for an unlimited period of time for further evaluation.

(12)The RM values shall be updated every year (including the risk level) in accordance with Article 15, based upon an observatory period of one year such that seasonal effects can be reflected in the values. The RMs values remain fixed until the next update.

(13)For the day-ahead common capacity calculation, the RMs for the north Greek borders and south Romanian borders shall be implemented 3 months after collecting 1 year of data since the day-ahead capacity calculation go-live.

(14)For the intraday common capacity calculation, the RMs for the north Greek borders and south Romanian borders shall be implemented 3 months after collecting 1 year of data since the intraday capacity calculation go-live.

(15)Before the first operational calculation of the RMs values, SEE CCR TSOs shall use the RM values already in operation in the existing capacity calculation initiatives. The RMs before the first operational calculation for the north Greek borders shall be 400 MW for each direction and for the south Romanian borders shall be 200 MW for each direction. Article 7 Methodologies for operational security limits, contingencies and allocation constraints 13 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(1)Each TSO of the SEE CCR shall define a list of proposed CNEs, which could be fully or partly located in its own control area. The list of CNEs shall be provided to the CCC, who shall monitor the CNEs during the coordinated NTC calculation process. This list shall be updated at least on a yearly basis and in case of topology changes (commissioning of new grid elements in the observability area of each TSO) in accordance with Article 15. A CNE is a network element, significantly impacted by SEE cross-zonal trades, which are supervised under certain operational conditions, the so-called contingencies. A CNE can be a cross zonal element or an internal network element. Those elements can be an overhead line, an underground cable, or a transformer.

(2)Each TSO of the SEE CCR shall define a list of proposed contingencies used in operational security analysis in accordance with Article 33 of the SO GL, limited to their relevance for the set of CNEs as defined in Article 7

(1)and pursuant to Article 23

(2)of the CACM Regulation. The contingencies of a TSO shall be located within the observability area of that TSO. This list shall be updated at least on a yearly basis and in case of topology changes in the grid of the TSOs (commissioning of new grid elements in the observability area of each TSO) in accordance with Article 15. A contingency can be an unplanned outage of: • a line, a cable, or a transformer; • a busbar; • a generating unit; • a load; or • a set of the aforementioned contingencies.

(3)Each TSO form the SEE CCR shall associate the contingencies established pursuant to Article 7

(2)with the CNEs established pursuant to Article 7

(1)following the rules established in accordance with Article 75 of SO GL. Until such rules are established and enter into force, the association of contingencies to CNEs shall be based on each TSO’s operational practise.

(4)Each TSO of the SEE CCR shall provide to the CCC a list of the proposed CNECs. The CCC shall merge the list of CNECs provided by all SEE CCR TSOs into a single list, which shall constitute the initial list of CNECs.

(5)In accordance with Article 23

(1)of the CACM Regulation, SEE TSOs shall respect the operational security limits used in operational security analysis carried out in line with Article 72 of the SO GL. The operational security limits used in the common capacity calculation are the same as those used in operational security analysis, therefore any additional descriptions pursuant to Article 23

(2)of the CACM Regulation are not needed. In particular: a. SEE TSOs shall respect the maximum admissible current limit (𝐼𝑚𝑎𝑥 ) which is the physical limit of a CNE according to the operational security policy in accordance with Article 25 of the SO GL. The maximum admissible current can be defined with: i. fixed limits for all MTUs of each of the four seasons; ii. fixed limits for all MTUs in the case of transformers and certain types of conductors which are not sensitive to ambient conditions; iii. fixed limits for all MTUs, in case of specific situations where the physical limit reflects the capability of substation equipment (such as circuit-breaker, current transformer, or disconnector). b. when applicable, 𝐼𝑚𝑎𝑥 shall be defined as a temporary current limit of the CNE in accordance with Article 25 of the SO GL. A temporary current limit means that an overload is only allowed for a certain finite duration. 14 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management c. 𝐼𝑚𝑎𝑥 shall represent only real physical properties of the CNE and shall not be reduced by any security margin, as all uncertainties in the common capacity calculation are covered on each CNEC by the reliability margin (𝑅𝑀) in accordance with Article 6.

(6)SEE TSOs shall not apply allocation constraints.

(7)SEE TSOs shall review and update the application of the methodologies for determining operational security limits, list of CNEs and the list of CNECs, respectively, contingencies on a yearly basis in accordance with Article 15. Article 7a Rules for avoiding undue discrimination between internal and cross-zonal exchanges

(1)In accordance with Article 21

(1)(b)(iv) of the CACM Regulation, this day-ahead and intraday common capacity calculation methodology shall describe the rules to mitigate possible discrimination between the treatment of internal and cross-zonal transactions, in response to Article 21

(1)(b)(

1. ii)of the CACM Regulation and Article 1.7 of Annex I to the Regulation (EC) 714/2009 and in line with Article 3(a), 3(
2. b)and 3(
3. e)of the CACM Regulation.

(2)The TSOs of SEE CCR shall monitor only the elements from initial list of CNECs significantly impacted by cross-zonal power exchange. The CCC shall calculate the sensitivity factors for selecting the CNECs that are significantly impacted by cross-zonal power exchange.

(3)The sensitivity factors calculated as a percentage using the relevant CGM and GSK are defined as follow: 𝑃𝑓 − 𝑃𝑖 𝑆𝐸𝐹𝐶𝑁𝐸𝐶 = × 100 ΔP with 𝑆𝐸𝐹𝐶𝑁𝐸𝐶 𝑃𝑓 𝑃𝑖 ΔP Sensitivity factor for CNEC; CNEC active power flow after ΔP; CNEC active power flow based on the relevant CGM; Increase of the exchange with 100 MW through the north Greek borders, respectively south Romania borders.

(4)SEE CCR cross-zonal network elements are by definition considered to be significantly impacted. The other CNECs from initial list shall have a sensitivity factor equal or higher than 5% to be taken into account in all of the steps of the common capacity calculation to determine the cross-zonal capacity.

(5)In an exceptional situation, such as extreme weather conditions, untypical flow conditions or topology or grid situation, a TSO may decide to modify the CNEC list defined in accordance with Article 7a

(4)for one or several MTUs covering the expected period of presence of the exceptional situation. a. In case a TSO decides, in an exceptional situation, to use a CNEC or node which is not significantly influenced by the changes in bidding zone net positions, the respective TSO shall inform SEE national regulatory authorities without undue delay and provide a clear description of the specific situation providing detailed information such as the specific topology or grid situation that led to this decision; b. In case a TSO decides, in an exceptional situation, to exclude a CNEC or node which is significantly influenced by the changes in bidding zone net positions, the respective TSO shall inform SEE national regulatory authorities without undue delay and provide a clear description of the specific situation providing detailed information such as the specific topological or grid situation that led to this decision. 15 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(6)The TSOs shall investigate whether a higher sensitivity threshold could be taken into account while guarantying security of supply, as a mid-term measure. A study shall be provided to the relevant regulatory authorities in 3 months after collecting 1 year of data since the day-ahead capacity calculation go-live.

(7)The TSOs shall consider efficient investments, as a long-term measure. Article 8 Generation shift keys methodology

(1)Each SEE TSO shall define for its bidding zone and for each MTU a GSK, which translates a change in a bidding zone net position into a specific change of injection or withdrawal in the CGM. This expectation shall be based on the observed historical response of generation units to changes in net positions, clearing prices and other fundamental factors, and thereby contributing to minimizing the RM.

(2)In accordance with Article 24 of the CACM Regulation, SEE TSOs developed the following methodology to determine the common generation shift key: a. SEE TSOs shall take into account the available information on generation available in the common grid model for each scenario developed in accordance with Article 18 of the CACM Regulation in order to select the nodes that will contribute to the GSK; b. SEE TSOs shall aim to apply a GSK that resembles the dispatch and the corresponding flow pattern, thereby contributing to minimizing the reliability margins; c. SEE TSOs shall define a constant generation shift key per market time unit.

(3)For the application of the methodology, SEE TSOs shall define, for the capacity calculation process, GSKs impacted by the actual generation present in the relevant CGM, for each MTU. SEE TSOs shall take into account the available information on generation available in the CGM in order to select the nodes that will contribute to the GSK.

(4)SEE TSOs have harmonized their GSK determination methodologies: a. In its GSK, each TSO shall use flexible and controllable production units which are available inside the TSO grid; b. Units unavailable due to outage or maintenance are not included; c. GSK is reviewed on a daily basis or whenever there are changes in the expectations referred to in paragraph

(1).

(5)For the Greek bidding zone a proportional representation of the generation variation to the remaining capacity, based on ADMIE’s best estimate of the initial generation profile, ensure the best modeling of the Greek system.

(6)For the Bulgarian bidding zone a proportional representation of the generation variation to the remaining capacity respecting the limits of the generating units, based on ESO EAD’s best estimate of the initial generation profile, ensure the best modeling of the Bulgarian system. The nuclear units are not included in the list.

(7)The Transelectrica GSK file contains dispatchable units which are available in the day of operation. The nuclear units are not included in the list. The fixed participation factors of GSK are impacted by the actual generation present in the relevant CGM.

(8)With the above GSKs, the SEE TSOs consider that the prediction error, between the forecasted and observed flows for all production units in each bidding zone for the day ahead and intraday time frame will be minimized. At the above GSKs, non-flexible production units, such as the nuclear production units are not included at the 16 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management generation shift.

(9)The GSKs shall be provided to the CCC to be used in the capacity calculation for each bidding zone and also the MTUs for which the GSKs shall be valid. The SEE TSOs shall make ex-post analysis of GSK regularly and if considered necessary request to change it.

(10)SEE TSOs shall review and update the application of the generation shift keys methodology, on a yearly basis in accordance with Article 15. Article 9 Methodology for remedial actions in capacity calculation

(1)In accordance with Article 25

(1)of the CACM Regulation and Article 20

(2)of SO GL, SEE TSOs shall individually define RAs to be taken into account in the day-ahead and intraday common capacity calculation. The relevant RAs shall be coordinated between TSOs, clearly described, and communicated to other TSOs and the CCC.

(2)Each TSO of SEE CCR shall inform the CCC in a timely manner on any change in its RAs within SEE CCR to ensure an efficient capacity calculation. The CCC which receives the RAs from the TSOs coordinates the process and either proposes the initial recommendations from the TSOs or develops new proposals for the TSOs.

(3)In accordance with Article 25

(2)and

(3)of the CACM Regulation, these RAs will be used in calculation of cross-zonal capacities while ensuring operational security in real time.

(4)In accordance with Article 25

(4)of the CACM Regulation, a TSO may refrain from considering a particular RA in capacity calculation in order to ensure that the remaining RAs are sufficient to ensure operational security. The CCC shall monitor and report in the annual report on systematic withholdings which were not essential to ensure operational security in real-time operation.

(5)All TSOs of the SEE CCR shall provide to the CCC all available RAs, and for the purpose of capacity validation all TSOs of the SEE CCR shall provide to the CCC all expected RAs.

(6)The RAs defined by each SEE TSOs shall be either preventive (pre-fault) or curative (post-fault), i.e. affecting all CNECs or only pre-defined contingency cases, respectively. The SEE TSOs may use the following noncostly RAs, but are not limited to: a. changing the tap position of a PST, b. topological action: opening or closing of one or more line(s), cable(s), transformer(s), bus bar coupler(s), or switching of one or more network element(s) from one bus bar to another, connection/disconnection of reactor(s), capacitor(s). c. Exception to the general rule: The activation of a post-fault RA could be treated as non-costly action, when it is agreed after negotiation among the relevant TSOs.

(7)In accordance with Article 25

(6)of the CACM Regulation, the RAs taken into account are the same for dayahead and intra-day common capacity calculation, depending on their technical availability.

(8)The RAC in the day-ahead and intraday common capacity calculation shall be an automated, coordinated, and repeatable optimization process performed by the CCC. The CCC shall take into account in capacity calculation RAs to increase the cross-zonal capacity. After calculation the maximum power exchanges between bidding 17 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management zones without RAs, necessary adjustment taking into account RAs are executed in the CGM and maximum power exchanges between bidding zones taking into account RAs shall be recalculated.

(9)The RAC consists of the following objective function, constraints and variables: a. The RAC objective is to enlarge the capacity domain around the balanced net position of the Common Grid Model Alignment process, with the objective function to minimize the overload of the CNECs and/or the violation of the nodes voltage; b. The constraints are the operational security limits in accordance with Article 7, minimum impact on objective function value for use RAs and without negative impact on the TTC values calculated according with Article 11. c. The variables are the switching states of the topological measures and tap positions

(10)In case a RA is made available for the capacity calculation in the SEE CCR is also one which is made available in another CCR, the TSOs taking control of the RA shall take care, when defining it, of a consistent use in its potential application in both regions to ensure operational security. An exchange of foreseen RAs in each CCR, with sufficient impact on the cross-zonal capacity in other CCRs, shall be coordinated among CCCs. The SEE CCC shall take this information into account for the coordinated application of RAs in the SEE CCR.

(11)In accordance with Article 21

(1)(b)(iv) of the CACM Regulation, at this day-ahead and intraday common capacity calculation methodology: a. an exchange of foreseen remedial actions in each CCR, with sufficient impact on the cross-zonal capacity in other CCRs, should be coordinated among CCCs. b. the coordinated application of RAs shall aim at increasing cross-zonal capacity in the SEE CCR in accordance with Article 29

(4)of the CACM Regulation; c. the applied RAs should be transparent to all TSOs, also of adjacent CCRs, and shall be an input to the coordinated operational security analysis established under SO GL Article 75.

(12)SEE TSOs shall review and update remedial actions taken into account in capacity calculation, on a yearly basis in accordance with Article 15. Article 10 Cross-zonal capacity validation methodology

(1)Each TSO of the SEE CCR shall, in accordance with Article 26

(1)and 26

(3)of the CACM Regulation, validate and have the right to correct cross-zonal capacity relevant to the TSO’s bidding zone borders for reasons of operational security during the validation process. In exceptional situations cross-zonal capacities can be decreased by TSOs. These situations are: a. an occurrence of an exceptional contingency or forced outage pursuant to Article 3 of SO GL; b. when all available costly and non-costly RAs, that are needed to ensure the calculated capacity, are not sufficient to ensure operational security; c. extremely low demand of a TSO which leads to low system inertia and high voltage conditions and so require a minimum number of power plants on the grid; d. a mistake in input data, that leads to an overestimation of cross-zonal capacity from an operational security perspective.

(2)Capacity validation shall consist of two steps. In the first step, the SEE TSOs shall analyse in a coordinated manner whether the cross-zonal capacity (i.e. 𝑁𝑇𝐶𝑎𝑑𝑗 ) could violate operational security limits, and whether they have sufficient RAs to avoid such violations. In the second step, each SEE TSOs shall individually analyse whether the cross-zonal capacity could violate operational security in its own control area. 18 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(3)In the first step, the CCC in coordination with all SEE TSOs shall validate the 𝑁𝑇𝐶𝑎𝑑𝑗 . In this process they shall exchange information on all expected available (non-costly and costly) RAs in the SEE CCR, defined in accordance with Article 22 of the SO Regulation. In case the 𝑁𝑇𝐶𝑎𝑑𝑗 on CNECs could lead to violation of operational security, all SEE TSOs in coordination with the CCC shall verify whether such violation can be avoided with the application of RAs. For those CNECs where all available RAs are not sufficient to avoid the violation of operational security, the SEE TSOs in coordination with the CCC may reduce the 𝑁𝑇𝐶𝑎𝑑𝑗 to the maximum value which avoids the violation of operational security. This reduction of the 𝑁𝑇𝐶𝑎𝑑𝑗 is called coordinated validation adjustment (CVA) and the adjusted NTC is called NTC after coordinated validation.

(4)After coordinated validation, each SEE TSO shall validate and have the right to decrease the NTC for reasons of operational security during the individual validation. The adjustment due to individual validation is called individual validation adjustment (IVA) and may reduce the NTC only to the minimum degree that is needed to ensure operational security considering all expected available costly and non-costly RAs, in accordance with Article 22 of the SO Regulation.

(5)When performing the validation, SEE TSOs may consider the operational security limits pursuant to Article 7. When considering such limits, they may consider additional grid models, and/or other relevant information from the real time situation. Therefore, SEE TSOs shall use tools developed by the CCC for analysis, but may also employ verification tools not available to the CCC.

(6)After coordinated and individual validation adjustments, the final NTC (𝑁𝑇𝐶𝑓𝑖𝑛𝑎𝑙 ) shall be calculated by CCC according to the following equation: 𝑁𝑇𝐶𝑓𝑖𝑛𝑎𝑙 = 𝑁𝑇𝐶𝑎𝑑𝑗 − 𝐶𝑉𝐴 − 𝐼𝑉𝐴

(7)When one or more SEE TSOs do not validate the calculated cross-zonal capacity, the concerned TSO(s) shall provide the CCC the reasons for the reduction. The final cross-zonal capacity is the minimum value set by the SEE TSOs of the considered border.

(8)Any reduction of cross-zonal capacities during the validation process shall be communicated and justified to market participants and to the SEE national regulatory authorities. The CCC shall issue a quarterly report to regulatory authorities that shall include the amount of reduction in cross-zonal capacity and reason for reduction, pursuant to Article 26

(5)of CACM. In cases of reduction the report shall include information for each bidding zone border and direction affected by a reduction and for each MTU (i.e. the identification of the border and direction; the volume of reduction; detailed reasons for reduction, including the security constraint violated, and under which circumstances it was violated; the before and after the contingency values for the NTC; the RAs included in CGM before capacity calculation; in case of reduction due to individual validation, the TSO invoking the reduction) and the proposed measures to avoid similar reductions in the future. The report shall also include at least the following aggregate information: statistics on the number, causes, volume and estimated loss of economic surplus of applied of reductions by different TSOs and general measures to avoid capacity reduction in the future.

(9)When a given SEE TSO reduced capacity for its border in more than 1% of MTUs of analyzed quarter, the concerned TSO shall provide to CCC a detailed report and action plan describing how such deviations are expected to be alleviated and solved in the future. This report and action plan shall be included as an annex to the quarterly report.

(10)The CCC shall coordinate with neighboring CCCs during the validation process, where at least the reductions in cross-zonal capacity are shared among them. Any information on decreased cross-zonal capacity from neighboring CCCs shall be provided to SEE TSOs. 19 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management Article 11 Mathematical description of the day-ahead and intraday capacity calculation approach

(1)The CNTC computation is a centralized calculation based on AC load flow which delivers the main parameter needed for the definition of CNTC domain: TTC. The TTC represent the maximum power exchange on a bidding zone border and calculation shall according to the following procedure: (

1. a)use the common grid model, generation shift keys, and list of CNECs defined in accordance with Article 7a to calculate maximum power exchange on bidding zone borders, which shall equal the maximum calculated exchange between two bidding zones on either side of the bidding zone border respecting operational security limits; (
2. b)adjust maximum power exchange using remedial actions in accordance with Article 9.

(2)The CCC shall define the values of TTC for each MTU for the north Greek borders and south Romanian borders.

(3)The NTC values for the north Greek borders and south Romanian borders are determined with the following equations: 𝑁𝑇𝐶𝑛𝑜𝑟𝑡ℎ 𝐺𝑟𝑒𝑒𝑘 𝑏𝑜𝑟𝑑𝑒𝑟𝑠 = 𝑇𝑇𝐶𝑛𝑜𝑟𝑡ℎ 𝐺𝑟𝑒𝑒𝑘 𝑏𝑜𝑟𝑑𝑒𝑟𝑠 − 𝑅𝑀𝑛𝑜𝑟𝑡ℎ 𝐺𝑟𝑒𝑒𝑘 𝑏𝑜𝑟𝑑𝑒𝑟𝑠 𝑁𝑇𝐶𝑠𝑜𝑢𝑡ℎ 𝑅𝑜𝑚𝑎𝑛𝑖𝑎𝑛 𝑏𝑜𝑟𝑑𝑒𝑟𝑠 = 𝑇𝑇𝐶𝑠𝑜𝑢𝑡ℎ 𝑅𝑜𝑚𝑎𝑛𝑖𝑎𝑛 𝑏𝑜𝑟𝑑𝑒𝑟𝑠 − 𝑅𝑀𝑠𝑜𝑢𝑡ℎ 𝑅𝑜𝑚𝑎𝑛𝑖𝑎𝑛 𝑏𝑜𝑟𝑑𝑒𝑟𝑠

(4)The splitting factor used for day-ahead and intraday capacity calculation in the year Y will be based on the NTC values from the last two calendar years before the implementation of the methodology. This approach is based on the Article 3(

1. h)of the CACM Regulation that contributes to the objective of respecting the need for a fair and orderly market and price formation and ensures a fair distribution of costs and benefits between the involved TSOs. Moreover, the approach is in line with the distribution of the congestion income (as defined in the Article 73 of CACM Regulation and Article 57 of FCA Regulation) collected by the TSOs, and thus do not alter the signals for investments to TSOs given by the congestion income. The splitting factors used at the NTC computation will comply with the security operation in accordance with Article 3(
2. c)of the CACM Regulation, will not alter the signals for investments to TSOs given by the congestion income and allow reasonable financial planning according with Article 73 of the CACM Regulation. TSOs can amend the splitting factors with values other than described above with justification to NRAs (for example when new tie lines will be in operation, when market and system conditions justify changes after agreement of all concerned TSOs).

(5)The splitting factor for BG-GR direction is determined with the following equation: 𝑆𝐹𝐵𝐺−𝐺𝑅 = 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 /𝑁𝑇𝐶𝑛𝑜𝑟𝑡ℎ 𝐺𝑅 𝑠𝑦𝑠𝑡𝑒𝑚𝑠−𝐺𝑅 where: 𝑆𝐹𝐵𝐺−𝐺𝑅 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 𝑁𝑇𝐶𝑛𝑜𝑟𝑡ℎ 𝐺𝑅 𝑠𝑦𝑠𝑡𝑒𝑚𝑠−𝐺𝑅 splitting factor as percentage to be applied for BG-GR direction for day-ahead and intraday capacity calculation in the year Y Average value of the NTC for the direction BG-GR in the last two years before the implementation of the methodology Average value of the total NTC for the direction north GR systems -GR in the last two years before the implementation of the methodology

(6)The splitting factor for GR-BG direction is determined with the following equation: 𝑆𝐹𝐺𝑅−𝐵𝐺 = 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 /𝑁𝑇𝐶𝐺𝑅−𝑛𝑜𝑟𝑡ℎ 𝐺𝑅 𝑠𝑦𝑠𝑡𝑒𝑚𝑠 where: 𝑆𝐹𝐺𝑅−𝐵𝐺 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 splitting factor as percentage to be applied for GR-BG direction for day-ahead and intraday capacity calculation in the year Y Average value of the NTC for the direction GR-BG in the last two years before the implementation of the methodology 20 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management 𝑁𝑇𝐶𝐺𝑅−𝑛𝑜𝑟𝑡ℎ 𝐺𝑅 𝑠𝑦𝑠𝑡𝑒𝑚𝑠 Average value of the total NTC for the direction GR-north GR systems in the last two years before the implementation of the methodology

(7)The splitting factor for BG-RO direction is determined with the following equation: 𝑆𝐹𝐵𝐺−𝑅𝑂 = 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 /𝑁𝑇𝐶𝑠𝑜𝑢𝑡ℎ 𝑅𝑂 𝑠𝑦𝑠𝑡𝑒𝑚𝑠−𝑅𝑂 where: 𝑆𝐹𝐵𝐺−𝑅𝑂 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 𝑁𝑇𝐶𝑠𝑜𝑢𝑡ℎ 𝑅𝑂 𝑠𝑦𝑠𝑡𝑒𝑚𝑠−𝑅𝑂 splitting factor as percentage to be applied for BG-RO direction for day-ahead and intraday capacity calculation in the year Y Average value of the NTC for the direction BG-RO in the last two years before the implementation of the methodology Average value of the total NTC for the direction south RO systems-RO in the last two years before the implementation of the methodology

(8)The splitting factor for RO-BG direction is determined with the following equation: 𝑆𝐹𝑅𝑂−𝐵𝐺 = 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 /𝑁𝑇𝐶𝑅𝑂−𝑠𝑜𝑢𝑡ℎ 𝑅𝑂 𝑠𝑦𝑠𝑡𝑒𝑚𝑠 where: 𝑆𝐹𝑅𝑂−𝐵𝐺 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 𝑁𝑇𝐶𝑅𝑂−𝑠𝑜𝑢𝑡ℎ 𝑅𝑂 𝑠𝑦𝑠𝑡𝑒𝑚𝑠 splitting factor as percentage to be applied for RO-BG direction for day-ahead and intraday capacity calculation in the year Y Average value of the NTC for the direction RO-BG in the last two years before the implementation of the methodology Average value of the total NTC for the direction RO-south RO systems in the last two years before the implementation of the methodology

(9)The CCC of the SEE CCR shall provide to the SEE TSOs with the validated NTCs values after application of the RMs defined in accordance with Article 6 for the BG-RO and BG-GR borders.

(10)In accordance with Article 16

(8), of the Regulation (EU) 2019/943, SEE TSOs shall monitor the margin available for cross-zonal trade in the day-ahead capacity calculation.

(11)The coordinated capacity calculator shall ensure that the computed NTC reaches the minimum capacity requirements according to Article 16

(8)of the Regulation (EU) 2019/43, using remedial actions committed by the SEE TSOs or possibly proposed by CCC. In accordance with article 16

(3)of the Regulation (EU) 2019/43, where the available remedial actions are not sufficient to reach the above-mentioned minimum capacities while respecting the operational security limits, the coordinated capacity calculator may, as a measure of last resort, set out coordinated actions reducing the cross-zonal capacities accordingly.

(12)The minimum capacity shall be 70% of the transmission capacity respecting operational security limits after deduction of contingencies, except for those for which a derogation has been granted or an action plan to address structural congestions has been set in accordance with Articles 15 and 16 of the Regulation (EU) 2019/943. SEE TSOs affected by such derogations or action plans shall inform all the NRAs of the SEE CCR about the values of minimum capacity (if any) applicable during the period covered by the derogation or the action plan.

(13)The minimum level of capacity, as set in the article 16

(8)of the Regulation (EU) 2019/943, is translated on the margin on a limiting CNEC. The margin on a limiting CNEC is computed for each hour as follows: 𝑀𝑎𝑟𝑔𝑖𝑛 = ∑ 𝑝𝑃𝑇𝐷𝐹𝑖,𝑧2𝑧,𝑏 𝑆𝐹𝑏 𝑁𝑇𝐶 + ∑ 𝑃𝑇𝐷𝐹𝑧2𝑧 𝐶𝐺𝑀𝐸𝑛 𝑏 𝑛 where: 𝑏 Oriented bidding-zone border which belongs to the coordination area 21 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management 𝑝𝑃𝑇𝐷𝐹𝑧2𝑧,𝑏 = max (0, 𝑃𝑇𝐷𝐹𝑧2𝑧,𝑏 ) 𝑁𝑇𝐶 𝑆𝐹𝑏 𝑛 𝑃𝑇𝐷𝐹𝑧2𝑧,𝑛 𝐶𝐺𝑀𝐸𝑛 Positive zone-to-zone PTDF associated with the oriented bidding-zone border b (0 for a negative zone-to-zone PTDF) Net transfer capacity computed for all the North Greek Borders and South Romanian Borders Splitting Factor for the oriented bidding zone border b in the computed direction Oriented bidding-zone border, which does not belong to the coordination area (Positive or negative) zone-to-zone PTDF associated with the oriented bidding-zone border n CGM forecast of the net exchange on the oriented bidding-zone border n. If the margin of a limiting CNEC is below the minimum margin, an additional net transfer capacity 𝐴𝑁𝑇𝐶𝑖 is computed to reach the minimum margin: 𝐴𝑁𝑇𝐶𝑖 = 𝐴𝑁𝑇𝐶𝑖 𝑚𝑖𝑛𝑀𝑎𝑟𝑔𝑖𝑛 𝑚𝑖𝑛𝑀𝑎𝑟𝑔𝑖𝑛 − 𝑀𝑎𝑟𝑔𝑖𝑛 ∑𝑏∈𝑐𝑜𝑜𝑟𝑑𝑖𝑛𝑎𝑡𝑖𝑜𝑛 𝑎𝑟𝑒𝑎∩𝑐𝑜𝑚𝑝𝑢𝑡𝑒𝑑 𝑑𝑖𝑟𝑒𝑐𝑡𝑖𝑜𝑛 𝑝𝑃𝑇𝐷𝐹𝑧2𝑧,𝑏 ∗ 𝑆𝐹𝑏 Additional net transfer capacity related to CNEC i Minimum Margin Available for Cross-Zonal Trade If the margin of a limiting CNEC is equal or above the minimum margin, the additional net transfer capacity associated to that CNEC is equal to 0. The adjusted net transfer capacity ANTC for all the North Greek and South Romanian borders is then equal to: 𝑁𝑇𝐶𝑎𝑑𝑗 = 𝑁𝑇𝐶𝑖𝑛𝑖𝑡𝑖𝑎𝑙 + 𝐴𝑁𝑇𝐶 where 𝑁𝑇𝐶𝑖𝑛𝑖𝑡𝑖𝑎𝑙 is the total NTC value on the North Greek borders/South Romanian borders for either imports or exports respectively as evaluated from the section

(3)of this article. For the individual borders (i) of the North Greek and South Romanian borders, the adjusted net transfer capacity is given by the following equation. 𝑁𝑇𝐶𝑎𝑑𝑗,𝑖 = 𝑆𝐹𝑖 ∗ 𝑁𝑇𝐶𝑎𝑑𝑗 where 𝑆𝐹𝑖 is the splitting factor for the concerned border. For the BG-GR and BG-RO borders the following equations shall apply respectively, according to Article 10

(6), in order to calculate the final NTC values for each border and direction. 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 = 𝑁𝑇𝐶𝑎𝑑𝑗,𝐵𝐺−𝐺𝑅 − 𝐶𝑉𝐴 − 𝐼𝑉𝐴 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 = 𝑁𝑇𝐶𝑎𝑑𝑗,𝐺𝑅−𝐵𝐺 − 𝐶𝑉𝐴 − 𝐼𝑉𝐴 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 = 𝑁𝑇𝐶𝑎𝑑𝑗,𝐵𝐺−𝑅𝑂 − 𝐶𝑉𝐴 − 𝐼𝑉𝐴 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 = 𝑁𝑇𝐶𝑎𝑑𝑗,𝑅𝑂−𝐵𝐺 − 𝐶𝑉𝐴 − 𝐼𝑉𝐴

(14)In accordance with Article 21

(1)(b)(iii) of the CACM Regulation, SEE TSOs shall apply the rules for taking into account the previously-allocated cross-zonal capacity. The objective of the rules is to verify that the ATC 22 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management value of each border and direction of the SEE CCR remains non-negative in case of previously-allocated commercial capacity.

(15)The ATC taking into consideration the AACs is determined with the following equations in case of BG – GR border: 𝐴𝑇𝐶𝐵𝐺−𝐺𝑅 = 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 − 𝐴𝐴𝐶𝐵𝐺−𝐺𝑅 + 𝐴𝐴𝐶𝐺𝑅−𝐵𝐺 𝐴𝑇𝐶𝐺𝑅−𝐵𝐺 = 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 − 𝐴𝐴𝐶𝐺𝑅−𝐵𝐺 + 𝐴𝐴𝐶𝐵𝐺−𝐺𝑅 with 𝐴𝑇𝐶𝐵𝐺−𝐺𝑅 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 𝐴𝐴𝐶𝐵𝐺−𝐺𝑅 𝐴𝐴𝐶𝐺𝑅−𝐵𝐺 𝐴𝑇𝐶𝐺𝑅−𝐵𝐺 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 ATC on the BG-GR direction NTC on the BG-GR direction AAC on the BG-GR direction AAC on the GR-BG direction ATC on the GR-BG direction NTC on the GR-BG direction

(16)The ATC taking into consideration the AACs is determined with the following equations in case of BG – RO border: 𝐴𝑇𝐶𝐵𝐺−𝑅𝑂 = 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 − 𝐴𝐴𝐶𝐵𝐺−𝑅𝑂 + 𝐴𝐴𝐶𝑅𝑂−𝐵𝐺 𝐴𝑇𝐶𝑅𝑂−𝐵𝐺 = 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 − 𝐴𝐴𝐶𝑅𝑂−𝐵𝐺 + 𝐴𝐴𝐶𝐵𝐺−𝑅𝑂 with 𝐴𝑇𝐶𝐵𝐺−𝑅𝑂 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 𝐴𝐴𝐶𝐵𝐺−𝑅𝑂 𝐴𝐴𝐶𝑅𝑂−𝐵𝐺 𝐴𝑇𝐶𝑅𝑂−𝐵𝐺 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 ATC on the BG-RO direction NTC on the BG-RO direction AAC on the BG-RO direction AAC on the RO-BG direction ATC on the RO-BG direction NTC on the RO-BG direction

(17)The ATC for day-ahead market time-frame and also for the intraday market time-frame is determined with the following equations in case of BG – GR border, taking into account the NTC values calculated before and ANC: 𝐴𝑇𝐶𝐵𝐺−𝐺𝑅 = 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 − 𝐴𝑁𝐶𝐵𝐺−𝐺𝑅 + 𝐴𝑁𝐶𝐺𝑅−𝐵𝐺 𝐴𝑇𝐶𝐺𝑅−𝐵𝐺 = 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 − 𝐴𝑁𝐶𝐺𝑅−𝐵𝐺 + 𝐴𝑁𝐶𝐵𝐺−𝐺𝑅 with 𝐴𝑇𝐶𝐵𝐺−𝐺𝑅 𝑁𝑇𝐶𝐵𝐺−𝐺𝑅 𝐴𝑁𝐶𝐵𝐺−𝐺𝑅 𝐴𝑁𝐶𝐺𝑅−𝐵𝐺 𝐴𝑇𝐶𝐺𝑅−𝐵𝐺 𝑁𝑇𝐶𝐺𝑅−𝐵𝐺 ATC on the BG-GR direction NTC on the BG-GR direction ANC on the BG-GR direction ANC on the GR-BG direction ATC on the GR-BG direction NTC on the GR-BG direction

(18)The ATC for day-ahead market time-frame and also for the intraday market time-frame is determined with the following equations in case of BG – RO border, taking into account the NTC values calculated before and ANC: 𝐴𝑇𝐶𝐵𝐺−𝑅𝑂 = 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 − 𝐴𝑁𝐶𝐵𝐺−𝑅𝑂 + 𝐴𝑁𝐶𝑅𝑂−𝐵𝐺 𝐴𝑇𝐶𝑅𝑂−𝐵𝐺 = 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 − 𝐴𝑁𝐶𝑅𝑂−𝐵𝐺 + 𝐴𝑁𝐶𝐵𝐺−𝑅𝑂 with 𝐴𝑇𝐶𝐵𝐺−𝑅𝑂 ATC on the BG-RO direction 23 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management 𝑁𝑇𝐶𝐵𝐺−𝑅𝑂 𝐴𝑁𝐶𝐵𝐺−𝑅𝑂 𝐴𝑁𝐶𝑅𝑂−𝐵𝐺 𝐴𝑇𝐶𝑅𝑂−𝐵𝐺 𝑁𝑇𝐶𝑅𝑂−𝐵𝐺 NTC on the BG-RO direction ANC on the BG-RO direction ANC on the RO-BG direction ATC on the RO-BG direction NTC on the RO-BG direction

(19)If the ATC values calculated according with Article 11

(17)and Article 11

(18)are negative, no capacity will be made available for day-ahead, respectively intraday market time-frame.

(20)In accordance with Article 46 of CACM regulation, the CCC and TSOs of the SEE CCR shall ensure that the day-ahead validated cross-zonal capacity shall be provided to relevant entity no later than the day-ahead firmness deadline as defined in accordance with Article 69 of CACM Regulation.

(21)In accordance with Article 58 of CACM regulation, the CCC and TSOs of the SEE CCR shall ensure that the intraday validated cross-zonal capacity shall be provided to relevant entity no later than 15 minutes before the intraday cross-zonal gate opening time. Article 12 Fallback procedures

(1)Prior to the day-ahead common capacity calculation, the TSOs of SEE CCR shall provide to the CCC the coordinated cross-zonal capacities defined according with the long-term capacity calculation processes. For day-ahead market time-frame are used as fallback solution the NTCs values calculated for yearly and monthly processes.

(2)For the day-ahead common capacity calculation, where an incident occurs in the capacity calculation process (incident due to, inter alia, a technical failure in the tools, an error in the communication infrastructure, or corrupted or missing input data) and the CCC is unable to produce results within the allotted time for the calculation process, the SEE TSOs shall validate for day-ahead market time-frame the coordinated cross-zonal capacities calculated within the long-term time-frame.

(3)Prior to the intraday common capacity calculation, the TSOs of SEE CCR shall provide to the CCC the coordinated cross-zonal capacities calculated within the day-ahead capacity calculation processes.

(4)For the intraday common capacity calculation, where an incident occurs in the capacity calculation process (incident due to, inter alia, a technical failure in the tools, an error in the communication infrastructure, or corrupted or missing input data) and the CCC is unable to produce results, the SEE TSOs shall validate the cross-zonal capacities calculated within the day-ahead capacity calculation processes.

(5)SEE TSOs provide inputs to the CCC a few hours before the gate opening of the relevant timeframe. The exact deadlines will be defined during the simulation period. In case TSOs provide inputs to the CCC that are proven to be incomplete by the CCC or are missing, the CCC uses the relevant values from the previous timeframe. Article 13 Consideration of non-SEE CCR bidding zone borders 24 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(1)In accordance with Article 21

(1)(b)(vii) of the CACM Regulation, SEE TSOs take into account the influences of other CCRs by making assumptions on what will be the future non-SEE exchanges in accordance with Article 18

(3)of the CACM Regulation and Article 19 of the CGMM.

(2)The assumptions of non-SEE exchanges are implicitly captured in the relevant CGM by the non-SEE TSOs’ best forecasts of net positions and flows for HVDC lines, according to Article 18

(3)of CACM Regulation and are used as the basis for the common capacity calculation. In SEE CCR, this constitutes the rule for sharing power flow capabilities among different CCRs. Article 14 Publication and Timescale for Implementation of the capacity calculation methodology

(1)The TSOs of the SEE CCR shall publish this day-ahead and intraday capacity calculation methodology without undue delay after all relevant national regulatory authorities have approved the proposed methodology or a decision has been taken by the Agency for the Cooperation of Energy Regulators in accordance with Article 9

(10),

(11)and

(12)of the CACM Regulation.

(2)The TSOs of the SEE CCR shall start the implementation process of this common capacity calculation methodology with the entry into force of this methodology and shall consist of the following steps: a. Internal parallel run, during which the TSOs shall test the operational processes for capacity calculation inputs, capacity calculation process and capacity validation and develop the appropriate IT tools and infrastructure; b. External parallel run, during which the TSOs will continue testing their internal processes and IT tools and infrastructure. In addition, SEE TSOs will involve market participants to test the effects of applying this methodology on the market. In accordance with Article 20

(8)of CACM Regulation, this phase shall not be shorter than 6 months.

(3)During the internal and external parallel run, SEE TSOs shall continuously monitor the effects and the performance of the application of this methodology. For this purpose, they shall develop, in coordination with SEE NRAs, the Agency and stakeholders, the monitoring and performance criteria and report on the outcome of this monitoring on a quarterly basis in a quarterly report. After the implementation of this methodology outcome of this monitoring shall be reported in the annual report.

(4)The TSOs of the SEE CCR shall implement the day-ahead common capacity calculation methodology no later than 1st of Jan 2025.

(5)The TSOs of the SEE CCR shall implement intraday capacity calculation within the following timeframes: a. Update of cross-zonal capacities pursuant to Article 5

(9)(a) by the deadline of implementation of dayahead capacity calculation; b. Calculation of intraday cross-zonal capacities pursuant to Article 5

(9)(b) by 3 months after the implementation of day-ahead capacity calculation methodology; and c. Re-calculation of intraday cross-zonal capacities pursuant to Article 5

(9)(

1. c)by 12 months after the implementation of calculation of intraday cross-zonal capacities pursuant to point (
2. b)of this paragraph.

(6)Parallel runs may start at the earliest due to time required for procurement, development and testing of the industrial capacity calculation tool. Article 15 Reviews and updates 25 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management

(1)Based on Article 3(f) of the CACM Regulation and in accordance with Article 27

(4)of the CACM Regulation all TSOs shall regularly and at least once a year review and update the key input and output parameters listed in Article 27

(4)(

1. a)to (
2. d)of the CACM Regulation.

(2)In case the review proves the need of an update of the reliability margins methodology, SEE TSOs shall publish the changes at least 1 month before the implementation.

(3)In case the review proves the need of an update of the operational security limits, critical network elements and contingencies used for capacity calculation inputs pursuant to article 7, TSOs the SEE CCR shall publish the changes at least 1 week before the implementation.

(4)The review of the common list of RAs taken into account in capacity calculation shall include at least an evaluation of the efficiency of RAs considered during RAC.

(5)In case the review proves the need for updating the application of the methodologies for determining generation shift keys, operational security limits, critical network elements and contingencies referred to in Articles 23 to 24 of the CACM Regulation, changes have to be published at least 3 months before the final implementation.

(6)Any changes of parameters listed in Article 27

(4)of the CACM Regulation have to be communicated to market participants, SEE NRAs and the Agency.

(7)The impact of any changes of the parameters listed in Article 27

(4)(d) of the CACM Regulation have to be communicated to market participants, SEE regulatory authorities and the Agency. If any change leads to an adaption of this methodology, SEE TSOs will amend this methodology according to Article 9

(13)of the CACM Regulation. Article 16 Publication of data

(1)In accordance with Article 3(f) of the CACM Regulation aiming at ensuring and enhancing the transparency and reliability of information to the regulatory authorities and market participants, SEE TSOs and CCC shall regularly publish the data on the capacity calculation process pursuant to this methodology on a dedicated online communication platform representing all SEE TSOs of the SEE CCR. To enable market participants to have a clear understanding of the published data, SEE TSOs and CCC shall develop a handbook and publish it on this communication platform. This handbook shall include at least a description of each data item, including its unit and underlying convention.

(2)SEE TSOs and CCC shall publish the following data items (in addition to the data items and definitions of Commission Regulation (EU) No 543/2013 on submission and publication of data in electricity markets) no later than 30 minutes before market gate opening time in case of day-ahead capacity calculation and no later than 15 minutes before market gate opening time in case of intraday capacity calculation, except point p): a. NTC values determined for day-ahead and intraday market time-frames; b. RMs for each direction of the SEE CCR borders; c. RAs resulting from the RAC and for each RA it shall be published the type of RA, location of RA, whether the RA was curative or preventive, if the RA was curative, a list of CNEC identifiers describing the CNEC to which the RA was associated; d. Limiting CNECs; e. For each CNEC, it shall be published the methods for determining Imax in accordance with article 7

(5)a); f. For each CNEC the EIC code of CNE and Contingency; g. Real names of CNECs; 26 ΑΔΑ: 6ΜΚΘΙΔΞ-Φ6Γ SEE CCR TSOs’ proposal for the common capacity calculation methodology for the day-ahead and intraday market time-frame in accordance with Article 21 of Commission Regulation (EU) 2015/1222 of 24 July 2015 establishing a guideline on capacity allocation and congestion management h. Maximum flow on the CNECs; i. Zone to hub PTDF associated with the oriented bidding-zone border; j. Margin from coordinated capacity calculation (MCCC); k. Margin from non-coordinated capacity calculation (MNCC); l. M