ΑΠΟΦΑΣΗ ΤΟΥ ΚΛΑΔΟΥ ΕΝΕΡΓΕΙΑΣ ΤΗΣ ΡΑΑΕΥ ΥΠ’ ΑΡΙΘΜ. Ε- 162/2023

(2013)2949 final για την εξαίρεση του αγωγού TAP AG από τις διατάξεις των άρθρων 9, 32 και 41

(6),

(8)και

(10)της Οδηγίας 2009/73/ΕΚ και τροποποίηση της υπ. αριθμ. 111/2013 απόφασης της ΡΑΕ» (ΦΕΚ Β’ 1833/29.07.2013) με την οποία εγκρίθηκε το κείμενο με τίτλο «Final Joint Opinion of the Energy Regulators on TAP AG's Exemption Application: Autorita per l'energia elettrica e il gas (Italy), Enti Rregullator I Energjise (Albania), Ρυθμιστική Αρχή Ενέργειας (Greece)» (εφεξής, η «Κοινή Απόφαση Εξαίρεσης» ή «FJO»). 7. Την από 6 Ιουνίου 2013 υπ’ αριθμ. 249/2013/R/gas Απόφαση της Ιταλικής Ρυθμιστικής Αρχής (AEEG), την από 13 Ιουνίου 2013 υπ’ αριθμ. 64 Απόφαση της Αλβανικής Ρυθμιστικής Αρχής Ενέργειας (ERE) και την από 25 Ιουνίου απόφαση του Ιταλικού Υπουργείου Οικονομικής Ανάπτυξης (Ministero dello Sviluppo Economico), με τις οποίες επίσης εγκρίθηκε η ως άνω υπό στοιχείο

(6)αναφερόμενη Απόφαση Εξαίρεσης. 8. Την υπ’ αριθμ. 131/2015 Απόφαση της ΡΑΕ με θέμα «Συμμόρφωση της ΡΑΕ κατά την παράγραφο 9 του άρθρου 36 της Οδηγίας 2009/73/EC με την από 17.03.2015 Απόφαση της Ευρωπαϊκής Επιτροπής υπ. αριθμ. C

(2015)1852 final για την έγκριση του αιτήματος της εταιρείας TAP A.G. για την επέκταση της χρονικής διάρκειας της εξαίρεσης του αγωγού TRANS ADRIATIC PIPELINE (TAP) από τις διατάξεις των άρθρων 9, 32 και 41

(6),

(8)και

(10)της Οδηγίας 2009/73/ΕΚ», με την οποία εγκρίθηκε το κείμενο με τίτλο «Energy Regulators’ Joint Opinion on TAP AG’s request for a prolongation of the validity period of the exemption decision», το οποίο προσαρτήθηκε στην εν λόγω Απόφαση και αποτελεί αναπόσπαστο τμήμα αυτής (εφεξής η «Απόφαση Εξαίρεσης από κοινού με το σχετικό 6).

1. Την υπ’ αριθμ. 531/2013 Απόφαση της ΡΑΕ (ΦΕΚ Β’ 3003/26.11.2013) με θέμα «Έγκριση του Κανονισμού Τιμολόγησης της εταιρείας “TAP A.G.” για τον αγωγό TAP», όπως τροποποιήθηκε με την Απόφαση 708/2018 και ισχύει, καθώς και τις αποφάσεις AEEGSI Deliberation 495/2013/R/gas, dated 6/11/2013, και ERE Decision n. 127 dated 7/11/2013 της Ιταλικής και Αλβανικής Ρυθμιστικής Αρχής αντίστοιχα, με τις οποίες εγκρίθηκε ο Κανονισμός Τιμολόγησης για τον αγωγό TAP.
2. Τις διατάξεις της υπ’ αριθμ. Δ1/Α/5346/22.03.2010 απόφασης του Υφυπουργού Περιβάλλοντος Ενέργειας και Κλιματικής Αλλαγής με θέμα «Κώδικας Διαχείρισης του Εθνικού Συστήματος Φυσικού Αερίου» (Β΄379, εφεξής ο «Κώδικας»), όπως τροποποιήθηκε με τις υπ’ αριθμ. 1096/2011 (Β’ 2227), 526/2013 (Β’ 3131), 239/2017 (Β’ 1549 και Β’ 2159), -2- 123/2018 (Β’ 788), 1005/2019 (Β΄ 4088), 727/2020 (Β’ 1684), 1035/2020 (Β΄ 2840), 1400/2020 (Β΄ 4585), 1433/2020 (Β’ 4799 & Β’ 5078), 735/2021 (Β΄4687), 1060/2021 (Β΄ 37), 590/2022 (Β΄ 4270), 645/2022 (Β΄ 4269), 748/2022 (Β΄5176), 771/2022 (Β΄5576), 822/2022 (Β΄69) Αποφάσεις της ΡΑΕ και Ε-143 Απόφαση της ΡΑΑΕΥ.
3. Την υπ’ αριθμ. 517/2021 Απόφαση της ΡΑΕ με θέμα «Έγκριση Κατευθυντήριων Γραμμών για την Πρόσκληση Εκδήλωσης Ενδιαφέροντος έτους 2021 για την επαύξηση δυναμικότητας του αγωγού Trans-Adriatic Pipeline (TAP)», καθώς και τις αποφάσεις ARERA Deliberation 273/2021/R/gas, dated 28/06/2021 και ERE Decision n. 151 dated 29/06/2021 της Ιταλικής και Αλβανικής Ρυθμιστικής Αρχής αντίστοιχα, με τις οποίες εγκρίθηκαν οι κατευθυντήριες γραμμές για την εκδήλωση ενδιαφέροντος για την επαύξηση δυναμικότητας του αγωγού TAP.
4. Την έκθεση εκτίμησης ζήτησης της αγοράς για την επαυξημένη δυναμικότητα του αγωγού TAP, η οποία διαμορφώθηκε από κοινού από τους Διαχειριστές TAP, SNAM και ΔΕΣΦΑ και αναρτήθηκε στις ιστοσελίδες τους στις 25.10.2021 με τίτλο «Demand assessment report for incremental capacity between Trans Adriatic Pipeline, Snam Rete Gas and DESFA».
5. Την υπ’ αριθμ. 818/2022 Απόφαση της ΡΑΕ με θέμα «Έγκριση της Πρότασης Έργου Επαυξημένης Δυναμικότητας των Διαχειριστών TAP, SNAM και ΔΕΣΦΑ», καθώς και τις αποφάσεις ARERA Deliberation 548/2022/R/gas, dated 02/11/2022 και ERE Decision n. 270 dated 02/11/2022 της Ιταλικής και Αλβανικής Ρυθμιστικής Αρχής αντίστοιχα, με τις οποίες εγκρίθηκε η πρόταση έργου επαυξημένης δυναμικότητας των τριών διαχειριστών.
6. Το από 22.09.2023 έγγραφο της εταιρείας TAP AG, από κοινού με την Snam Rete Gas (SNAM) και τη ΔΕΣΦΑ A.E., προς τις Ρυθμιστικές Αρχές Ελλάδας, Αλβανίας και Ιταλίας με θέμα «Submission of Project Proposal of 2nd Binding Phase - NRAs» (αριθμ. πρωτ. ΡAΑΕY I358185/25.09.2023).
7. Το από 03.10.2023 ηλεκτρονικό έγγραφο της εταιρείας TAP AG προς τις Ρυθμιστικές Αρχές Ελλάδας, Αλβανίας και Ιταλίας με θέμα «Submission of Project Proposal of 2nd Binding Phase NRAs» με το οποίο υποβλήθηκε το τελικό κείμενο της πρότασης έργου επαυξημένης δυναμικότητας των τριών διαχειριστών (αριθμ. πρωτ. ΡAΑΕY I-358979/04.10.2023).
8. Το γεγονός ότι από την παρούσα απόφαση δεν προκαλείται επιβάρυνση στον κρατικό προϋπολογισμό. Σκέφτηκε ως εξής: Επειδή, με τις αποφάσεις των σχετικών 6 και 8 χορηγήθηκε στην εταιρεία ΤΑΡ AG (εφεξής, η «Εταιρεία»), σύμφωνα με τις διατάξεις του άρθρου 36 της Οδηγίας 2009/73/ΕΚ, εξαίρεση από την εφαρμογή των διατάξεων των άρθρων 9, 32 και 41

(6),

(8)και

(10)της εν λόγω Οδηγίας για τον αγωγό Trans Adriatic Pipeline (TAP) και για χρονικό διάστημα είκοσι πέντε

(25)ετών από την έναρξη εμπορικής λειτουργίας του αγωγού. Συγκεκριμένα, χορηγήθηκε εξαίρεση από: - τις διατάξεις του άρθρου 9 περί ιδιοκτησιακού διαχωρισμού - τις διατάξεις του άρθρου 32 περί πρόσβασης τρίτων μόνο για την αρχική δυναμικότητα του αγωγού TAP (Initial Capacity) ύψους 10 δις m3/έτος (bcma) και μόνο για την κατεύθυνση φυσικής ροής -3- - τις διατάξεις του άρθρου 41 παρ.

(6),

(8)και

(10)περί ρύθμισης τιμολογίων για το σύνολο της δυναμικότητας του αγωγού. Αντίθετα, δεν χορηγήθηκε η αιτηθείσα εξαίρεση για τα ακόλουθα: - για το σύνολο της δυναμικότητας (αρχική και πιθανή επέκταση), από το άρθρο 41

(6),

(8)και

(10)της Οδηγίας περί ρύθμισης τιμολογίων, για την περίπτωση της εμπορικής ανάστροφης ροής (commercial reverse flow) - από τις διατάξεις του Κανονισμού (ΕΚ) 715/

1. Επειδή, με την Απόφαση Εξαίρεσης οι αρμόδιες Ρυθμιστικές Αρχές Ελλάδας (ΡΑΕ), Αλβανίας (ERE) και Ιταλίας (ARERA), έθεσαν επιπλέον όρους στην Εταιρεία, όπως την υποχρέωση αύξησης της μεταφορικής ικανότητας του αγωγού σε 20 δις m3/έτος (bcma) μέσω μηχανισμών αγοράς, και σύμφωνα με τις βέλτιστες πρακτικές της Ευρωπαϊκής Ένωσης, εάν υπάρχει ζήτηση και η επέκταση κριθεί οικονομικά αποδοτική. Συγκεκριμένα, στα σημεία 7-9 της παραγράφου 4.1 της Απόφασης Εξαίρεσης αναφέρεται: «
2. Obligation to perform subsequent market tests – TAP AG is obliged to perform other Market Tests on a regular basis starting from no later than the Commercial Operations Date and, subsequently, at least every two years. TAP AG will perform the Market Tests, under guidelines to be approved by the Authorities, with the view to offer to all interested parties additional available capacity up to the Total Capacity.
3. Obligation to build Expansion Capacity – In order to fulfill the binding capacity requests resulting from each market test described in point 7, TAP AG will extend the capacity of the pipeline. TAP AG is obliged to build additional capacity, above the Initial Capacity, in order to accommodate the binding capacity requests resulting from each market test taking into account the provisions of points 2, 6 and 9 of §4.
4. TAP AG shall enter into a binding agreement to have the requested capacity constructed no later than 2 months following the closing date of the market test. If TAP AG considers that, in spite of such binding capacity requests, a pipeline expansion is not economically viable, TAP AG is obliged to demonstrate this situation to the Authorities within one month following the closing date of the market test. If so requested by the Authorities, TAP will provide the opinion of a third, independent party. In case such an opinion is requested by the Authorities, the one month deadline is extended by two months. The Authorities will decide upon the economic viability of a pipeline expansion within one month after receipt of TAP AG’s submission or receipt of the opinion from an independent third party, as the case may be. TAP AG shall enter into a binding agreement to have the Expansion Capacity constructed no later than 2 months after the Authorities have deemed its construction economically viable. The expansion is economically viable if the incremental revenues from capacity resulting from each market test is equal or larger than the efficient increment costs, quantified according to the TAP methodology as laid down in the TAP Tariff Code. To the extent that (in accordance with Article 4 of the present Decision) the Tap Tariff Code will remunerate TAP AG differently for Initial Capacity and Expansion Capacity, proper account will be taken in the TAP Tariff Code to ensure that the test for deciding whether construction of the Expansion Capacity is economically viable is unaffected. -4-
5. Possibility to further expand capacity – Expansion beyond the Total Capacity, i.e. beyond 20 bcm/year, shall be investigated by TAP AG and if economically and technically feasible, it will be undertaken, with a view to fulfill all requests for long-term capacity (long-term means here a duration of more than 15 years).». Επειδή, οι Ρυθμιστικές Αρχές, κατόπιν συνεργασίας μεταξύ τους και με την Εταιρεία, ενέκριναν τις Κατευθυντήριες Γραμμές για τη διεξαγωγή της πρώτης φάσης του Market Test του 2021 (σχετικό 11), οι οποίες δεν διαφοροποιούνται από τις Κατευθυντήριες Γραμμές του Market Test του 2019, και εξασφαλίζουν την κατά το δυνατόν εφαρμογή του Κανονισμού CAM, στο βαθμό που δεν αντιβαίνει στην Απόφαση Εξαίρεσης. Επειδή, τον Ιούλιο του 2021 πραγματοποιήθηκε η πρώτη φάση της διαδικασίας επαύξησης δυναμικότητας με την υποβολή μη δεσμευτικών αιτημάτων. Ειδικότερα, για το σημείο διασύνδεσης του αγωγού TAP με το Εθνικό Σύστημα Φυσικού Αερίου στη Νέα Μεσημβρία υποβλήθηκαν αιτήματα για δυναμικότητα με ροή από το ΕΣΦΑ προς τον αγωγό TAP ίση με 15.000 MWh ανά ημέρα για την περίοδο 2021-2023 και δυναμικότητα προς την ίδια κατεύθυνση ίση με 30.000 MWh ανά ημέρα για την περίοδο 2023-
6. Επειδή, σύμφωνα με τον Κανονισμό CAM, αμέσως μετά την υποβολή των μη δεσμευτικών αιτημάτων, οι τρεις Διαχειριστές (TAP, SRG και ΔΕΣΦΑ) συνέταξαν την Έκθεση Εκτίμησης Ζήτησης της Αγοράς, η οποία δημοσιεύτηκε τον Οκτώβριο του 2021 (σχετικό 12) και ανέδειξε την ανάγκη έναρξης έργου επαυξημένης δυναμικότητας. Επειδή, τον Ιανουάριο του 2022 οι τρεις Διαχειριστές, ακολουθώντας τις διατάξεις και τις προβλεπόμενες προθεσμίες του Κανονισμού CAM, διεξήγαγαν από κοινού δημόσια διαβούλευση επί του σχεδίου πρότασης του έργου επαυξημένης δυναμικότητας που είχαν μέχρι τότε διαμορφώσει, με στόχο να ικανοποιήσουν τα μη δεσμευτικά αιτήματα που είχαν υποβληθεί στην πρώτη φάση του market test, η οποία διήρκησε δύο μήνες (18.01.202218.03.2022). Επειδή, τον Νοέμβριο του 2022 οι Ρυθμιστικές Αρχές Ελλάδας, Αλβανίας και Ιταλίας με κοινή απόφαση ενέκριναν την πρόταση των τριών Διαχειριστών για το έργο επαυξημένης δυναμικότητας (σχετ. 13) σύμφωνα με τις διατάξεις των άρθρων 27 και 28 του Κανονισμού. Επειδή, σύμφωνα με το σχετικό 13 και ειδικότερα το άρθρο D.1 της εγκεκριμένης πρότασης έργου επαυξημένης δυναμικότητας: «Based on the feedback received during the Public Consultation which ended on the 18th of March 2022 and considering the recent gas market developments, the TSOs propose to adopt an accelerated timeline and organise a Binding Bidding Phase in January 2023, followed by a second Binding Phase, in
7. Should the TSOs elect, in their sole discretion, to hold a second Binding Phase, then such second Binding Phase will include the same phases (i.e., Information Phase and Binding Bidding Phase followed by capacity allocation, EVT and GTA entry).For the avoidance of doubt, and subject to Conditions Precedent set by each TSO in part E.7, commitments undertaken during the first Bidding Phase shall not be affected in case of a second Binding Phase. Participants should note that the TSOs Concerned reserve the right to hold a second Binding -5- Phase. Once, the decision to hold a second Binding Phase will be taken, it will be notified to the NRAs, and the TSOs Concerned shall have no liability to any party in connection with such decision. Επειδή, σύμφωνα με τα ανωτέρω, η πρόταση του έργου επαύξησης δυναμικότητας προέβλεπε την πιθανότητα διεξαγωγής μιας δεύτερης δεσμευτικής φάσης η οποία θα λάμβανε χώρα μέσα στο
8. Επειδή, οι τρεις Διαχειριστές TAP, SRG και ΔΕΣΦΑ με κοινή ανακοίνωση1, δήλωσαν την επιθυμία τους να πραγματοποιήσουν τη δεύτερη δεσμευτική φάση του Market Test 2021 το δεύτερο εξάμηνο του 2023, με την έγκριση της Πρότασης Έργου από τις Εθνικές Ρυθμιστικές Αρχές Ελλάδας, Ιταλίας και Αλβανίας. Επειδή, με το σχετικό 15 οι Διαχειριστές υπέβαλαν προς έγκριση στις Ρυθμιστικές Αρχές την πρότασή τους για το έργο Επαυξημένης Δυναμικότητας για τη Δεύτερη Δεσμευτική φάση του Market Test για το 2021, η οποία σύμφωνα με τα προβλεπόμενα στην παράγραφο 3 του άρθρου 27 και στην παράγραφο 1 του άρθρου 28 του Κανονισμού CAM, περιλαμβάνει τα ακόλουθα: - - Περιγραφή του έργου επαυξημένης δυναμικότητας συμπεριλαμβανομένης εκτίμησης του κόστους του έργου που απαιτείται. Επίπεδα προσφοράς για τα προϊόντα δεσμοποιημένης δυναμικότητας στα σημεία διασύνδεσης. Αιτιολόγηση για την επιλογή εναλλακτικού μηχανισμού κατανομής των διαχειριστών συστημάτων μεταφοράς Προσωρινά χρονοδιαγράμματα του έργου επαυξημένης δυναμικότητας Γενικούς κανόνες και όρους για τη συμμετοχή στο δεσμευτικό στάδιο κατανομής δυναμικότητας, συμπεριλαμβανομένων εγγυήσεων, διαδικασίας αντιμετώπισης ενδεχομένων καθυστερήσεων στην παροχή της δυναμικότητας και προβλέψεις για την περίπτωση διακοπής του έργου. Παράγοντα f για συγκεκριμένο επίπεδο προσφοράς ανά διαχειριστή σύμφωνα με το άρθρο 23 του Κανονισμού, Επειδή, με βάση τα δεσμευτικά αιτήματα που υποβλήθηκαν στην πρώτη φάση της διαδικασίας οι συμμετέχοντες αιτήθηκαν δυναμικότητα στο σημείο διασύνδεσης με το ΕΣΦΑ στη Νέα Μεσημβρία με κατεύθυνση ΕΣΦΑ προς αγωγό ΤΑΡ: Νέα Μεσημβρία (Έξοδος ΔΕΣΦΑ -Είσοδος ΤΑΡ) Δυναμικότητα (kWh/ημέρα) Χρονική Περίοδος 5.000.000 1/10/2026-30/09/2033 1 https://www.tap-ag.gr/shippers/market-tests-7 -6- Επειδή, λαμβάνοντας υπόψη τα μη δεσμευτικά και τα δεσμευτικά αιτήματα που υποβλήθηκαν στην πρώτη φάση της διαδικασίας, οι Διαχειριστές προσδιόρισαν, ανά σημείο διασύνδεσης, τα ακόλουθα εναλλακτικά επίπεδα επαύξησης δυναμικότητας ανά σημείο διασύνδεσης: Κήποι: Επίπεδο Προσφοράς 1Α Επίπεδο Προσφοράς 1Β Επίπεδο Προσφοράς 1C Επίπεδο Προσφοράς 2 Επίπεδο Προσφοράς 3 Ημ/νία Έναρξης Q4 - 2027 Τέλος 2028 Τέλος 2028 Τέλος 2028 Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 45.297.040 61.196.933 97.368.428 12.270.720 204.565.936 Νέα Μεσημβρία: Επίπεδο Προσφοράς 1 Ημ/νία Έναρξης Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 25.000.000 Προσφέρων Διαχειριστής Έξοδος Είσοδος ΔΕΣΦΑ TAP Κομοτηνή: Επίπεδο Προσφοράς 1 Ημ/νία Έναρξης Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 25.000.000 Προσφέρων Διαχειριστής Έξοδος Είσοδος TAP - Kucove: Επίπεδο Προσφοράς 1 Ημ/νία Έναρξης Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 7.500.000 Προσφέρων Διαχειριστής Έξοδος Είσοδος TAP - Roskovec: Ημ/νία Έναρξης Προσφέρων Διαχειριστής Επίπεδο Προσφοράς 1 Έξοδος Είσοδος Τέλος 2028 TAP - -7- Προσφέρων Διαχειριστής Έξοδος Είσοδος - TAP Δυναμικότητα (kWh/ημέρα) 2.500.000 Fier: Επίπεδο Προσφοράς 1 Ημ/νία Έναρξης Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 7.500.000 Προσφέρων Διαχειριστής Έξοδος Είσοδος TAP - Fier (προς TAP): Επίπεδο Προσφοράς 1 Προσφέρων Διαχειριστής Έξοδος Είσοδος - TAP Ημ/νία Έναρξης Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 44.900.000 Επίπεδο Προσφοράς 1Α Επίπεδο Προσφοράς 1Β Επίπεδο Προσφοράς 1C Επίπεδο Προσφοράς 2 Επίπεδο Προσφοράς 3 Ημ/νία Έναρξης Q4 - 2027 Τέλος 2028 Τέλος 2028 Τέλος 2028 Τέλος 2028 Δυναμικότητα (kWh/ημέρα) 45.297.040 61.196.933 97.368.428 112.270.72 0 204.565.93 6 Melendugno: Προσφέρων Διαχειριστής Έξοδος Είσοδος TAP SRG Επειδή, για να καταστεί διαθέσιμη η δυναμικότητα εξόδου από το ΕΣΦΑ προς τον TAP στο σημείο διασύνδεσης της Νέας Μεσημβρίας, δεν απαιτούνται νέες επενδύσεις πέραν των ήδη ενταγμένων στο τρέχον εγκεκριμένο Πρόγραμμα Ανάπτυξης του ΕΣΦΑ, ήτοι της νέας μονάδας συμπίεσης στην Αμπελιά, της αναβάθμισης του σταθμού συμπίεσης στη Νέα Μεσημβρία και του booster συμπιεστή στη Νέα Μεσημβρία. Επειδή, το εκτιμώμενο κόστος των έργων που θα πρέπει να εκτελέσουν οι δύο άλλοι Διαχειριστές προκειμένου να καλύψουν το ενδιαφέρον που εκδηλώθηκε παρουσιάζεται ανά επίπεδο προσφοράς, στον ακόλουθο πίνακα: Επίπεδο Επίπεδο Επίπεδο Επίπεδο Επίπεδο Διαχειριστής Προσφοράς Προσφοράς Προσφοράς Προσφοράς Προσφοράς 1Α 1Β 1C 2 3 768 Μ€ 974 Μ€ TAP 457 M€ 1349 Μ€ 1814 Μ€ SNAM 270 Μ€ Επειδή, το έργο επαυξημένης δυναμικότητας περιλαμβάνει περισσότερα από δύο συστήματα εισόδου – εξόδου στην Ευρωπαϊκή Ένωση, ήτοι τον αγωγό TAP, το Ιταλικό σύστημα μεταφοράς φυσικού αερίου και το Εθνικό Σύστημα Φυσικού Αερίου (ΕΣΦΑ). Τα δεσμευτικά αιτήματα της -8- πρώτης φάσης αφορούσαν σε πρόθεση δέσμευσης δυναμικότητας στα ακόλουθα σημεία: Κήποι, Νέα Μεσημβρία, Kucove, Roskovec, Fier και Melendugno, και για χρονικό διάστημα μεγαλύτερο του έτους. Επειδή, σύμφωνα με τα παραπάνω πληρούνται ο προϋποθέσεις που τίθενται στην παράγραφο 2 του άρθρου 30 του Κανονισμού CAM, για την εφαρμογή Εναλλακτικού Μηχανισμού Κατανομής δυναμικότητας. Επειδή, λαμβάνοντας υπόψιν το ιδιάζον ρυθμιστικό πλαίσιο του αγωγού TAP (σχετικά 6, 7 και 8) και τα ιδιαίτερα υψηλά κόστη των απαιτούμενων επενδύσεων, προκειμένου να αυξηθεί η πιθανότητα θετικής έκβασης των οικονομικών δοκιμών που θα εφαρμοστούν στις δύο πλευρές κάθε σημείου διασύνδεσης, κρίνεται εύλογη η πρόταση των Διαχειριστών για την εφαρμογή Εναλλακτικού Μηχανισμού Κατανομής δυναμικότητας, σύμφωνα με το άρθρο 30 του Κανονισμού CAM, για προϊόντα δυναμικότητας έως 20 ετών. Επειδή, οι δεσμευτικές προσφορές των συμμετεχόντων θα συνδέουν δεσμεύσεις σε ένα σημείο διασύνδεσης με δεσμεύσεις σε άλλα σημεία διασύνδεσης και δεσμεύσεις σε πλήθος διαφορετικών ετησίων τυποποιημένων προϊόντων δυναμικότητας, σύμφωνα με την παράγραφο 3 του άρθρου 30 του Κανονισμού CAM. Επομένως, προκειμένου να αυξηθεί η πιθανότητα υλοποίησης του έργου επαύξησης, κρίνεται σκόπιμη η παροχή προτεραιότητας σε δεσμεύσεις δυναμικότητας διάρκειας κατ’ ελάχιστον τριών συνεχόμενων ετών και η σύνδεση δεσμεύσεων σε περισσότερα του ενός σημεία διασύνδεσης, σύμφωνα με την παράγραφο 4 του άρθρου 30 του Κανονισμού CAM. Επειδή, στην πρόταση των Διαχειριστών περιλαμβάνονται οι κανόνες και οι όροι για τη συμμετοχή στη δεσμευτική φάση της διαδικασίας επαύξησης δυναμικότητας και επιπλέον οι εγγυήσεις που απαιτούνται για τη συμμετοχή, η διαδικασία επιστροφής τους σε περίπτωση αρνητικής οικονομικής δοκιμής ή μη κατανομής δυναμικότητας, η διαδικασία που θα ακολουθηθεί σε περίπτωση θετικής οικονομικής δοκιμής (υπογραφή σύμβασης μεταφοράς και πρόσθετες εγγυήσεις), καθώς και η περίπτωση που δεν τεθεί σε ισχύ κάποια σύμβαση μεταφοράς. Επειδή, το ύψος των εγγυήσεων που προτείνεται από τον ΔΕΣΦΑ για τη συμμετοχή στη δεσμευτική φάση είναι ίσο με το 20% της χρέωσης που προκύπτει για τη μέγιστη αιτηθείσα ετήσια δυναμικότητα κάθε συμμετέχοντα με βάση την εκτίμηση του Διαχειριστή για τα τιμολόγια χρήσης του ΕΣΦΑ, όπως ισχύει και για τις περιπτώσεις προϊόντων δυναμικότητας ετήσιας διάρκειας στα Σημεία Εισόδου του ΕΣΦΑ (Κώδικας Διαχείρισης ΕΣΦΑ άρθρα 21Η παρ. 2Α και 21Ι παρ. 3Α). Επειδή, για τον ίδιο λόγο, οι εγγυητικές επιστολές που αφορούν στη διαδικασία της επαύξησης δυναμικότητας (συμμετοχή στη δεσμευτική φάση της διαδικασίας και εγγυήσεις σύμβασης μεταφοράς) θα πρέπει να εκδίδονται από ελληνικό χρηματοπιστωτικό ίδρυμα εποπτευόμενο από την Ευρωπαϊκή Κεντρική Τράπεζα (συστημικές τράπεζες) ή οποιοδήποτε ελληνικό υποκατάστημα διεθνούς φήμης τράπεζας – ή οποιασδήποτε διεθνούς φήμης τράπεζας – με ελάχιστη αξιολόγηση πιστοληπτικής ικανότητας Α- από την Standard and Poor’s ή A3 από την Moody’s, το οποίο έχει εγκριθεί εκ των προτέρων από τον ΔΕΣΦΑ. -9- Επειδή, κάθε έγκριση ή εν γένει πράξη που απορρέει από την Απόφαση Εξαίρεσης αποτελεί κοινή απόφαση των τριών Ρυθμιστικών Αρχών Ιταλίας, Αλβανίας και Ελλάδας, σύμφωνα με την παράγραφο 4.8.1 της Απόφασης Εξαίρεσης: «Where the present opinion foresees an action by the Authorities, for the purpose of the implementation of such an action, the Authorities shall endeavor all efforts to act jointly.». Ωστόσο, εν προκειμένω, κάθε Ρυθμιστής εγκρίνει το κείμενο κατά το μέρος που τον αφορά, δηλαδή η ΡΑΑΕΥ για τα θέματα που αφορούν στους TAP και ΔΕΣΦΑ. Επειδή, περαιτέρω, ο συντονισμός στις αποφάσεις των αρμοδίων Ρυθμιστών προβλέπεται επίσης και στην παράγραφο 2 του άρθρου 28 του Κανονισμού CAM. Επειδή, οι Ρυθμιστικές Αρχές Ιταλίας, Αλβανίας και Ελλάδας συνεργάστηκαν για την εξέταση της πρότασης έργου επαυξημένης δυναμικότητας των τριών Διαχειριστών TAP, SRG και ΔΕΣΦΑ (σχετ.15) και κατά τη διαδικασία αυτή διατυπώθηκαν κοινές θέσεις, οι οποίες αποτυπώνονται στο Παράρτημα της παρούσας, το οποίο αναφέρεται ως «ANNEX A». Για τους παραπάνω λόγους Αποφασίζει
9. Την έγκριση του κειμένου με τίτλο «Project Proposal of TAP, SRG and DESFA for the 2021 Incremental Capacity Process 2nd Binding Phase».
10. Το εγκεκριμένο κείμενο αποτελεί Παράρτημα (Παράρτημα Β – Annex B) της κοινής Απόφασης των Ρυθμιστικών Αρχών της Ελλάδος, Ιταλίας και Αλβανίας με τίτλο «Approval of “Project Proposal of TAP, SRG and DESFA for the 2021 Incremental Capacity Process – 2nd Binding Phase” jointly proposed by TAP, SRG and DESFA in September 2023», η οποία προσαρτάται στην παρούσα Απόφαση ως «Παράρτημα Α» και αποτελεί αναπόσπαστο τμήμα αυτής. Κατά της παρούσας απόφασης χωρεί αίτηση αναθεώρησης, η οποία ασκείται μέσα σε τριάντα

(30)ημέρες από τη δημοσίευση ή κοινοποίηση της απόφασης, σύμφωνα με τη διάταξη της παραγράφου 2 του άρθρου 32 του ν. 4001/2011. Αθήνα, 05-10 - 2023 Ο Προεδρεύων του κλάδου Ενέργειας της ΡΑΑΕΥ Καθηγητής Κωνσταντίνος Τσιμάρας - 10 - ΠΑΡΑΡΤΗΜΑ A Autorità di regolazione per energia, reti e ambiente (ARERA, Italy) Enti Rregullator i Energjise (ERE, Albania) Ρυθμιστική Αρχή Αποβλήτων, Ενέργειας και Υδάτων (RAEWW, Greece) Approval of “Project Proposal of TAP, SRG and DESFA for the 2021 Incremental Capacity Process – 2nd Binding Phase” jointly proposed by TAP, SRG and DESFA in September 2023 11 Whereas1:: On August 29th 2011, TAP AG submitted to the Italian Ministry of Economic Development and on August 31st 2011 to the Regulatory Authority for Energy of Greece (RAE), an “Exemption Application for Trans Adriatic Pipeline”, as foreseen by Article 36 of the Gas Directive 2009/73/EC. On September 1st 2011, TAP AG submitted to the Energy Regulatory Entity (ERE) of Albania an “Exemption Application for Trans Adriatic Pipeline”, in accordance with Article 22 of the Gas Directive 2003/55/EC. In June 2013 the Italian Ministry, RAE and ERE took the decision on the exemption, adopting the Final Joint Opinion (hereafter: “the FJO”), a document jointly written by ARERA, ERE and RAE (hereafter: “the Authorities”) and amended to comply with the Commission Decision [C

(2013)2949 final] dated 16th of May 2013 and to take note of the Opinion 1/2013 of the Energy Community Secretariat dated 14th of May

1. In November of the same year, the Authorities approved TAP’s Tariff Code
2. In the FJO an exemption from the provisions of Articles 9 (Unbundling), 32 (TPA) for the Initial Capacity of 10bcm/y, and 41.6, 41.8, 41.10 (Regulated Tariffs) of the Gas Directive has been granted to TAP AG for a period of 25 years starting from the beginning of the Commercial Operation Date, under several conditions. Among others, according to Article 4.1.7 of the FJO, TAP AG is obliged to perform Market Tests on a regular basis starting no later than the Commercial Operation Date and, subsequently, at least every two years. TAP AG shall perform Market Tests under guidelines approved by the Authorities, with the view to offer to all Interested Parties additional available capacity up to the Total Capacity of 20 bcm/y
3. Following Article 4.1.7, TAP AG is obliged to fulfil the binding capacity requests resulting from each market test taking into account the provisions of points 3, 6 and 9 of §4.7 of the FJO. The expansion takes place if it is economically viable, namely if the incremental revenues from capacity resulting from each market test are equal or larger than the efficient incremental costs, quantified according to the TAP AG methodology as laid down in the TAP Tariff Code. Additional terms to safeguard full compliance to the criteria of Article 36.1 of the Gas Directive were also imposed, among others, the obligation to build additional entry and exit points in Greece and Albania upon request of a third party, as a result of any market test, as long as such construction is technically feasible. The burden of proof to demonstrate that the construction of such additional entry and exit point is not technically feasible rests with TAP AG. If requested by the Authorities, TAP AG is to provide an opinion from an independent third party. All costs related to the construction and operation of such entry and exit points will be borne by the third party who made the request, according to the national legislation in place at the time of the request. Costs related to such entry and exit points will not include the investments required for additional capacity of TAP, resulting from §4.1 of the FJO, which will be remunerated through TAP Tariffs. On March 16th 2017, the EU Regulation 459/2017 “establishing a network code on capacity allocation mechanisms in gas transmission systems and repealing Regulation (EU) No 984/2013” was adopted. The EU Regulation 2017/459 (hereafter: CAM NC) establishes a Network Code setting up capacity allocation mechanisms in gas transmission systems for both existing and incremental capacity. 1 Hereafter the definitions of the Final Joint Opinion and of EU Regulation 2017/459 apply. 2 TAP’s Tariff Code was amended in
4. Following Article 4.1.9, the possibility to further expand capacity beyond the Total Capacity, (i.e. beyond 20 bcm/year), shall be investigated by TAP AG and if economically and technically feasible, it will be undertaken, with a view to fulfil all requests for long-term capacity (long-term means here a duration of more than 15 years). 3 12 On June 11th 2021, TAP AG submitted to the Authorities the “Guidelines for the 2021 Market Test of Trans Adriatic Pipeline Guidelines” for the incremental capacity process, seeking to align the related provisions of the Final Joint Opinion with EU Regulation 2017/459, in particular by coordinating the expected timeline/deadlines and by strengthening the cooperation with adjacent TSOs. On June 28th 2021, (ARERA Deliberation 273/2021/R/gas), on June 29th 2021 (ERE’s Decision No.151), on July 1st 2021 (RAE’s Decision 517/2021), respectively, ARERA, ERE and RAE approved the Guidelines. The main points of the Guidelines relevant for the present decision are:
5. the incremental capacity process is split into two phases, a non-binding phase (that includes the demand assessment and the design of expansion) and a binding phase (that includes an information period and a binding bidding phase);
6. the above-mentioned phases shall include all steps described in CAM NC to allow participants to submit binding bids for capacity allocation;
7. the procedure is open to all Interested Parties, namely any legal person who is interested in submitting non-binding and binding capacity demand indications to TAP AG and to participate in TAP’s Market Test in a transparent and non-discriminatory manner;
8. during the Market Test, all Interested Parties can request expansion of the entry and/or of the exit capacity on the TAP Transportation System, as well the construction of new entry and/or exit points along TAP’s transportation system;
9. Interested Parties must submit to the Authorities a declaration to ensure that their nonbinding demand indication complies with any applicable Capacity Caps; they have also to confirm to TAP AG, at least two weeks prior to the end of Assessment Phase that the Authorities have deemed the request compliant with capacity caps.
10. the binding phase is sketched in the proposed Guidelines because its detailed rules will depend on the demands received during the non-binding phase and will be subject to further approval by Authorities. On 5th July 2021, TAP AG, launched the non-binding phase of the Incremental Capacity Process on the Trans Adriatic Pipeline, in coordination with Snam Rete Gas (SRG) and DESFA. The three TSOs received non-binding demand indications and produced a joint Demand Assessment Report (DAR), published on the 25th of October 2021, concluding that there was sufficient indicative demand to initiate an Incremental Capacity Project. In January 2022, SRG, DESFA and TAP AG in accordance with the provisions set out in article 27

(3)of CAM NC, jointly launched a public consultation on the identified draft Project Proposal written with the purpose to meet, to the extent possible, the received indicative non-binding demand requests. The joint Project Proposal was approved by the Authorities in November 2022, in accordance with the provisions set in article 28 of the CAM NC and the binding phase started with the publication of the Project Proposal on TAP AG's web site the 14th of November

1. After the “information phase”, Binding Bids were submitted by interested parties and the capacity corresponding to the first offer level was allocated during the month of December 2022, on a long term basis with gas delivery starting from 2026 at entry or exit points in Kipoi, Nea Mesimvria, Relievi Roskovec, Melendugno. 13 The Project Proposal envisaged a possible second binding phase in 2023 to be carried out in the sole discretion of the TSOs, to be notified to the Authorities. The second Binding Phase includes the same phases of the first one (Information Phase, and Binding Bidding Phase, followed by capacity allocation, EVT and GTA). On 22 September 2023 TAP AG, SRG and DESFA submitted for approval a new joint Project Proposal for the 2nd binding phase of the 2021 Market Test procedure, in accordance with the provisions set in Article 28 of the CAM NC
2. According to CAM (Article 28.2), the NRAs should publish coordinated decisions on the project proposal, considering the views of the other national regulatory authorities involved. Therefore, the present joint decision is taken without prejudice for the NRAs involved to supplement it with further decisions falling within their competence, namely all aspects related to TAP connection with their respective national systems. Whereas: The incremental capacity project of the second binding phase for the 2021 Incremental Capacity Process concerns 7 (seven) Interconnection Points (IPs) along the route of the TAP: Kipoi (TRGR), Komotini (GR), Nea Mesimvria (GR) , Kucove (AL), Relievi Roskovec (AL), Fier (AL), and Melendugno (IT). In particular, the Incremental Capacity Project comprises the following: a. Incremental capacity offered jointly by TAP and SRG as a bundled capacity product at the IP of Melendugno exit TAP and entry SRG; b. Incremental capacity offered jointly by TAP and DESFA at the IP of Nea Mesimvria as a bundled capacity product exit DESFA and entry TAP; c. Incremental capacity offered by TAP at the IP Kipoi as unbundled entry capacity; d. Incremental capacity offered by TAP at the IP Komotini as unbundled exit capacity; e. Incremental capacity offers by TAP at prospective Kucove exit point as unbundled exit capacity; f. Incremental capacity offer by TAP at prospective Fier exit point as unbundled exit capacity; g. Incremental capacity offer by TAP at prospective Fier entry point as unbundled entry capacity; h. Incremental capacity offered by TAP as unbundled exit capacity at the prospective relevant Exit points of Roskovec. On the TAP section, the Incremental Capacity Project:
3. can be achieved by installing additional compressor units, no modifications are required to the pipeline;
4. foresees possible expansion levels with different technologies, namely, with reference to entry Kipoi: a. “limited expansion”, variant 1A: upgrade of existing stations + addition of 3 gas compression units. Incremental capacity offer level of 4.7 MSm3/d (45.3 GWh/day); 4 On the 3rd of October a replacement of the document (version of the 26th of September) was sent by TAP AG, SRG and DESFA for a minor corrigendum in section G.1.3, which concerns only SRG. 14 b. “limited expansion”, variant 1B: upgrade of existing stations + addition of 4 electric compression units. Incremental capacity offer level of 6.3 MSm3/d (61.2 GWh/day); c. “limited expansion”, variant 1C: upgrade of existing stations + addition of 5 electric compression units. Incremental capacity offer level of 10.1 MSm3/d (97.4 GWh/day); d. “partial expansion”: upgrade of existing stations + addition of 7 electric compression units. Incremental capacity offer level of 11.6 MSm3/d (112.3 GWh/day); e. “full expansion”: upgrade of existing stations + addition of 10 electric compression units. Incremental capacity offer level of 21.1 MSm3/d (204.6 GWh/day);
5. sets capacity at the TAP IPs, consistent with the expansion levels at entry Kipoi and the already available capacity, on SRG side and expansion projects of DESFA;
6. set the offer levels in kWh/d at all entry and exit points consistent with the abovementioned technical capacity and taking into: a. account a GCV value of 9,71 kWh/Sm3 and b. the need to set aside 10% of the expansion capacity for short term bookings. To increase the possibility that the economics for the Incremental Capacity Project are passed in accordance with the provisions of art. 30

(1)of CAM NC and considering TAP’s specific regulatory framework as well as the findings of the non-binding demand indications, SRG, TAP AG and DESFA propose a number of measures: 1. the application of an Alternative Allocation Mechanism (“AAM”) with an extended capacity booking horizon of 20 years after the start of the operational use, as all conditions set in Article 30

(2)of CAM are met;

1. the requirement of a minimum commitment for duration of at least 3 consecutive years, as documented to the Authorities by TAP AG, SRG and DESFA;
2. the requirement for participants to submit a reduced bid bond (during the bidding phase) and the full amount in a second phase, to secure the coverage of investments made by TAP before the COD;
3. the possibility for TAP to propose to the user that part of the capacity be made available in advance of the date contained in the offer. This measure avoids the first delivery of gas takes place only once the entire demand for capacity has been met;
4. the conclusion of the process before the starting of the binding phase of the new Incremental Capacity Process initiated in June 2023; In accordance with the provisions of article 30

(3)of the CAM NC, TAP AG, DESFA and SRG intend to allow interested parties to submit binding bids on the following basis as all conditions for AAM are met: • commitment at one IP linking commitments at other IP(s); • commitments across a number of different standard yearly capacity products; • commitments conditional on the allocation of a minimum amount of capacity. 15 In the light of the characteristics of the Incremental Capacity Project, the proposed AAM intends to prioritize bids depending on their booking durations, in accordance with article 30

(4)of the CAM NC. The TSOs propose the following timeline: • 20th October 2023 – 15th December 2023: information phase • 16th December 2023 – 31st January 2024: binding bidding phase 2, including capacity allocation and Execution of GTAs. The first gas through the expansion capacity is expected to be delivered in the time period from Q4 2027 to the end of 2028, depending on the reached offer level and the delivery point. The economic test is carried out separately by each TSO at their side of the relevant IP and incremental capacity project shall be initiated if the economic test has a positive outcome on both sides of TAP interconnection points for at least one offer level. Market test and ranking criteria are specified in the Project Proposal separately for each TSO. Whereas: • the project proposal is in line with the principles stated in the Final Joint Opinion, the approved Guidelines, the CAM NC and does not introduce undue barriers to the foreseen process for building incremental capacity; • the project has been developed in cooperation with adjacent TSOs, with the aim of ensuring a coordinated development of the network; • all the information listed in Article 28 of CAM NC are included in the project proposal; • the conditions set out in Article 30

(2)of CAM NC for the potential application of an AAM are achieved, considering that the project involves more than two entry-exit systems, bids are requested along several interconnection points and bids with a duration of more than 1 year are requested; • the economic parameters proposed by TAP AG are in line with the TAP Tariff Code; • the other economic parameters are verified by the competent authority in each country and are in line with the respective tariffication systems the Authorities jointly approve the “Project Proposal of TAP, SRG and DESFA for the 2021 Incremental Capacity Process – 2nd Binding Phase” jointly proposed by TAP AG SRG and DESFA and attached as ANNEX B. 16 ΠΑΡΑΡΤΗΜΑ Β Project Proposal of TAP, SRG and DESFA for the 2021 Incremental Capacity Process 2nd Binding Phase Submission to NRAs September 2023 This document is published at the websites of TAP, SRG and DESFA in accordance with Article 28 of Regulation (EU) No 2017/459 of 16 March

1. ANNEX B This document is jointly elaborated and published by: Snam Rete Gas S.p.A. Piazza Santa Barbara, 7 20097 San Donato Milanese Trans Adriatic Pipeline AG Lindenstrasse 2 357-359 Messogion Ave., 6340 Baar Athens, 15231 Switzerland Greece Italy T: +41 41 747 3400 T: + +39.
2. 370.38300 Key 8 F: +41 41 747 3401 E: market.test@tap-ag.com E: ipa@snam.it DESFA SA www.tap-ag.com www.snam.it 2 T: +302130884000 F: +302130884062 E: market-test@desfa.gr www.desfa.gr ANNEX B Table of Contents Introduction 5 Description of the incremental capacity project and cost estimates 8 A.1 Market demand for incremental capacity 8 A.2 Description of the Incremental Capacity Project 9 B. Offer Levels (Art. 28

(1)lit. a NC CAM) 14 C. Alternative allocation mechanism (Art.27

(3)lit. c, f NC CAM) 17 D. Provisional Timeline of the incremental capacity project (Art. 27

(3)lit.d CAM NC) 18 D.1 Incremental capacity cycle timeline 18 D.2 Duration of project realization 19 E. General rules and conditions for Binding Phase (Art. 27

(3)lit. e NC CAM) 21 E.1 Participation criteria and Registration 22 E.2 Binding Bid content 27 E.3 Bid Evaluation 28 E.4 Preliminary Capacity Allocation Procedure (Bid Ranking) 28 Competing Procedure in SRG’s system 29 E.5 Allocation of Equal Marginal Bids (EMB) 32 E.6 Economic Viability Test 33 E.7 Gas Transportation Agreement (“GTA”) 35 E.8 Project progress, lack of permits, delays in making available transportation capacity 47 E.9 Force Majeure 47 E.10 Element IND and RP for fixed price approach (Art. 28

(1)lit. g NC CAM) 48 G. Economic Test Parameters (Art. 28

(1)lit.d CAM NC) 49 G.1 Economic test parameter for SRG 49 G.1.4 F-factor (Art. 22

(1)lit.c NC CAM) 50 G.2 Economic test parameter for DESFA - G.2.1 Reference Price (Art. 22

(1)lit. a No. i NC CAM) 50 H. Additional demand Indication 52 H.1 Contact information 52 Annex I - TAP Specific Provisions 53 Annex II – Definitions and Abbreviations 56 3 ANNEX B Disclaimer Each TSO has acted in good faith to ensure that the information in this Project Proposal is correct as at the date of this Project Proposal, however no representation or warranty is made by any TSO as to the accuracy or completeness of such information and the TSOs will not accept any liability, of any kind, to each other or to any third party, for any inaccuracies or incompleteness in such information. Furthermore, the TSOs shall have no obligation to update the Project Proposal for any changes arising after the date of issue of the Project Proposal. Nonetheless, if new or revised information is provided in the Project Proposal, the TSOs shall have no liability to each other or to any third party. Furthermore, whilst each of the TSOs will endeavour to co-ordinate the processes and steps anticipated under this Project Proposal, no TSO will have any liability to any third party for any acts, omissions, breaches or decisions of the other TSOs or any other third party. 4 ANNEX B Introduction Commission Regulation (EU) 2017/459 of 16 March 2017 establishing a network code on Capacity Allocation mechanisms in gas transmission systems (Regulation, also referred to as CAM NC) establishes a harmonised European Union wide process for the offer of incremental capacity between Member States. CAM NC became applicable in Albania as a contracting party to the Energy Community Treaty from 28 February 2020. The rules for the allocation of capacity for this Incremental Capacity Project as set out in this document consider the specific regulatory framework of TAP according to the Final Joint Opinion issued by the National Regulatory Authorities of Italy (ARERA), Greece (RAE) and Albania (ERE), collectively referred to here as the Authorities dated 6 June 2013 (FJO). TAP is exempted from certain provisions on third party access, regulated tariffs and ownership unbundling of Directive 2009/73/EC, subject to terms and conditions set by the FJO. The exemption from regulated tariffs and ownership unbundling also applies to TAP’s Expansion Capacity (being capacity made available in the TAP Transportation System in addition to the Initial Capacity, up to 10 BCMA). Expansion Capacity is offered in compliance with the third-party access principles. Thus, the Expansion Capacity of TAP will be offered following the Capacity Allocation rules as set by the CAM NC to the extent they do not conflict with the FJO (as per paragraph 4.6 of the FJO) and consequent tailor-made regulatory framework as summarised in Annex I of this Project Proposal. Following the launch of the Incremental Capacity Process in July 2021, Trans Adriatic Pipeline (TAP), Snam Rete Gas (SRG) and DESFA have received non-binding demand indications and produced a joint Demand Assessment Report (DAR), which was published on the 25th of October 2021 with the conclusion that there was sufficient indicative demand to initiate an Incremental Capacity Project. In January 2022, SRG, DESFA and TAP in accordance with the provisions set out in article 27

(3)of CAM NC, jointly launched a public consultation on the draft Project Proposal elaborated in line with the indicative non-binding demand requests. The TSOs have received comments during the public consultation from 2 (two) stakeholders. These comments, as well as more general market environment considerations and stakeholder engagement processes,1 have been considered to the extent possible in the subsequent design phase of the Incremental Capacity Project. A first Binding Phase was initiated through the publication of a Project Proposal on 14 November 2022, resulting in the allocation of capacity as published on 31 January 2023. That Project Proposal also included provisions for a second Binding Phase, that could be launched later in 2023. This updated Project Proposal governs such second Binding Phase and has been jointly prepared by SRG, TAP and DESFA in accordance with the provisions set out in article 28 of the CAM NC as Project Proposal for the Incremental Capacity Project of the involved TSOs. This updated Project Proposal is submitted to the Authorities for their evaluation and coordinated approvals. In particular, the Incremental Capacity Project comprises the following: • Incremental capacity offered jointly by TAP and SRG at the IP of Melendugno as a bundled capacity product exit TAP and entry SRG. • Incremental capacity offered jointly by TAP and DESFA at the IP of Nea Mesimvria as a bundled capacity product exit DESFA and entry TAP. 1 On 18 July 2022, the EU and Azerbaijan signed a Memorandum of Understanding on a Strategic Partnership in the Field of Energy. It includes a commitment to double the capacity of the Southern Gas Corridor to deliver at least 20 billion cubic metres to the EU annually by 2027. 5 ANNEX B • • • • • • Incremental capacity offered by TAP at the IP Kipoi as unbundled entry capacity. Incremental capacity offered by TAP at the IP Komotini as unbundled exit capacity. The capacity offered reflects available TAP exit point capacity at IP Komotini without factoring in any expansion capacity in IGB. Accordingly, Participants will be solely responsible for ensuring that corresponding expansion capacity is available on the other side of the IP Komotini with IGB, and TAP offers no guarantee and has no liability to Participants in this regard. Participants should also note that IGB itself will not be participating as an adjacent TSO in the market test. Incremental capacity offers by TAP at prospective Kucove exit point as unbundled exit capacity.2 Incremental capacity offer by TAP at prospective Fier exit point as unbundled exit capacity.3 Incremental capacity offer by TAP at prospective Fier entry point as unbundled entry capacity.4 Incremental capacity offered by TAP as unbundled exit capacity at the prospective Exit point of Roskovec.5 This Incremental Capacity Project is primarily driven by potential increases of the technical capacity at IPs along the TAP pipeline route. If infrastructure upgrades necessary for the Incremental Capacity Project are realised by the interconnected TSOs, then additional natural gas flows from the Greek-Turkish border, Greece or Albania will potentially reach downstream markets. Hence, this Incremental Capacity Project is conducted in close coordination by TAP, SRG and DESFA, to enable the offering of capacities at the IPs shared by the TSOs concerned. Notwithstanding such co-ordination, each TSO will be responsible for its own infrastructure upgrades and the other TSOs shall not have any liability to any party for the undertaking, or fail to undertake, such infrastructure upgrades. Note that volumetric capacity of technical solutions will be quoted in Sm3 or Nm3, while incremental capacity to be offered for booking in each Binding Phase will be quoted in kWh/day. 2 It is the responsibility of the Participant to initiate any procedures that may be necessary for capacity to be made available downstream of TAP. TAP makes no representation as to the availability of such capacity or to the existence of required facilities outside of TAP. 3 It is the responsibility of the Participant to initiate any procedures that may be necessary for capacity to be made available downstream of TAP. TAP makes no representation as to the availability of such capacity or to the existence of required facilities outside of TAP. 4 It is the responsibility of the Participant to initiate any procedures that may be necessary for capacity to be made available upstream of TAP. TAP makes no representation as to the availability of such capacity or to the existence of required facilities outside of TAP TAP makes no representation as to the availability of capacity downstream of TAP or to the existence of required facilities outside of TAP. 6 ANNEX B Indicatively, a convention of a minimum Gross Calorific Value (“GCV”) of 9.716 kWh/Sm3 (10.23 kWh/Nm3) can be applied for conversion between capacity in volume and in energy. 6 For Melendugno IP the offer levels were calculated considering the existing contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 7 Description of the incremental capacity project and cost estimates A.1 Market demand for incremental capacity Non-binding demand indications by IP are described in detail in the DAR published by TAP, SRG and DESFA on 25 October 2021.7 The following summarises high-level conclusions from the DAR relating to the non-binding requests for Forward Firm capacity: - - - At Kipoi IP the non-binding requests equal 5,500,000 kWh/day from 2024/25 until gas year 2030/31. At Melendugno IP, non-binding requests peak at 60.700.000 kWh/day in the period 20262032. They then gradually reduce to 26.500.000 kWh/day in the period 2032-2036. No requests were received for the period beyond 2040. Note that out of these numbers, only demand for 15,000,000 KWh/d was received by both TAP and SRG, for the period 2021/22 - 2030/31. At Nea Mesimvria IP, non-binding requests (for exit from the DESFA system and – entry into the TAP pipeline) are equal to 15,000,000 kWh/day for the period 2021/22-2022/23. After this period, the requested capacity is equal to 30,000,000 kWh/day until gas year 2030/31. At IP Kucove, TAP has received non-binding requests equal to 7,500,000 KWh/d from gas year 2023/24 until gas year 2030/31. At IP Fier, TAP has received non-binding requests equal to 7,500,000 KWh/d from gas year 2023/24 until gas year 2030/31. At Roskovec exit point, TAP has received non-binding requests equal to 5,500,000 KWh/d from gas year 2024/25 until gas year 2030/31. Connection Requests received for TAP a. In addition to non-binding capacity requests, TAP has received the following non-binding connection requests for:

1. a)an exit point at Relievi Roskovec, Albania, with a technical capacity of 7,500,000 KWh/d.
2. b)an exit point at Kucove, Albania, with a technical capacity of 7,500,000 KWh/d.
3. c)2 (two) non-binding connection requests concerning Fier (with technical capacity requested for an exit of 7,500,000 kWh/d and entry of 1.8 BCMA respectively), potentially making the interconnection point bidirectional. The DAR concluded that the demand indications received by TAP, SRG and DESFA were enough to initiate the design phase of an Incremental Capacity Project in accordance with paragraph 2 of Article 26 of NC CAM. Capacity Allocation under the first Binding Phase The following aggregate capacity has been allocated as part of the first Binding Phase: 7 This section refers to the non-binding phase of the 2021 market test. Non-binding demand indications received following the launch on 3 July 2023 of the non-binding phase of the 2023 market test will be addressed in the Demand Assessment Report of that market test. 8 - Entry capacity to TAP at Kipoi IP of 32,829,131 kWh/day from 1 January 2026 until 31 December 2028. Exit capacity from DESFA and Entry capacity to TAP at Nea Mesimvria IP of 5,000,000 kWh/day from 1 October 2026 until 30 September 2033 Exit capacity from TAP at the exit point of Roskovec of 5,000,000 kWh/day from 1 October 2026 until 30 September 2033 Exit capacity from TAP and entry capacity to SRG at Melendugno IP of 32,829,131 kWh/day from 1 January 2026 until 31 December 2028. The holders of capacity in the TAP pipeline have an option to extend the duration of bookings until 14 November 2045, subject to conditions as set out in the Project Proposal published on 14 November 2022 governing the first Binding Phase8. The capacity allocated as part of such first Binding Phase (including capacity booked in the TAP pipeline in respect of which Participants may exercise the extension option described above) has been set aside and accounted for in order to calculate the Offer Levels for this second Binding Phase. As set out in Section E of the Project Proposal published on 14 November 2022 in respect of the first Binding Phase (and in Section E of this Project Proposal below), if TAP would be prevented from allocating capacity as a result of such option to extend, TAP may notify the relevant Participant that the latest end date for the extension is curtailed to an earlier date. A.2 Description of the Incremental Capacity Project Based on the capacity requests received in the non-binding demand indication phase (as well as the capacity allocated as part of the first Binding Phase), TAP, SRG and DESFA have started analysing potential infrastructure developments in their respective transmission systems to fulfil interested parties’ requests. The next paragraphs provide further information on the alternatives and associated costs for each of the TSOs. We note that investment costs provided in the descriptions below are established in line with established regulatory practices, as individually applicable to each TSO. A.2.1 TAP Following the capacity allocation under the first Binding Phase, TAP has identified the following remaining alternative Expansion Projects:9 a. Level 1: TAP limited expansion – to an actually built total capacity entry Kipoi ranging from 45 to 51 MSm3 per day (437 – 495 GWh/day) (Limited Expansion Project) b. Level 2: TAP partial expansion – to an actually built total capacity entry Kipoi of 52.7 MSm3 per day (511 GWh/day) (Partial Expansion Project) c. Level 3: TAP full expansion – to an actually built total capacity entry Kipoi of 63.2 MSm3 per day (614 GWh/day) (Full Expansion Project) 8 Please note that this provision included in the Project Proposal published on 14 November 2022 does not give Par- ticipants any priority right in purchasing the corresponding capacity on the adjacent TSO system. 9 Volumetric capacities noted in this TAP section for entry Kipoi are the outcome of hydraulic simulations assuming gas with a minimum GCV in accordance with the TAP Network Code (9.71 kWh/Sm3), with the corresponding energy content shown in brackets. 9 The TAP pipeline expansion can be achieved by installing additional compressor units at the compressor stations GCS00 (Kipoi) and ACS03 (Fier) and/or by the construction of the additional compressor stations GCS01 (Serres) and ACS02 (Bilisht). No major modifications are expected to be required to pipeline sections between compressor stations. The extent of the expansion depends on the firm demand for the Expansion Capacity. The expansion projects described in this document (including the estimated technical capacities) may be subject, in TAP’s sole discretion, to adjustment during their development, which may include optimisation based on the Binding Bids received by TAP. The different indicative infrastructural development configurations, with preliminary cost estimates according to cost risk analysis based on pre-FEED studies, are described in the following paragraphs: Level 1: TAP Limited Expansion Project TAP has identified three alternative configurations for the Limited Expansion Project. The project to be selected will depend on the composition and timing of binding bookings. The three alternative configurations are as follows: Level 1A: TAP Limited Expansion Project (gas) The required works for expansion to allow transportation of up to 45 MSm3/day (437 GWh/day) from Q4 2027 are: ▪ ▪ ▪ ▪ GCS00: Upgrade of the existing compressor station with the addition of 1 compressor unit (approx. 15 MW), including relevant facilities, process and utility upgrade; ACS02: no infrastructure upgrade required; ACS03: Upgrade of the existing compressor station with the modification of the internals of existing compressors and the addition of 2 compressor units (approx. 15 MW each), including relevant facilities, process and utility upgrade; IPR01: Upgrade of the metering and pressure reduction station. The cost of this project is estimated to be approximately 457 M€10. The cost estimate may be amended and notified through the publication of the TAP section of the Joint Notice, depending on the availability of further technical information at such time. Level 1B: TAP Limited Expansion Project (electric - 35 MW) The required works for expansion to allow transportation of up to 46.8 MSm3/day (455 GWh/day) from end 2028 are: ▪ ▪ GCS00: Upgrade of the existing compressor station with the addition of 1 electrical compressor unit (approx. 35 MW), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS02: no infrastructure upgrade required; Class 4 estimate, in accordance with AACE® International Recommended Practice Cost Estimate Classification System-as applied in Engineering Procurement and Construction for the Process Industries No. 18R-97. The cost estimate includes a contingency that reflects the class 4 accuracy of the estimate and any applicable allowance. 10 10 ▪ ▪ ACS03: Upgrade of the existing compressor station with the addition of 3 electrical compressor units (approx. 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; IPR01: Upgrade of the metering and pressure reduction station. The cost of this project is estimated to be approximately 768 M€11. The cost estimate may be amended and notified through the publication of the TAP section of the Joint Notice, depending on the availability of further technical information at such time. Level 1C: TAP Limited Expansion Project (electric – Bilisht first) The required works for expansion to allow transportation of up to 51 MSm3/day (495 GWh/day) from end 2028 are: ▪ ▪ ▪ ▪ GCS00: Upgrade of the existing compressor station with the addition of 2 electrical compressor units (approx. 30 – 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS02: Upgrade of the existing metering station to become a compressor station with the addition of 3 electrical compressor units (approx. 30 - 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS03: Main process piping tie-ins to avoid future pipeline capacity flow restrictions in case of any subsequent expansion steps; IPR01: Upgrade of the metering and pressure reduction station. The cost of this project is estimated to be approximately 974 M€12. The cost estimate may be amended and notified through the publication of the TAP section of the Joint Notice, depending on the availability of further technical information at such time. Please note that these three alternative configurations for the Limited Expansion are mutually exclusive. Also, only Level 1C is directly compatible with the Partial and Full Expansion steps as defined below. Level 1A is included as it allows capacity to be made available earlier, given that it relies on the same design as published for the first Binding Phase. Level 1B uses electric compressor units (of larger power), providing more capacity while not requiring the construction of a new compressor station. Level 1C uses electric compressor units, requires a new compressor station and is fully compatible with the revised design for TAP’s Partial and Full Expansion as given below. Level 2: TAP Partial Expansion Project The required works for expansion to allow transportation of up to 52.7 MSm3/day (511 GWh/day) Class 4 estimate, in accordance with AACE® International Recommended Practice Cost Estimate Classification System-as applied in Engineering Procurement and Construction for the Process Industries No. 18R-97. The cost estimate includes a contingency that reflects the class 4 accuracy of the estimate and any applicable allowance. 12 Class 4 estimate, in accordance with AACE® International Recommended Practice Cost Estimate Classification System-as applied in Engineering Procurement and Construction for the Process Industries No. 18R-97. The cost estimate includes a contingency that reflects the class 4 accuracy of the estimate and any applicable allowance. 11 11 from end 2028 are: ▪ ▪ ▪ ▪ GCS00: Upgrade of the existing compressor station with the addition of 2 electrical compressor units (approx. 30 - 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS02: Upgrade of the existing metering station to become a compressor station with the addition of 3 electrical compressor units (approx. 30 – 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS03: Upgrade of the existing compressor station with the addition of 2 electrical compressor units (approx. 30 – 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; IPR01: Upgrade of the metering and pressure reduction station. The cost for this project is estimated to be approximately 1349M€.13 The cost estimate may be amended and notified through the publication of the TAP section of the Joint Notice, depending on the availability of further technical information at such time. Level 3: TAP Full Expansion Project The required works for expansion to allow transportation of up to 63.2 MSm3/day (614 GWh/day) from end 2028 are: ▪ ▪ ▪ ▪ ▪ GCS00: Upgrade of the existing compressor station with the addition of 2 electrical compressor units (approx. 30 - 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; GCS01: Upgrade of the existing scraper facility to become a compressor station with the installation of 3 electrical compressor units (approx. 30 - 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS02: Upgrade of the existing metering station to become a compressor station with the addition of 3 electrical compressor units (approx. 30 - 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; ACS03: Upgrade of the existing compressor station with the addition of 2 electrical compressor units (approx. 30 - 35 MW each), including relevant facilities, process and utility upgrade as well as required electric infrastructure, such as grid connection and electric substation; IPR01: Upgrade of the metering and pressure reduction station; The cost for this project is estimated to be approximately 1814 M€.14 The cost estimate may be amended and notified through the publication of the TAP section of the Joint Notice, depending on the availability of further technical information at such time. 13 14 See footnote above. See footnote above. 12 A.2.2 SRG Level 1A (35,3 MSm3/day - 378 GWh/day15 ), Level 1B (37,1 MSm3/day – 395,7 GWh/day16 ), Level 1C (41,2 MSm3/day – 435,9 GWh/day17 ) and Level 2 (43 MSm3/day – 452,4 GWh/day18) Entry Melendugno The already existing infrastructures are already sized to deliver these Offer Levels, and so no additional investments are needed on SRG’s side of the IP. Level 3 (53,5 MSm3/day - 555 GWh/day19 ) The additional infrastructures needed to guarantee Offer Level 3, are: • The upgrades of the regulation and measurement plant in Melendugno; • Regulation plant in Moliterno (SRG NDP NR/15438); • Matagiola-Massafra pipeline, increasing the maximum capacity at the entry point in Puglia. An estimate of the overall total costs for all described interventions could amount up to around 270 M€. Costs have been estimated according to industry best practices and specific regulatory provisions (e.g., cost estimate methodology for CBA), The already existing infrastructures, complemented by the above-mentioned additional infrastructures, are required to deliver Offer Level 3. Capacity offered at Melendugno IP for all levels will be in competition on the SRG side with the other IPs of Mazara and Gela: the capacity allocation will be subject to a constraint reflecting the maximum simultaneous capacity transportable at these IPs as indicated in Paragraph E.4 SRG Section. The specific and detailed operating competing procedure for the allocation of capacity at the above-mentioned IPs in the SRGs system, including a full description of participation requirements, the competing mechanism as well as the bid ranking functioning, is defined in Paragraph E.4 SRG Section of this document. A.2.3 DESFA The level of incremental capacity offered by DESFA in the framework of this incremental process, is calculated considering the existing technical capacities of DESFA’s Gas System entry points, as well as the already approved projects in the frame of DESFA’s TYNDP. Nea Mesimvria connects the Greek System with TAP pipeline. One compression station (CS) is operating at Nea Mesimvria. A new CS is also planned at Ampelia area as well as the upgrade of the existing CS at Nea Mesimvria. Also, a new CS (booster) is planned at Nea Mesimvria in order to enable reversal of flow towards TAP. The upgrades of the transmission system included in DESFA’s 15 For Melendugno IP, the offer levels were calculated considering the existing contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 16 For Melendugno IP, the offer levels were calculated considering the existing contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 17 For Melendugno IP, the offer levels were calculated considering the existing contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 18 For Melendugno IP, the offer levels were calculated considering the existing contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 19 For Melendugno IP, the offer levels were calculated considering the existing contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 13 TYNDP are considered as a prerequisite for the hydraulic simulation and the calculation of the Offer Level(
4. s)by DESFA. DESFA has executed preliminary technical studies in order to identify the investments needed to make incremental capacity available at the IP Nea Mesimvria. These technical studies refer to flows from DESFA’s towards TAP’s gas system in the IP Nea Mesimvria. DESFA has not received any non-binding requests for incremental capacity in the direction from TAP towards DESFA’s gas System. DESFA has included in the already approved by RAE TYNDP, a new booster compressor at Nea Mesimvria in order to facilitate flows from DESFA’s gas System towards TAP. This booster Compressor will enable DESFA to offer firm capacity products at the exit point Nea Mesimvria. The compressor is expected to have been completed by the end of Q3 2024 and the commercial operation date is expected at Q4 2024. The impact of the incremental flows through Nea Mesimvria exit point was examined performing hydraulic simulations of the transmission system in a highly loading hydraulic case. The result is that the level of the flow can be covered without any new investments after the completion of the above-mentioned booster CS. The investments levels are the following: Exit capacity at Nea Mesimvria Level 1: incremental capacity of 25 GWh/day The already projected infrastructure would be enough to deliver this Offer Level, and so no additional investments are needed on DESFA’s side of the IP. The above-mentioned Offer Level has as a prerequisite the completion of the planned Ampelia CS and the booster Compressor Station at Nea Mesimvria, already included in DESFA’s approved 10-year Network Development Plan. B. Offer Levels (Art. 28

(1)lit. a NC CAM) According to the different project configurations described above it will be possible to propose distinct Offer Levels for each IP. The Offer Levels may be combined in different ways, depending on the overall set of Binding Bids received. Please note that the capacities at the different TAP Entry and Exit Points are not cumulative. They may be in competition with each other. On the other hand, the capacities for the different technical solutions as set out in Section A.2.1 above, assume that all new bookings utilise the full pipeline length (i.e., the thresholds for TAP Entry Kipoi found below are based on hydraulic simulations assuming entry bookings are linked with the same amount of bookings for TAP Exit Melendugno). Readers should also note the terms of Section E.6 in connection with Annual Requests made in respect of TAP. The Offer Levels in the tables below – providing an overview of capacities jointly offered at all IPs - represent the capacity that could be allocated in this Binding Phase of this Incremental Capacity Project as long-term capacity (considering any available capacity net of the already booked capacity (and including extension options in respect of capacity booked in the TAP pipeline, as described at A.2 above) and the capacity to be reserved for short term bookings). In order to guarantee firm transportation service, the levels are also calculated based on all gas to be transported through the TAP pipeline having a minimum GCV of 9.71 kWh/Sm3 (36.84 MJ/Nm3 or 14 10.23kWh/Nm3).20 Please note that the starting dates in the tables below assume that the capacity allocation process in this Binding Phase will take place in January 2024.21 Please further note that the earliest starting date of offered capacity at any IP of TAP in this Binding Phase is around end 2028, unless capacity is allocated as part of Level 1A TAP Limited Expansion project (gas) , in which case the starting date of offered capacity may be during Q4 2027. Because the technical solution for Level 1A is not a building block of any of the technical solutions for the other TAP Offer Levels identified in this Project Proposal, offered capacity commencing in Q4 2027 is not compatible with offered capacity under a higher Offer Level which will have a starting date around end 2028 (i.e. a phased expansion cannot be assumed to be possible under this Binding Phase).22 Kipoi Offered Capacity (kWh/

1. d)Level 1A Level 1B Level 1C Level 2 Level 3 Starting date Q4 2027 End 2028 End 2028 End 2028 End 2028 Capacity 45,297,040 61,196,933 97,368,428 112,270,720 204,565,936 Entry / Exit and TSO offering capacity Entry TAP Nea Mesimvria - Exit DESFA/Entry TAP Offered Capacity (kWh/
2. d)Level 1 Starting date End 2028 Capacity 25,000,000 Entry / Exit and TSO offering capacity Exit DESFA and Entry TAP Komotini Offered Capacity (kWh/
3. d)Starting date End 2028 Capacity 30,000,000 Entry / Exit and TSO offering capacity Exit TAP Kucove23 Offered Capacity (kWh/
4. d)Level 1 Starting date End 2028 Capacity 7,500,000 Entry / Exit and TSO offering capacity Exit TAP Reference conditions for normal cubic meters are 25°C for combustion and 0°C for volume at atmospheric pressure. For Melendugno IP, the offer levels were calculated considering the contracted capacity converted with a GCV equal to 11.07 kWh/Sm3 and the expansion capacity converted with a GCV equal to 9,71 kWh/Sm3. 21 Please see Section D for more details on the timing. 20 22 Please note that the realisation of Level 1A would not stop a future project proposal from including a different technical solution for a full expansion of TAP. 23 Please note that TAP makes no representation as to the existence of downstream facilities or availability of capacity at this point. 15 Roskovec24 Offered Capacity (kWh/
5. d)Level 1 Starting date End 2028 Capacity 2,500,000 Entry / Exit and TSO offering capacity Exit TAP Fier25 Offered Capacity (kWh/
6. d)Level 1 Starting date End 2028 Capacity 7,500,000 Entry / Exit and TSO offering capacity Exit TAP Fier26 Offered Capacity (kWh/
7. d)Starting date End 2028 Capacity 44,900,000 Entry / Exit and TSO offering capacity Entry TAP Melendugno 27 Offered Capacity (kWh/
8. d)Starting date28 Capacity Entry / Exit and TSO offering capacity Level 1A Level 1B Level 1C Level 2 Level 3 Q4 2027 End 2028 End 2028 End 2028 End 2028 45,297,040 61,196,933 97,368,428 112,270,720 204,565,936 Exit TAP and Entry SRG In line with the provisions of the FJO and CAM NC an amount equal to 10% of the expansion capacity will be set aside to be offered as short-term capacity, as applicable for each TSO and in addition to the numbers included in the table above. With regards to TAP’s initial project, according to Section 4.1.10 of the FJO, TAP also has an obligation to set aside 5% of the Initial Capacity for short-term auctions. 24 Please note that TAP makes no representation as to the existence of downstream facilities or availability of capacity at this point. Please note that TAP makes no representation as to the existence of downstream facilities or availability of capacity at this point. 26 Please note that TAP makes no representation as to the existence of upstream facilities or availability of capacity at this point. 27 Capacity offered at Melendugno IP will be in competition on the SRG side with other IPs of Mazara and Gela, so capacity allocation will be subject to the capacity constraints as published on SRG website. The specific operating procedure is available in the Paragraph E.4 SRG Section 25 28 Please note that the starting dates inserted for Offer Levels 1A, 1B, 1C and 2 refer to TAP availability as no works are required on SRG side since the corresponding capacity is already available at Melendugno entry point. 16 C. Alternative allocation mechanism (Art.27

(3)lit. c, f NC CAM) To increase the possibility that the economics for the Incremental Capacity Project are passed in accordance with the provisions of art. 30

(1)of CAM NC and considering TAP’s specific regulatory framework as well as the findings of the non-binding demand indications, SRG, TAP and DESFA intend to apply an Alternative Allocation Mechanism (AAM) with an extended capacity booking horizon of up to 20 years after the start of the operational use, subject to the approval of the concerned Authorities. The criteria envisaged under Article 30

(2)of CAM NC for the potential application of an AAM are achieved by this Incremental Capacity Project, on the following basis29: • The Incremental Capacity Project involves at least three entry-exit systems in the EU (TAP, SRG, DESFA), Albania and potentially other entry-exit systems in the future. • Capacity is offered at a number of IPs, as set out in the tables in Section B. • Interest concerns capacity reservations of more than 1 year. • Participants have indicated interest for commitments linking more than one IP. In accordance with the provision of article 30

(3)of the CAM NC, TAP, DESFA and SRG intend to allow interested parties to submit Binding Bids on the following basis: • Commitment at one IP linking commitments at other IP(s); • Commitments across several different standard yearly capacity products; • Commitments conditional on the allocation of a minimum amount of capacity. In the light of the characteristics of the Incremental Capacity Project, the proposed AAM prioritizes bids depending on their booking durations, in accordance with article 30

(4)of the CAM NC. In particular, TAP, SRG and DESFA give priority to commitments for durations of at least 3 consecutive years starting from the relevant E-COD and linking more than one IP along the gas route as further specified in the following parts of this document. Binding Bids will be processed subject to the Participants meeting the requirements set out in Section E.1. In the event of congestion, in order to be consistent with TAP’s specific regulatory framework (in particular the TAP Tariff Code) and to ensure coherent allocation results for interconnected TSOs, a ranking will be performed on the basis of the net present value (NPV) of incremental revenues from each Binding Bid per unit of annual capacity requested as further specified in Section E.30 29 30 Please also refer to the evidence provided in the DAR. The TAP Tariff Code does not foresee an auction except for the exceptional situation of equal marginal bids. 17 D. Provisional Timeline of the incremental capacity project (Art. 27

(3)lit.d CAM NC) This chapter describes the timeline for the conclusion of the Incremental Capacity Project (Section D.1) and provides estimates of the possible time needed for the realization of the new incremental capacity (Section D.2). D.1 Incremental capacity cycle timeline In accordance with the option set out in the Project Proposal published on 14 November 2022, the TSOs have elected to hold a second Binding Phase. This second Binding Phase will include the same phases (i.e., Information Phase and Binding Bidding Phase followed by capacity allocation, EVT and GTA entry) as under the first Binding Phase. For the avoidance of doubt, and subject to satisfaction of the Conditions Precedent set by each TSO in part E.7 and under each TSO’s GTA (as applicable), commitments undertaken during the first Binding Bidding Phase shall not be affected by this second Binding Phase. D.1.1 Timeline of the Binding Phase

(2023)This second Binding Phase will commence with the publication of the Joint Notice on the websites of TAP, SRG and DESFA, envisaged to take place on 20th October 2023.31 A Binding Phase is made up of an Information Phase and a Binding Bidding Phase. During the Information Phase, the parties interested in participating in this Binding Bidding Phase will, subject and in accordance with TSO-specific requirements set out in Section E.1 below, be requested to register with the TSOs Concerned as an Applicant in order to participate in this Binding Bidding Phase. At the beginning of such Information Phase, together with the Joint Notice, on their websites, TAP, SRG and DESFA will make available a Binding Phase Notice and a list of the relevant documentation that needs to be submitted by the Applicants for their registration and the respective deadline for submission of such documentation. In a Bid Submission Window commencing in December 2023, the parties interested in participating in this Binding Bidding Phase will be required to submit Binding Bids by no later than the end of the Bid Submission Window. Please see Section E.2 which sets out the content of the Binding Bids. Following the end of the Bid Submission Window, TAP, SRG and DESFA will proceed with bid evaluation, Preliminary Capacity Allocation and the Economic Viability Test (EVT), entering into Gas Transportation Agreements with the successful Participants. This Binding Phase will end either in case no Offer Level passes the EVT or with GTAs, as applicable for each TSO, becoming fully effective (see Section E.7 concerning Conditions Precedent to the GTAs). Milestone Timeline (dates envisaged) Milestones A Information Phase Dates 20 October – 15 December 2023 Joint Notice: TAP/SRG/DESFA make available a list of documentation to be submitted to each TSO 20 October 2023 31 This timeline depends on the possibility that the Project Proposal is approved by the Italian, Greek and Albanian NRAs in line with the intended publication date. 18 Milestones B Dates Registration Period 20 October –1 December 2023 TAP/SRG/DESFA evaluate the applicants’ eligibility 2 December – 15 December 2023 Binding Bidding Phase 16 December 2023 – 31 January 2024 Bid Submission Window 16 December – 22 December 2023 Bid Evaluation Period 23 December 2023 – 12 January 2024 Preliminary Capacity Allocation32 13 January – 17 January 2024 Economic Viability Test Results published 18 January 2024 C Capacity Allocation 18 January 2024 D Execution of GTAs 31 January 2024 D.2 Duration of project realization The table below contains an indicative overview of the timing expected by the TSOs Concerned for the realization of the respective projects. TSO TAP SRG33 DESFA Level 1A Level 1B, Level 1 C, Level 2 and Level 3 44 months from Capacity Allocation 59 months from Capacity Allocation OL1A, OL1B, OL1C, OL2: Incremental capacity will be made available at no additional effort due to pre-investment – timing dependent on TAP. OL3: starting from end 2028 In direction from DESFA to TAP: Incremental capacity can be available after the completion of the relevant projects, already approved in DESFA’s TYNDP (estimated completion in Q4 2024) TAP Following receipt of Binding Bids and a positive EVT for one of the Expansion Projects for entry capacity, TAP will continue to develop and further specify the technical elements, schedule, and 32 If during the Preliminary Capacity Allocation TAP reaches a preliminary conclusion of a negative EVT result, TAP may enter into discussions with Participants for a revision of their Binding Bids, with the purpose of yielding a positive EVT, in accordance with Section 3.3.1(

1. d)TAP Tariff Code. TAP will also proceed to inform the Authorities of the negative EVT result. Depending on decisions of the Authorities, the preliminary capacity allocation period may (as an indicative, non-binding estimate) be extended by up to 4 months, as follows: according to Section 4.1.8 of the FJO, in case the EVT is negative, TAP is obliged to demonstrate this situation to the Authorities within one month following the closing date of the market test. If so, requested by the Authorities, TAP will provide an opinion by an independent third party. In case such an opinion is requested, the one-month timeline is extended by two months. The Authorities will then decide on the economic viability of the expansion within one month following receipt of TAP’s argumentation / from the receipt of the independent opinion. 33 The allocation of this capacity levels is subject to the application of the procedure described in Paragraph E.4 SRG Section “Competing Procedure in SRG’s system”. 19 costs of the chosen Expansion Project.34 In parallel to the development of the FEED, TAP will seek relevant key permits and third-party financing, if applicable. TAP and the Participants shall cooperate with one another in relation to any schedule updates and use reasonable endeavours to keep the other updated about developments, changes or delays which are likely to impact the timeline according to which the Expansion Project can be implemented (including, in relation to TAP, anticipated delays to the Start Date (as defined in Schedule 2 of the Transportation Confirmation) and in relation to each Participant, matters relating to upstream operations and the anticipated availability of gas to transport as part of the Expansion Project). SRG The capacity for Offer Level 1A, 1B, 1C and 2 is already available. The capacity for Offer Level 3 will be available starting from end 2028 with the realization of Matagiola-Massafra pipeline and the other related infrastructure, as described in the Chapter A.2 SRG section. Capacity offered at Melendugno IP will be in competition on the SRG side with the other IPs of Mazara and Gela, so the capacity allocation will be subject to the capacity constraints, reflecting the maximum simultaneous capacity transportable at the IPs. For a detailed description of the competing procedure applicable to Melendugno, Mazara and Gela IPs and maximum simultaneous capacities, please refer to the Paragraph E.4 SRG Section of this document (“Competing Procedure in the SRG’s system”). SRG may waive Condition(
2. s)Precedent under GTAs and proceed with project implementation (see Section E.7). DESFA Based on the preliminary technical studies, DESFA estimates that the necessary projects for the offer of the incremental capacity (the booster Compressor at Nea Mesimvria and the new CS at Ampelia) as described in part A.2.4 will be concluded by Q4 2024 so DESFA will be able to offer firm exit capacity at Nea Mesimvria exit point at Q4 2024. In any case, it must be noted that the above-mentioned timeframe, for the DESFA Offer Level will be further clarified during the technical studies phase. 34 At TAP option, a FEED may also be commenced prior to the EVT. 20 E. General rules and conditions for Binding Phase (Art. 27

(3)lit. e NC CAM) This chapter describes the general rules and conditions which the TSOs Concerned will apply in relation to the participation of interested parties in this Binding Phase. This Binding Phase will be open to all interested parties, including those that have not submitted a non-binding demand indication during the non-binding phase of the 2021 Market Test. Access to the transportation service provided by each TSO’s systems is permitted impartially and on an equal basis, to all interested parties that meet the requirements set out in this document. Incremental capacity will be offered as bundled products (where possible) to Participants for a minimum duration of 3 consecutive years, with the earliest possible start date being the planned E-COD and the latest possible end date for capacity in the TAP pipeline being the expiry of TAP’s exemption (14 November 2045). Demand requests of shorter duration will also be evaluated in the allocation process, subject to the restrictions described below.35 TAP Capacity booked in the TAP pipeline must have an initial end date that is the same as the end date of the corresponding booking in the relevant adjacent TSO’s system, and such firm capacity booked in the TAP pipeline shall be bundled with capacity in the relevant adjacent TSO’s system. However, please note in relation to capacity allocated in the TAP pipeline only that each Participant shall have the right, in accordance with the TAP GTA, to notify an extended end date for its capacity booking. This extended end date must be nominated by no later than one month before the latest of the finally determined Start Dates (as determined in accordance with the GTA) and initially allows an extension to a date up until 14 November 2045. If a Participant exercises such right in relation to capacity booked in the TAP Pipeline, it will be the responsibility of the Participant to purchase matching capacity in the adjacent TSO’s system. For IPs where capacity is made available as bundled capacity, the Participant must confirm to TAP no later than one month after making any such nomination whether, and to what extent, it has purchased matching capacity in the adjacent TSO’s system:36 • any such capacity in TAP up to the extended end date for which the Participant has purchased matching capacity with the adjacent TSO will be bundled with that capacity in the adjacent TSO; and • any such capacity in TAP up to the extended end date for which the Participant has not purchased matching capacity within the one-month period specified above will not be retained by the Participant in order to avoid residual unbundled capacity bookings in TAP, as detailed further in the TAP GTA. Notwithstanding the option to notify an extended end date for capacity booked in the TAP pipeline, TAP will use only firm and bundled capacity bookings for the purpose of calculating and passing the EVT for any applicable Expansion Project. However, there may be circumstances where this option to notify an extended end date of bookings in the TAP pipeline will prevent TAP from allocating capacity (either in this Expansion Project or in a future Binding Phase) that, if it was allocated, would result in a positive Economic Viability Test and trigger a further expansion. This may 35 The three-year minimum duration for bids contributing to determine the extent of an expansion is set to avoid a short peak in demand leading to suboptimal investment requirements and value chain economics. Note that shorter requests may be included in an EVT if required for this to be passed (see E.6) 36 Please note that this provision does not give Participants any priority right in purchasing the corresponding capacity on the adjacent TSO system. 21 occur if a participant requests capacity that is currently reserved under the extension option held by another Participant. If this happens, in order to prioritise further expansions, TAP can notify the relevant Participant that the latest end date for the extension is curtailed to an earlier date that allows TAP to allocate the requested capacity to the other participant. Note also that in relation to the allocation of bundled capacity, in the event of a delay or misalignment in the start date of capacity for an adjacent TSO, TAP has the right (but not obligation) to agree and implement ways of mitigating the consequences of such delay or misalignment, including by making adjustments to any bundled capacity allocation or, in relation to Linked Bids, to capacity allocated at both exit and entry points as may be agreed with the relevant Participant. Any such mitigation is expected to be neutral to TAP. SRG For the avoidance of doubt, the abovementioned right granted by TAP to the Participants to notify an updated end date for its capacity booking in the TAP pipeline, does not provide any right in relation to the bid on the SRG side. In relation to the allocation of bundled capacity, in the event of a delay or misalignment in the start date of capacity for an adjacent TSO, SRG has the right (but not obligation) to agree and implement ways of mitigating the consequences of such delay or misalignment, including by making adjustments to any bundled capacity allocation as may be agreed with the relevant Participant. Any such mitigation is expected to be neutral to SRG. DESFA For the avoidance of doubt, the abovementioned right granted by TAP to the Participants to notify an updated end date for its capacity booking, does not provide any right in relation to the bid on the DESFA side. In relation to the allocation of bundled capacity, in the event of a delay or misalignment in the start date of capacity for an adjacent TSO, DESFA has the right (but not obligation) to agree and implement ways of mitigating the consequences of such delay or misalignment, including by making adjustments to any bundled capacity allocation as may be agreed with the relevant Participant. Any such mitigation is expected to be finally neutral to DESFA. E.1 Participation criteria and Registration The requirements referred to in this Section E.1 will apply to this Binding Phase carried out by the TSOs. Applicants will have to submit filled-in Binding Phase Registration Forms to TAP, SRG and DESFA, which will be provided together with the Joint Notice and each TSO’s own Binding Phase Notice. The information to be submitted by Applicants shall include (but not be limited

1. to)the following information: A. Company Name and Address. B. Name and contact details of Company Representative. C. A list of the IPs/entry-exit point(
2. s)where the Applicant intends to submit a binding commitment. The above registration requirements apply in addition and subject to each TSO’s further requirements in relation to registration and their applicable regulatory framework, in each case as 22 indicated below. Applicants must submit (within the required deadlines) all the documents needed, as described in this Section E.1, each TSO’s own Binding Phase Notice and the Joint Notice, and also potentially be enabled to operate on a jointly identified capacity platform if so decided by the TSOs Concerned, as indicated in the Joint Notice. At the end of the Registration Period, TAP, SRG and DESFA will communicate to Applicants their eligibility to participate in the Binding Bidding Phase. By participating in a Binding Bidding Phase, each Participant will be required to accept that: ▪ the Capacity Allocation referred to in the Incremental Capacity Process is subject to the positive outcome of the EVT of the TSOs Concerned; ▪ in case of a negative outcome of the initial EVT carried out prior to Capacity Allocation, the TSOs Concerned shall, if applicable, return any Bank Guarantees submitted as part of the registration or with the Binding Bid and no transport capacity will be contractually allocated; ▪ in case of a positive outcome of the initial EVT carried out prior to Capacity Allocation, the successful Participant shall enter into a GTA and, if applicable, transmit to the TSOs respective Bank Guarantees as described below in Section E.7; ▪ in case a Participant is not allocated incremental capacity after a positive EVT, the Bank Guarantees shall be returned; and ▪ if the Participant is allocated capacity but the GTA between the TSO and the Participant is not executed between the relevant Parties or does not, for any reason, become fully effective, the Participant will be subject to TSO-specific rules as set out below. TAP TAP accepts as Participants in the Binding Phase either (
3. i)parties who are already registered with TAP under TAP’s Network Code rules (Registered Party/-ies)37, or (
4. ii)parties that have duly commenced such registration process (by following the steps indicated on TAP’s webpage “How to become a Registered Party” and having correctly completed and submitted an Initial Onboarding Form).38 By the end of the Registration Period as indicated above at Section D: - Applicants must have submitted a duly signed Binding Phase Registration Form for this second Binding Phase of the 2021 Market Test. Please note that along with the Binding Phase Registration Form all parties must submit a Confidentiality Agreement (as required under the Binding Phase Registration Form); and - any Applicants who are not yet Registered Parties with TAP must also have commenced the process to become a Registered Party under TAP Network Code rules by having correctly completed and submitted the Initial Onboarding Form. For the sake of clarity, these Applicants are also required to submit a Binding Phase Registration Form and Confidentiality Agreement, as mentioned above. In the Binding Phase Registration Form, amongst others matters, each Applicant must acknowledge: “Registered Party” means any Person that has satisfied the conditions to becoming a Registered Party specified in Section 3.1 of TAP Network Code and has received confirmation from the Transporter of its status as a Registered Party, in accordance with TAP Network Code. 38 https://www.tap-ag.com/shippers/applying-to-become-a-registered-party 37 23 o that no sanctioned gas will be transported through the TAP pipeline. o their obligation to engage in the Capacity Caps assessment with the Authorities and submit any information required to perform such an assessment to the relevant Authorities (ARERA in Italy, RAE in Greece and ERE in Albania). Once the assessment has been done, the Applicant is required to inform TAP of any capacity caps that may be imposed following the dominance assessment. Upon confirmation by TAP that an Applicant is eligible to participate in the Binding Bidding Phase, such Applicant becomes a Participant. A Participant may submit a Binding Bid Form in accordance with the requirements of this Project Proposal, the Joint Notice, the Binding Phase Notice and the Binding Bid Form. When a Participant submits a Binding Bid Form to TAP, the Participant will be required at the same time to deliver to TAP an on-demand Bank Guarantee (the Bid Guarantee) with an expiry date no earlier than 31 May 2024 from an internationally reputable bank with a minimum credit rating of BBB - at Standard and Poor’s or Baa3 at Moody's, or alternatively issued by any Greek financial institute supervised by the ECB (systemic banks, namely any of Alpha Bank, Eurobank, National Bank of Greece and Piraeus Bank), which has been approved in advance by TAP in its absolute discretion, cashable at first request of TAP and equal in value to the lower of: I. 15 % of the maximum annual capacity requested by the Participant at all IPs multiplied by the TAP tariff for Forward Firm Long-Term Capacity published for calendar year 2023; and II. 15 MEUR. The Bid Guarantee is provided as security in respect of the Participant’s obligations and liabilities under and in connection with this Project Proposal. TAP shall be entitled to make a demand under the Bid Guarantee at any time up to the total aggregate amount available for demand under the Bid Guarantee if: (
5. i)at any time, the credit rating of the bank providing the Bid Guarantee no longer satisfies the requirements set out above (including in respect of minimum credit rating) or if the Bid Guarantee has an expiry date prior to 31 May 2024 and no renewed Bid Guarantee (substantially in the same form as the Bid Guarantee it is replacing and meeting the requirements set out above in relation to the provider) has been provided no less than fifteen

(15)days prior to expiry of the original Bid Guarantee; (

1. ii)the Participant fails to satisfy its obligations and liabilities arising as a result of and in connection with a withdrawal of its Bid or termination of a TAP GTA (see Section E.7 below); or (iii) the Participant does not provide the Post-Bid Guarantee in accordance with section E.7 below. If the Bid Guarantee is called solely in connection with the circumstances set out in limbs (
2. i)or (iii) above and if, in TAP’s sole discretion, such circumstances have been adequately remedied by the issue of a renewed or new Bid Guarantee or provision of the Post-Bid Guarantee in accordance with Section E.7 (as applicable) or by the implementation of other arrangements satisfactory to TAP, TAP will repay to the Participant those amounts, if any, received by TAP on the calling of the Bid Guarantee on account of the circumstances set out in limbs (
3. i)or (iii) to the extent such sums have not been utilised by TAP in accordance with this Project Proposal. The Bid Guarantee provided to TAP by each Participant will be returned by TAP to such Participant once: o TAP confirms that the Participant will not be allocated capacity in the Expansion 24 Project; o The EVT is finally determined to be negative (in accordance with the provisions of Section E6 of this Project Proposal); or o If the Participant is allocated incremental capacity as part of the Expansion Project, upon provision to TAP of a Post-Bid Guarantee in accordance with Section E.7 below. By submitting a Binding Bid Form to TAP, the Participant accepts: o that submission of a Binding Bid will constitute an irrevocable commitment to enter in a GTA with TAP, subject only to the successful outcome of the EVT; and o the consequences of the TAP GTA being terminated, as set out in Section E.7 below. Notwithstanding the above, TAP may at its sole discretion (and to the extent agreed in advance with TAP) accept an alternative form of credit support acceptable to it in place of a Bank Guarantee. If such alternative credit support is provided, it must be provided such that it can be called on by TAP in the circumstance in which TAP would be permitted to call on the Bank Guarantee. All of TAP’s rights, remedies and entitlements in connection with the Bank Guarantees (as set out this Project Proposal) shall apply equally to such alternative form of credit support. SRG Applicants will be required to state the possession of relevant requirements defined in paragraph 1.1 – Chapter 5 and comply with the conditions referred to in paragraphs 1.4 and 9.1 of Chapter 5 of Snam Rete Gas Network Code. Any statement of possession of requirements (requests, commitments, declarations or acceptances), as well as any request/communication or expression of will, made by the Applicant, including via the relevant functionality of SRG’s website or a potentially jointly identified capacity booking platform, constitutes a formal obligation and commitment on the part of the Participant, which accepts – even in respect of third parties – any and all liability arising from any breaches/errors or omissions. Participants shall be required to present to SRG within the end of the Information Phase: - The Transportation Contract (“GTA”) signed by a person in possession of power of attorney. - The “First Guarantee” : a Bank Guarantee , cashable at first request, issued by an Italian financial institute or Italian insurance company or Italian branch of a foreign bank or foreign insurance company with a minimum credit rating of BBB- at Standard and Poor’s or Fitch Ratings, Baa3 at Moody's or BBB low at DBRS or a non-interest-bearing security deposit, respectively equal in value to 20% of the maximum annual capacity charge (based on the indicative tariff made available by SRG) of the incremental capacity they intend to request and with an expiry date no earlier than 01/08/2024. SRG will publish on its own web site the estimated value of the annual capacity charge referred to in the Incremental Capacity Project. Binding Bids by Participants will be accepted only within the limits of the First Guarantees which will have been presented to SRG according to the provisions above. The First Guarantee provided to SRG by each Participant will be returned by SRG to such Participant once: 25 o SRG confirms that the Participant will not be allocated capacity in the Expansion Project; o The EVT is finally determined to be negative (in accordance with the provisions of section E6 of this Project Proposal); or o If the Participant is allocated incremental capacity as part of the Expansion Project, upon provision to SRG of the Contracts Guarantees in accordance with section E.7 below. By submitting a Binding Bid Form to SRG, the Participant accepts: ▪ that submission of a Binding Bid will constitute an irrevocable commitment to enter in a GTA with SRG, subject only to the successful outcome of the EVT; and the consequences of the GTA being terminated, as set out in section E.7 below. DESFA Applicants will be required to state the possession of relevant requirements defined in DESFA Network Code, Annex I of the NNGS Standard Transmission Agreement and the relevant Application. Only Transmission Users, as defined in DESFA’s Network Code, can submit binding bids for entry/exit capacity to/from the DESFA system, in the Binding bidding phase. The specific requirements that must be fulfilled by the interested parties will be defined in detail in DESFA’s section of the Joint Notice (DESFA’s Binding Phase Notice). DESFA shall not allow any interested party to submit Binding Bids if these requirements are not met and even if submitted shall be rejected for this reason. Any statement of possession of requirements (requests, commitments, declarations or acceptances), as well as any request/communication or expression of will, made by the Applicant, including via the relevant functionality of DESFA’s website or a potentially jointly identified capacity booking platform, constitutes a formal obligation and commitment on the part of the Participant, which accepts – even in respect of third parties – any and all liability arising from any breaches/errors or omissions. Participants shall be required to provide to DESFA within the required deadlines a Bank Guarantee (Binding Bid Guarantee), cashable at first request of DESFA, issued by any Greek financial institute supervised by the ECB (systemic Banks, namely any of Alpha Bank, Eurobank, National Bank of Greece and Piraeus Bank) including their subsidiaries or any Greek branch of an internationally reputable bank with a minimum investment grade credit rating from the following Agencies: BBB at Standard and Poor’s, BBB at Fitch or Baa3 at Moody’s, or any internationally reputable bank with a minimum investment grade credit rating (as described above), or any subsidiary of an internationally reputable bank with a minimum investment grade credit rating (as described above), or any subsidiary of an internationally reputable bank without a minimum investment grade credit rating (or without any rating at all), provided that the Bank Guarantee is counter-guaranteed by any internationally reputable bank with a minimum investment grade credit rating (as described above); which has been approved in advance by DESFA, at its sole discretion, equal in value to 20% of the maximum annual capacity charge (based on the indicative tariff made available by DESFA, including any mandatory minimum premium) of the incremental capacity they intend to request, valid until two

(2)months from the execution of the GTAs according to D.1.

1. DESFA will publish on its own website the estimated value of the annual capacity charge referred to the Incremental Capacity Project. 26 Binding Bids by Participants will be accepted only within the limits of the guarantees which will have been presented to DESFA according to the provisions above. By submitting a binding request to DESFA, the Participant accepts that said request will constitute an irrevocable commitment to enter a GTA with DESFA, subject to the successful outcome of the EVT. The Binding Bid Guarantee provided to DESFA by each Participant will be returned to such Participant once: o DESFA confirms that the Participant will not be allocated incremental capacity; o The EVT is finally determined to be negative (in accordance with the provisions of section E6 of this Project Proposal); or o If the Participant is allocated incremental capacity, upon the provision to DESFA of the GTA Bank Guarantee described in section E.
2. E.2 Binding Bid content During the Binding Bidding Phase, Participants will have to submit their Binding Bids for incremental capacity products to each TSO. Participants shall specify in each Binding Bid: • Ιf a Binding Bid is a Linked Bid as per the indications from the Binding Bid Form. In a Linked Bid the capacity requested at a TAP entry point must equal the exit capacity requested at one other IP/exit point. Legal entities belonging to the same group of companies and therefore being able to be considered as part of the same business undertaking for the purpose of the Project Proposal (as confirmed to TAP by those entities), may be considered as the same Participant for the purpose of submitting Linked Bids as provided in the Project Proposal, provided that both such entities indicate in their Binding Bid Forms that they wish their bids to be Linked Bids with the bid of the other entity. • The capacity requested (in kWh/day) per entry and exit point. Capacity requested cannot exceed the maximum incremental capacity on offer at a particular IP, as defined in the relevant table of Section B. • The requested start date. • End date of the bid. Except for Annual Requests (with restrictions as noted below, and described in Section E.6), the duration cannot be less than 3 consecutive years, with the latest possible end date for capacity booking in the TAP pipeline being 14 November
3. For the avoidance of doubt, each Binding Bid must relate to consecutive years. • Indication whether capacity reduction is acceptable or not. Participant must also indicate whether they will accept a reduction in their Capacity Allocation (and up to which amount) in the event of congestion and their bid happens to be marginal. For Linked Bids, any reduction in capacity at the IP where the Linked Bid is assessed as being marginal will result in an equal reduction in incremental capacity at the linked IP/exit point (it should be noted that bundled capacity is reduced by the same amount at both sides of the IP). Participants may submit more than one Binding Bid. Binding Bids submitted by the same Participant may vary by IP, duration of capacity requested and capacity amount. As a basic rule, in a single Binding Bid, Participants may specify only one value of incremental capacity for all gas years requested. A Binding Bid may however indicate a ramp-up over the first two years of the period to which the Binding Bid relates, with a minimum value for the first year of 40% of capacity 27 and 70% for the second year. Should Participants wish to profile their capacity request further, then they should submit separate Binding Bids. A Binding Bid does not have to specify a bid price, as the price applicable to the incremental capacity for the purposes of the evaluation process shall be equal to the Reserve Price plus any mandatory minimum premium(s) where applicable. The TAP Tariff is specified according to the TAP Tariff Code. The respective annual capacity charge by SRG and DESFA, according to the provisions of the relevant tariff regulations, as approved by the respective Authorities (to be used as estimated reference price for the duration of the initial incremental capacity requests), will be published on their own websites during the Information Phase. There will be no additional auction premia charged on top of the Reference Prices (other than in relation to the Equal Marginal Bid process set out under Section E.5 below) except for Melendugno IP, where Participants, taking into account the competing constraint, will submit also an indication of the auction premia that are willing to pay and that will be considered for the ranking of their bids as described in the Paragraph E.4 SRG Section. Bids will have to be submitted inside the Bid Submission Window in accordance with the instructions that will be provided in the Joint Notice published by the TSOs. By submitting a Binding Bid Form, a Participant will be deemed to have agreed to the terms and process set out in this Project Proposal and the Joint Notice published by the TSOs, as well as with the Binding Phase Notice of each relevant TSO, including the process regarding the overall Project Proposal and the potential liability of the Participant for Termination Costs in connection with a GTA not being executed between the relevant parties or not becoming fully effective in accordance with its terms and/or the termination or modification of the Incremental Capacity Process (see further detail in Sections E.1 and E.7). E.3 Bid Evaluation At the end of the Bid Submission Window, each TSO will assess the respective received Binding Bids for completeness and compliance with the relevant requirements set out under this Project Proposal, the Joint Notice and the Binding Phase Notice issued by each TSO (including, where capacity is being made available as bundled capacity, that equal Binding Bids have been made to each of the TSOs Concerned). Those Binding Bids that are accepted at this stage will be considered as part of the preliminary Capacity Allocation procedure of Section E.4 below. In case of rejection of a Binding Bid, the relevant TSO shall (without prejudice to the procedure applicable to Equal Marginal Bids) notify the relevant Participant of such rejection and the other TSOs Concerned within 5 business days from the end of the Bid Submission Window. For the avoidance of doubt, the rejecting TSO shall have no liability whatsoever to the other TSOs Concerned or any other party in connection with such rejection. E.4 Preliminary Capacity Allocation Procedure (Bid Ranking) The rules for preliminary Capacity Allocation of incremental capacity at all IPs are described below. If a TSO curtails or rejects any Binding Bid at an IP where capacity is made available as bundled capacity, the bundled Binding Bid made with the other TSO Concerned will also be curtailed or rejected to the same extent. The TSOs will undertake the actions listed below. • For each year, the sum of Binding Bid capacity requests is computed at each IP. • If there is no congestion at any IP, the TSOs Concerned shall undertake a preliminary Capacity Allocation and proceed with the EVT process set out in Section E.
4. • If, there is congestion at an IP and in consideration of the specific regulatory framework defined for TAP by the Authorities, Binding Bids received in relation to that IP are ranked 28 according to the ratio of the NPV of the hypothetical revenues on the TAP system from the bid divided by the maximum annual capacity of the bid. In case of Linked Bids, the hypothetical revenues include revenues from both the TAP entry point and the other TAP exit point component of the bid. A Marginal Bid at a congested IP is allocated the remaining incremental capacity unless the Participant has explicitly declared, in its Binding Bid, nonacceptance of a capacity reduction. If the Participant of such Marginal Bid has declared non-acceptance of capacity reduction, the remaining capacity is allocated to the next Participant with a lower NPV/capacity ratio. If there is no other Participant with a lower NPV/capacity ratio, only the allocated capacity (without such Participant) will be considered in the EVT. • In the case of two or more Equal Marginal Bids, an auction may be initiated according to Section E.
5. • If a Linked Bid happens to be a Marginal Bid or one of Equal Marginal Bids, an equal capacity reduction shall be made by the TSOs Concerned at the linked IPs/exit points. • The outcome of the preliminary allocation process shall comprise of a table showing each Offer Level and IP showing all Binding Bids. The timescales and the administrative details related to the bid submission process will be specified in the Joint Notice published by the TSOs. Competing Procedure in SRG’s system The incremental Capacity process related to the TAP Expansion foresees the application of an alternative allocation mechanism in substitution of the regular auctions foreseen by CAM NC at art.
6. Considering that the Interconnection Point (IP) of Melendugno, subject to the expansion process, is in competition with the IPs of Mazara and Gela, it is necessary to manage the multi-yearly capacity bids starting from Q4 2027 for offer level 1a and end of 2028 for offer levels 1b, 1c, 2 and Offer level 3 outside the regular auction procedure foreseen in par. 3.2.3 of Chapter 5 of the SRG Network Code, as hereunder described. Participation requirements – Melendugno IP The Participants interested in buying multi-yearly capacity on Melendugno IP will need to satisfy the requirements indicated to the SRG section of the above paragraphs E.1 and E.
7. Participation requirements – Mazara and Gela IPs The Participants interested in buying multi-yearly capacity on Gela and Mazara IPs will need to satisfy the following requirements: - possess a signed Transportation Contract with SRG - have submitted the appropriate “First Guarantee”: a guarantee cashable at first request, issued by an Italian financial institute or Italian insurance company or Italian branch of a foreign bank or foreign insurance company with a minimum credit rating of BBB- at Standard and Poor’s or Fitch Ratings, Baa3 at Moody's or BBB low at DBRS or a non-interestbearing security deposit, respectively equal in value to 20% of the maximum annual capacity charge (including a potential auction premium as described below) of the capacity 29 - they intend to request and with an expiry date no earlier than 01/08/2024 within the 15 th December
8. possess the requirements referred to in ARERA Resolution no. 137/02 and its subsequent modifications as indicated in Chapter 5 of the SRG Network Code. comply with the conditions referred to in paragraphs 1.4 and 9.1 of Chapter 5 of the SRG Network Code. In the event of successful allocation of capacity, as a requirement under the relevant GTA, the Participant shall present to SRG, by 31th January 2024, the “Contract Guarantees”: two Bank Guarantees), cashable at first request, issued by an Italian financial institute or Italian insurance company or Italian branch of a foreign bank or foreign insurance company with a minimum credit rating of BBB- at Standard and Poor’s or Fitch Ratings, Baa3 at Moody's or BBB low at DBRS or a non-interest-bearing security deposit, respectively equal in value to the amount required in SRG Network Code (Chapter 5 Paragraph 1.3.4 and 1.3.5). The Contract Guarantees shall remain valid for the entire duration of the relevant GTA, with an expiry date at the end of the sixth month following the end of the relevant GTA. Once the Contract Guarantees described here above will be presented to SRG, the First Guarantee will be returned. If the Participant does not issue the Contract Guarantees above described (SRG Network Code Chapter 5 Paragraph 1.3.4 and 1.3.5) within the 31th January 2024, it shall pay a fee to SRG equal to the value of the First Guarantee and the contract will be void. Competing mechanism The bids need to be submitted during the bid submission window (16th December-22th December 2023) through the templates published on SRG website
9. As a basic rule, in a single bid, Participants must specify the same value of capacity for all the gas years requested. A bid may however indicate a ramp-up over the first two years of the period to which the bid relates, with a minimum value of capacity of 40% for the first gas year and 70% for the second gas year. Should Participants wish to profile their capacity request further, then they should submit separate bids. Consistently with the current tariff regulatory framework, SRG considers applying a floating reference price. For the purpose of the economic test and the presentation of the Bank Guarantees, this has been estimated equal to: - Mazara 3.296498 €/year/Smc/day equivalent to 0.296106 €/year/kWh/day - Gela 3.022228 €/year/Smc/day equivalent to 0.275448 €/year/kWh/day - Melendugno