transmission networks on the implementation of …€¦ · border commercial capacities (i.e. ntc)....

ACERAgncy for tht’ Cooperationc)1 tnergv Regulators

OPINION OF THE AGENCY FOR THE COOPERATION OF ENERGYREGULATORS No 08/2016

of 27 July 2016

ON THE IMPLEMENTATION OF INVESTMENTS IN ELECTRICITYTRANSMISSION NETWORKS

THE AGENCY FOR THE COOPERATION OF ENERGY REGULATORS,

HAVING REGARD to Regulation (EC) No 713/2009 ofthe European Parliament and ofthe Councilof 13 July 2009 establishing an Agency for the Cooperation of Energy Regulators1 (hereinafterreferred to as “the Agency”), and, in particular, Articles 6(7) and 6(8) thereof,

HAVING REGARD to the favourable opinion of the Board of Regulators of 1 3 July 201 6, issuedpursuant to Article 1 5(1) of Regulation (EC) No 713/2009,

WHEREAS:

(1) Articles 6(7) and 6(8) of Regulation (EC) No 713/2009 task the Agency for the Cooperation ofEnergy Regulators (“the Agency”) with monitoring the progress as regards the implementationof investments to create new interconnector capacity and the implementation of the electricityUnion-wide ten-year network development plan (“EU-TYNDP”).

(2) National regulatory authorities (“NRAs”) have provided essential input for this Opinion, bysubmitting information on components of transmission investments2 via an online data collectionprocess (completed on 6 June 2016) and additional updates provided until 30 June 2016. Thisinformation is analysed and summarised in the Annexes to this Opinion. The results from theAgency’s monitoring3’4 were taken into account as well.

1 OJL211, l4.$.2009,p.l2 j this Opinion, “component” (or investment component) means the national part of a transmission investment item.3 Opinion ofthe Agency for the Cooperation of Energy Regulators No 16/2014 on the implementation of investments inelectricity transmission networks, available at:http://www.acer.europa.eu/official documents/acts oLthe agency/opinions/opmions/acer%2Oopinion%2016-2014.pdf4 Opinion ofthe Agency for the Cooperation of Energy Regulators No 04/2016 on National Ten-Year ElectricityNetwork Development Plans, available at:http://www.acer.europa.eu/Offlcial documents/Acts ofZthe Agency/Opinions/Opinions/ACER%200pinion%2004-2016.pdf

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HAS ADOPTED THIS OPINION:

The aim and scope of this Opinion is to analyse the progress in the development of the investmentsofpan-European5 and regional significance6 and ofother investments ofcross-border relevance7. Theprogress in the development ofinvestments for Projects ofCommon Interest (PCIs) under Regulation(EU) No 347/2013 of the European Parliament and of the Council of 17 April 2013 on guidelines fortrans-European energy infrastructure has been separately evaluated and therefore the results of suchan evaluation are not presented in this Opinion, but are available in the Agency’s consolidated reporton the progress of electricity and gas projects of common interest of 30 June 20168.

This review focuses on the status and the timing of development of each investment, as well as onthe increase of Cross-Border Grid Transfer Capability (XB GTC) that the implementation of eachinvestment is supposed to bring. As the monetised information related to the costs and benefits ismissing in most of the National Network Development Plans (NDPs)9, costs and benefits are notdiscussed in this Opinion. Moreover, given the overall lack of maturity of the 2014 EU-TYNDPinvestments in the “under consideration” status (5 1 % of the investment components with this statushave been cancelled), this category of investments has been considered only for part of the analysis.

Based on the data provided by the NRAs, the following major findings were identified:

. An important decrease in the number of investments in the 20 14 EU-TYNDP compared to the2012 EU-TYNDP was observed, mostly as a result ofthe application ofthe new Cost-BenefitAnalysis (CBA) methodology and, in particular, of the new clustering rules.

. Less than half (i.e. 43%) of the investment components are “on time” or ahead of schedule,while 35% encountered delays and 22% have been rescheduled.

. The number of cancelled investment components significantly increased (+60%) compared tothe number reported by NRAs for the previous Opinion. The main reason reported forcancellation was related to changes on the generation side (56 %)b0.

. 66 components have been commissioned since the last monitoring exercise (Agency’sOpinion No. 16/2014). The actual commissioning rate, based on the data reported by NRAs,is similar to the one reported in the previous exercise, i.e. 12%.

. Most of the “new” investments included in the 2014 EU-TYNDP (i.e. those not alreadyincluded in the 2012 EU-TYNDP) have the “under consideration” status. This fact could be

5 The list of investments with pan-European significance is displayed in Appendix 1 of the EU-TYNDP released by theEuropean Network of Transmission System Operators for Electricity (ENTSO-E) on 30 October 2014 (“TYNDP”investments). The monitoring has been performed with reference to the investment items.6 this Opinion, the Agency also reports on the monitoring of investments included in the Regional Investment Plans,published in October 2014, which are not included in the 2014 EU-TYNDP.7 i.e. the investments which are not included in the 2014 EU-TYNDP or in the Regional Investment Plans 2014, but appeareither in the national investment plans (“OTHER” investments) or are developed by Third-Party Promoters (“TPP”investments).8 http://www.acer.europa.eu/Official_docurnents/Puhlications/Pages/Puhlication.aspx9 Opinion ofthe Agency for the Cooperation of Energy Regulators No 04/2016 on National Ten-Year ElectricityNetwork Development Plans, available at:

2016.pdf10 Based on the data provided by Bulgaria, Great Britain, Latvia and Sweden.

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considered to some extent as a normal feature for a plan, but it also emphasises the exploratoryrole ofthe 2014 EU-TYNDP.

. Since 2014, four interconnectors were commissioned, which contributed to an increase ofNetTransfer Capacity (NTC) of up to 2000 MW1 , while the expected XB GTC12 increase was2800 MW (see Annex I, Table 3).

. The majority of reported delays concerns investments which are in the permitting status’3.

. Most of the rescheduled investments are located in Portugal, Spain, Great Britain andHungary. In the case ofPortugal and Great Britain, the main reason for rescheduling is relatedto the uncertainties regarding the pace of deployment of Renewable Energy Sources (RES).

A more detailed analysis of the evolution of investments is provided in Annex I. Tables displayingthe list of cancelled, commissioned, delayed and rescheduled investment components are presentedin Annex II.

The following recommendations can be made taking into account the results of the monitoringexercise:

. To facilitate transparency and the tracking of progress over time, the mapping of cross-references between investment codes in different plans should be ensured, as already proposedby the Agency in the previous Opinion on the draft 2014 EU-TYNDP’4. Further, the EUTYNDPs should maintain (or keep track of) the investment codes in previous TYNUPreleases. ENTSO-E should ensure consistency with the national NDPs already in the first stepsof the preparation of future EU-TYNDPs.

. Information about the XB GTC and costs (especially for the interconnectors) should beincluded in the Regional Investment Plans. When applicable, the uncertainty of the XB GTCforecasts should be explained in the EU-TYNDPs and in the Regional Investment Plans.

. Future EU-TYNDPs should adopt a clear definition of investment items (e.g. a transmissionline, a high voltage direct current link, a substation, a phase shifting transformer).

. Future EU-TYNDPs should adopt the following statuses’5, for consistency with the Agency’smonitoring activities: under consideration; planned, but not yet in permitting; permitting;under construction; commissioned; and cancelled.

11 The value depends on the direction ofthe commercial flows. In addition, one interconnector between LT and SE is stillin testing mode and its contribution is thus not accounted for.12 The TYNDP CBA Socio-Econornic Welfare (SEW) indicator utilises XB GTC as a forecast of the increase in cross-border commercial capacities (i.e. NTC). Over-estimation ofXB GTC leads to over-estimated SEW benefits, which mightlead to questionable CBA results.13 Even though this may indicate that the permitting process is the main reason for these delays, based on the informationreceived, the Agency cannot substantiate such a conclusion.14 Opinion ofthe Agency forthe Cooperation ofEnergy Regulators No 01/2015 on National Ten-Year Electricity NetworkDevelopment Plans, available at: http://www.acer.europa.eu/Media/News/Pages/ACER-published-an-Opinion-onENTSO-E-draft-ten-year-network-developrnent-plan-2014.aspx15 The above classification ensures a clear distinction between investments which already reached the permitting phaseand investments which have not entered the permitting phase yet. This distinction is essential to draw the right conclusionsregarding the progress ofthe investments. In order to make the status phases comparable, the Agency considers the 2014EU-TYNDP status “under design & permitting” as “permitting” and “planned” status as “planned but not yet inpermitting”.

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. Future EU-TYNDPs and the related ENT$O-E monitoring activities should clearly define anddifferentiate between “rescheduled” and “delayed” investments16.

. Future EU-TYNDPs should include the indications of the costs per investment item.

. Future EU-TYNDPs should include the list of commissioned investment items (in the firstEU-TYNDP after commissioning), display the actual increase in XB GTC and provideexplanations in case it differs from the expected increase.

Done at Ljubljana on 27 July 2016.

For the Agency:

I’APototschnigDirector

16 For the purpose of this Opinion, the Agency considers an investment “rescheduled” if the investment is voluntarilypostponed by a promoter due to changes ofexternal circumstances (e.g. lower demand, less urgent need for an investmentdue to updated planning data or priority to other transmission solutions). The term “delayed” investment correspondsinstead to an investment component which is still needed at the expected date, but cannot be delivered on time due tovarious external factors like permitting, environmental, legislative reasons, etc.

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Annex I — Analyses of the evolution of investments

1. Overview on the monitoring process and investments

The monitoring activity is performed at a disaggregated level, i.e. at transmission investmentcomponent level, even in the case of clusters. As some components of interconnection investmentsare located in countries outside the scope of this Opinion (which covers EU Member States andNorway only17), this Opinion covers 662 components corresponding to 615 investments. The totalnumber ofinvestments, including PCIs which are not discussed in this Opinion, is presented in Table1.

National Regulatory Authorities from 30 jurisdictions (AT, BE, BG, CY, CZ, DE, DK, EE, EL, ES,Fl, FR, GB, HR, HU, IE, IT, LT, LV, LU, MT, NI, NL, NO, PL, PT, RO, SE, SI, 5K) participated inthe process, providing their input on components oftransmission investments by 30 June 2016.

REG 104 375 109 388OTHER 13 1 18 2

TPP 33 20 55 28Total 757 746 838 832

- of which, interconnections 99 1 03 1 80 189- ofwhich, internal 658 643 658 643

Assessments are based on the available data supplied by NRAs. In particular:

. the information regarding the status of investment components is available for approximately80% of them;

. the information regarding the progress of investment components is available forapproximately 47% ofthem 20;

. the information regarding the commissioning date of investment components is available forapproximately 5 1% of them2’.

17 Thanks to the voluntary participation ofthe Norwegian NRA.18 For the sake of comparison, in this table, the amount of the 2014 investments also includes the transmission PCIs (inthis Opinion, they colTespond to 1 32 investment components).19 “TYNDP” means investments which are included in the 2014 EU-TYNDP; “REG” means investments which areincluded in the 2014 Regional Investment Plans; “OTHER” means investments which are included in national investmentplans; TPP means investments which are developed by Third-Party Promoters.20 Cancelled investment components and investment components “under consideration” are excluded from the sample.21 Cancelled investment components are excluded from the sample.

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1.1 Category of investments

Alternate-current (AC) transmission lines represent half of the investment components. Thebreakdown of investments listed in the 2014 EU-TYNDP and in 2014 Regional Investment Plans(REG) is further illustrated in

Figure 1 : Breakdown of investment components by investment categories

Transformer IReactive compensation device

Phase shifting transformer IOnshore substation 1L

Onshore DC transmission cable

Offshore substation

Offshore DC transmission cable I ‘ TYNDP

Offshore DC line • REGOffshore AC transmission cable

DC transmission line

Combined investments

Back to back substation

AC transmission tine

0 50 100 150 200 250

2. Current status

2.1 Current status of the EU-TYNUP, REG and OTHER investments

The analysis regarding the status of the EU-TYNDP and REG investments, as well as of theinvestments which are included in national investment plans (OTHER) has been carried out for 529investment components, as no information was reported for the other 1 33 investment components.

The following statuses for the investments were taken into account for this analysis:

. under consideration;

. planned, but not yet in permitting;

. permitting;

. under construction;

. commissioned;

. cancelled.

An overview of the status of the 529 investment components is presented in

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Figure 2. Based on the information provided, the Agency has found that 21% of the investmentcomponents are currently “under consideration”, 19% are “planned, but not yet in permitting”, 27%are in “permitting”, 1 1 % are “under construction”, 12% have been commissioned and 1 0% have beencancelled. Compared to the last monitoring exercise, it can be observed that the percentage of theinvestment components in the permitting status has decreased, but the percentage of the cancelledinvestment components has increased.

Figure 2: Current status for all investment components

m Cancelled

;

__

S Under consideration

S Planned, but not yet inpermitting

S Permitting

. Under constructinn141

99

For the purpose of comparison with the 2014 EU—TYNDP data and a better understanding of theevolution of the investments, the analysis of the status has been carried out separately for EU-TYNDP, REG and OTHER investments with a breakdown for old and new investments22.

EU-TYNDP Investments

Old investments

Out of the total 1 5 1 old investment components for which information is available, the Agency hasfound that 21 % are currently “under consideration”, 15% are “planned, but not yet in permitting”,25% are in ‘permitting’, 12% are “under construction”, 16% have been commissioned and 1 1 % havebeen cancelled, as presented in figure 3. Compared to the status ofthe 2014 EU-TYNDP investmentssummarised in Figure 4, the Agency observes a significant reduction of the EU-TYNDP investmentcomponents in the “planned, but not yet in permitting” and “permitting” statuses and an importantincrease in cancelled and commissioned investments. The Agency notes that 41 % of the EU-TYNDPinvestment components, which were “under construction” in 20 1 4, have been commissioned.

22 In this Opinion, the term “old investment” denotes an investment which is included both in the 2012 EU-TYNDP andin the 2014 EU-TYNDP. The term “new investment” denotes an investment included only in the EU-TYNDP 2014.

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Figure 3: Current status of the old EU-TYNDPinvestment components

Figure 4: The investment status as in the 2014EU-TYNDP

S Cancelled

I Under consideration

Planned, but not yet inperridtting

Permitting

. Under construction

. Commissioned

S Cancelled

a tinder ronsicieratior

S Planned, but not ye’permitting

S Perriritting

New investments

Out of the total 34 new investment components for which information is available, the Agency hasfound that 62% are currently “under consideration”, 20% are “planned, but not yet in permitting”, 9%are in “permitting”, and 9% have been cancelled, as presented in Figure 5.

Old investments

I Under

consideration

S Planned, but notyet in wrnnitting

Permitting

Out of the 283 old REG investment components for which information is available in both the 2012and 20 1 4 Regional Plans, the Agency has found that 1 1 % are currently “under consideration”, 20%are “planned, but not yet in permitting”, 32% are in “permitting”, 15% are “under construction”, 13%have been commissioned and 9% have been cancelled, as presented in Figure 7. Compared to thestatus of the REG investments in 2014 summarised in Figure 8, the Agency observes a significantlyhigher percentage of cancelled investments and significant decrease of the investments in“permitting”. The Agency notes that 44% of the REG investments which were “under construction”in 2014 have been commissioned.

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B Under construction

. Commissioned

Figure 5: The current status of the new EU-TYNDP investment components

Figure 6: Status of the new EU-TYNDPinvestment components in 2014

S Cancelled

S Underconsideration

a Planned, but notyet in permitting

a Permitting

REG investments

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figure 7: The current status of old REGinvestment components

S Cancelled


S Planned, but not yet inpermitting

Permitting

. Under construction

. Commissioned

Figure 8: The status of old REG investmentcomponents in Regional Investment Plans 2014

. Cancelled


Planned, but not yetin permitting

Permitting

I Under construction

S Commissioned

Out of the 41 new REG investment components for which information is available, the Agency hasfound that 39% are currently “under consideration”, 34% are “planned, but not yet in permitting”,12% are in “permitting”, 2% are “under construction”, and 12% have been cancelled, as presented inFigure 9.

S Underconsideration

S Planned, but notyet in permitting

S Permitting

. Underconstruction

Figure 10: The status of new REG investmentcomponents in Regional Investment Plans 2014

a Under

consideration

B Planned, butnot yet in

permitti rtg

U Permitting

New investments

figure 9: The current status of new REGinvestment components

S Cancelled

t — . — —

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OTHER investments

The status of the 20 OTHER investment components for which information is available is presentedinFigure H.

2.2 Status progress

Figure 1 1 : The current status of OTHER investments

S Caxdlled

I Underconsideration

Planned, hut notyet in petriitting

Pe

. tJnd:t

constructicn

B Commissioned

The proportions of EU-TYNDP and REG investment components that have remained at the samestatus (labelled as “stable”), progressed to the next status or reported a backward progress (labelledas “degression”) are shown in Figures 12 and 1 3 below. Overall, it can be concluded that the majorityof EU-TYNDP investments (89%) and of REG investments (82%) have remained at the same status,whilst a small share have progressed to the next status - 9% of TYNDP investments and 12% of REGinvestments - and only 2 (2%) TYNDP investments and 10 (6%) REG investments have regressed.Of the regressed investments, eleven have regressed by one status, six from “planned” to “underconsideration” and five from “permitting” to “planned”, and one investment has regressed twostatuses from “permitting” to “under consideration”.

Figure 12: Investment status progress for TYNDPinvestment components since last TYNDP

figure 13: Investment status progress forREG investment components since last

TYNDP

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S Progress s Stable Degression S Progress s Stable a Degression

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3 . Creation of interconnector capacity

Based on the available data, the Agency has analysed the implementation of 67 investmentcomponents (27 interconnector and 40 internal investment components) for which informationregarding an increase in XB GTC was provided by NRAs. The Agency notes that, out of these 67investment components, 1 9 have already been commissioned (10 internal and 9 cross-borderinvestment components).

23 investment components (8 interconnector investment components and 15 internal investmentcomponents) reported an impact on a border without information on the value of the XB GTCincrease. Four investment components reported an internal impact.

A summary ofthe expected XB GTC increase per reporting country and per border is shown in Table2.

1000 BE-FRBE 1000 BE-GB 3000

1000 BE-NL95 CZ-DEcz 13540 CZ-SK

1400 ES-FRES l700to 1800

From 300 to 400 ES-PTFT 500 Fl-SE 500

400FR-CH

500

600 to 1300FR FR-BE 3900 to 5600

1400

l000to2000 FR-DE

GB 1000 GB-BE‘5001500 GB-IE

GR 300 AL/MK/GR-RO and BG 300504

HR HR-BA 719215

BG 65 65

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90/10 (st. grid reinforcements)90/10 (st. grid reinforcements)

Table 3 presents the 7 investment components corresponding to four interconnectors, which werecommissioned and operational after the 20 1 2 EU-TYNDP, but before 31 December 2015:

. A new interconnector between France and Spain, operational since October 2015, expectedto increase the commercial capacities by 1 ,400 MW24. The investment is a HVDC link of 320kV including converter stations in Baixas (France) and Sta.Llogaia (Spain).

. Litpol link that established a first interconnection between Lithuania and Poland and wascommissioned in December 201 5 . The investment is a double-circuit interconnector operatingat 400 kV that is expected to provide in the first stage: 500 MW of tradable capacities fromLithuania to Poland and 0 MW from Poland to Lithuania25. The interconnection is expectedto increase the XB GTC to 1000 MW, after the commissioning of the second stage of theinvestment.

. Skagerrak 4, a 500 kV HVDC interconnector between Norway and Denmark, operationalsince the end ofDecember 2014.

. Italy has linked to Malta via a new electricity interconnector, operational since March 2015.The line is operating at 220 kV with a capacity of 200 MW.

IT 300/300

IT

AT-ITIT 100/100 CH-ITIT 600/600 North Africa - ITIT 100/100 Northern neighbours - IT

1280/1120

SI-IT / IT-SI

6001350

LT 600 LT-LV150

LV 500 LV-SE 500PL 1500/500 PL-DE/DE-PL 1500/500

425 RO-MDRO 1225

800 RO-TR

700 SE-DESE 1200

500 SE-Fl/fl-SE

indicative value 10005J23SI-IT 1000/100

indicative_100

23 According to AGEN-RS, the NTC values provided are only indicative, as the future conditions in neighbouringcountries are not considered in calculations. Therefore, the final NTC values on the Slovene borders will have to bebilaterally/multilaterally harmonised between the Slovenian TSO and TSOs of neighbouring countries, so that the finalvalues may vary significantly from the indicative values above.24 However, fbr the additional capacity offered to the market to reach the expected level of 1400 MW in both directions,completion of further work on the Spanish internal network is still needed.25 Export opportunities from the Polish side will depend on the current system capabilities.

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In addition, a new 300kV HVDC interconnector (Nordbalt) composed of a subsea and undergroundcable between Lithuania and Sweden was commissioned in December 201 5 and is operational sinceFebruary 2016. The investment is expected to increase the tradable capacities by 700 MW.

The total NTC increase for the commissioned interconnector investment items (excluding Nordbalt)ranges between 1460 MW and 2167 MW (depending on the direction ofthe commercial flow).

Table3:Expected increases in XB GTC and actual increases in NTC for commissioned interconnector

Border with NO426 Tjele (DK) 700 500 DK to NO(Kristiansand)Border with FR36 Sta.Llogaia (ES) 1400 600 ES-FR(Baixas)

Border with ES36 Baixas(FR) 1400 1000 FR-ES(Sta.Llogaia)Border with PL376 Alytus (LT) 500 30726 LT-PL(Elk)Border with LT376 Elk(PL) 027 160 PL-LT(Alytus)Border with MTNot in the Ragusa area,

(Maghtab Terminal 200 200 IT-MTplan Sicily (IT)Station)

4. Progress of implementation of investments

4.1 Expected commissioning dates

NRAs reported commissioning dates for 314 components. Based on these dates, Figure 14 belowpresents the expected cumulative number of components being commissioned in each year up to2030. The peak for commissioning is expected to happen in 2020 with 40 investment components.Before this peak, the figure shows a steep slope which is due to a high number of expectedcomponents to be commissioned, around 30 per year on average, for the period 2015-20 19.

26 On the basis of the data available from the TGE SA Power exchange for the period 9 December 2015 to 17 of June2016.27 Export opportunities from the Polish side will depend on the current system capabilities.

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Figure 14: Cumulative number of investment components to be commissioned per year5t)

2(11 1 Iou ?013 ?074 2C)15 2016 ?OI 1 ‘018 ?O1 bit) IC)? I 2C)12 2(J) 3 2024 2W 1026 2C)2 1 1028 1C)29 203t)

Figure 15 illustrates that commissioning tends to be postponed, since for any given year until 2023the cumulative number of investment components to be commissioned according to 2016 data islower than the number calculated according to the data provided in 2014.

Figure 15: Cumulative number of investment components to be commissioned per year (TYNDP)

60

so i—w-i

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‘:

201 1 20122013)014 2015201(201? )0182()1..920202021202220232024202520262027202820292030

——CumuIative number — 1t)14 ——(utnulative number - 2016

(*)only 53 investment components for which both 2014 and 2016 expected commissioning dates wereavailable were taken into consideration

The breakdown of the investment components expected to be commissioned in each year is shown inFigure 16.

Figure 16: Number of investment components to be commissioned by year (TYNDP)

is

i* ihII’[iII[II’i.2011 2012 1013 2Q14 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030

S Number of commissioned componerts hy year (2014) S N;rnber of commissioned components by year (2016)

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To complete the analysis, Figure 17 presents the evolution of the commissioning dates according tothe difference in number of years between the information reported in 2014 and 201 6. It confirmsthat although a majority of investment components (5 8%) keeps the same commissioning dates, 30%have a later commissioning date in 201 6 compared to 2014 while only 1 1 % have an earlier one.

Figure 17: Evolution of the commissioning dates —TYNDP investment components

IEarlier than No change late by less than tate L mcro rate by votepreviously 2 years than 2 years but than S yearsexpected less than 5

Figure 1 8 below makes the same comparison as Figure 1 5 for the cumulative number of investmentcomponents contained in the Regional Investment Plans. A similar trend is observed, i.e. for manycomponents, expectations in 2014 were for earlier commissioning dates. Based on the 146components, for which NRAs reported commissioning dates both in 2014 and 2016, a difference inthe cumulative number of the components expected to be commissioned can be observed for everyyear ofthe period 2015-2025, with an average difference ofl2 and a peak difference of22 investmentcomponents observed for 2017.

Figure 18: Cumulative number of investment components to be commissioned per year(REG)

160

0

139146

2011 2012 2013 2014 2015 2016 2017 201 2019 2020 2021 2022 2023 2024 2025 ?()26 2027 ?()2 2029 103t)————Cumu!ative number 2014 —Cumulative number - 2016

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Figure 19 shows that, during the period 2014—2017, the actual and expected number of investmentcomponents to be commissioned is lower for each year compared to the expectations of 2014.

figure 19: Number of investment components to be commissioned by year (REG)30

: I I I’i: I iii I . i _; I2011 1012 2013 2014 2015 2016 201? 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 202$ 2019 2030

R Number of commissioned components by yeat (2014) S Number of ommissioned coiponents by year (2015)

4.2 Time progress of the investments

In this section, progress of the investment components is evaluated over a two-year period (i.e. sincetheir inclusion in 2014 EU-TYNDP and/or the 2014 Regional Investment Plans).

An investment component lags behind its previous schedule if it is delayed or if the promoters decideto reschedule it for any reason.

The monitoring of progress covers in total 198 investment components for which progress data wasavailable and which meet the following criteria:

. the investment component is in a more advanced status than “under consideration”, but notyet commissioned, and

. the investment component is not cancelled.

figure 20 shows the progress in the implementation of those investment components. Out of 198investment components, less than half managed to keep their previous schedule, while 35% aredelayed and 22% are rescheduled.

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Figure 20: The current progress of investment components since 2014, excluding those underconsideration, cancelled or commissioned

(35%)

A breakdown ofthe progress of investment components by their status is presented in Figure 2 1 . TheFigure shows that components which are in the “planned, but not yet in permitting” or in the“permitting” statuses are more frequently delayed, than investments “under construction” (35% and38% compared to 28%).

Figure 21: Breakdown on the progress ofinvestment components by their status

A separate evaluation of progress was carried out for those investment components which have beencommissioned since their inclusion in the 2014 EU-TYNDP or 2014 Regional Investment Plans, theresults of which are presented in Figure 22. The progress data was available for slightly more thanhalf of the commissioned investment components (i.e. 37 out of 66).

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figure 22: Progress of investment components from 2014 until their commissioning

4.3 Rescheduling, delays and difficulties encountered by project promoters

This section focuses on the reasons for delays and for the rescheduling of investments, as the Agencyaspires to provide policy makers and involved authorities with the necessary information they wouldneed to make the appropriate policy decisions to address the identified problems.

The following paragraphs analyse in more detail the reasons of delays and the rescheduling reportedby the project promoters.

Reasons for delays

The main reason for delays was indicated for 49 out of the 69 investment components which werereported as delayed and which are in a more advanced status than “under consideration”. As presentedin figure 23 , for 3 1 (64%) of the investment components, the main reason for the delay was claimedto be linked to permitting, and in most cases to changes in national laws on permitting. further, for 3of the investment components the delay is due to other investments being delayed and in the case of3 other investment components the reason is related to the tendering process. The remaining reasonsinclude delays related to public debates, to the acquisition of land and to the need for cross-bordercoordination. In 6 cases, an “other” reason was reported but without a clear description of the (main)reason.

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Figure 23: Main reasons for delay

2 (2%)(4%)

6

12%)

(4%)

(64%)

(2%)

(6%)

a )e1aV due to tondoong process

I Delay reldted to fiaiisaticc of agreerncnts and coordination across

. Dedy5 due to t or relat ion ciith ot1r delayed tr ansmission liCSt1iI5 ets

: Delays slat ed to as 1UiStf)t5 of or at tess to land

Deiays relatso to the ntihc debate

K Reevaluation of the assumptions jttstdying the projet t.

. P[RMTI!NG Delaysdue to environmental problems

PERMIIt ING Delays due to cUter perrmt Cratine reasons

II PERMIFI iNti National law changes affectinp petmitting

Reasons for rescheduling

The main reason for rescheduling was reported for 32 out of the 42 rescheduled investmentcomponents. The frequencies of the main reasons for rescheduling are presented in Figure 24. Themost frequent main reason, reported for more than halfofthe rescheduled investment components, isrelated to changes on the generation side (about halfofthem mentioned changes linked to renewable-based generation). The second most frequent reason for rescheduling relates to changes on thedemand side (5 investment components). Further, 4 investment components have been rescheduleddue to changes in the overall planning data (i.e. for both the generation and demand or in otherplanning data) and 3 investment components have been rescheduled due to other prioritisedtransmission investments, one due to changes in works and one reported an “other” reason28.

28 The reason indicated is that “after completion ofthe main parts, additional interventions are planned”.

o44

ACER— .\g4n( V for th( Coopertion

ol Irergv ReguLtors

Figure 24: Main reasons for rescheduling

R ( Itanges due t other tot tS(d

tratist!ussIt)rl tflVtstr1le11t

— t hariges in th( ovct all planning Uatinput

t Itttges )t tllr generaton S(t

I ( Iie on th detnn side

. C lianges in sOtSW s:orks

S Othet

The reason behind cancellation was provided for 24 of the 52 cancelled investment components aspresented in Figure 25. The most frequent reason is related to changes on the generation side (10investment items), followed by changes on the demand side (3 instances), cancellation due to othertransmission investments (3 instances), changes in the overall planning process and inputs (2instances), environmental reasons (one instance) and a change in national laws (one instance). In 4instances, “other” reasons were reported, which, in most cases, were related to the insufficientmaturity of the investment.

o\4

N

Reasons for cancellation

ACERAgency for th (oprat ionof Lncrgv Rgulators

I Other

Figure 25: Main reason for cancellation

Page2I\<4

K Changes due to other transmission investments • Changes due to the overall planning process and inputs

( Changes on the demand side • Changes on the generation side

S environmenta’ reasons and re routings • National laws

ACERAgen4:y for thi (oc)prtc)nC)1 Lncrgv Regulators

Annex II — Information on components of transmission investments

National Regulatory Authorities from 30 jurisdictions (AT, BE, BG, CY, CZ, DE, DK, EE, EL, ES, Fl, FR, GB, HR, HU, IE, IT, LT, LU, LV, MT,NI, NL, NO, PL, PT, RO, SE, SI, 5K) participated in the process, providing their inputs on components oftransmission investments by 30 June 2016.

Table I: List of commissioned interconnector investment components

\Page22of44

Sta.L1oaia (ES’0000041

0000041

0000456

0000456

0000473

FR

FT

PL

LT

Border with FR

ACER . .Country . . . CommissioningInvestment Item Substation 1 Substation 2 Progress in countryCode dateCode

Delayed

Border with ES Baixas (FR) 2015

Alytus (LT) State border (PL-LT) On time 2015

State border (PL-LT) Elk (PL) 2015

2014

Klaipeda (LT) Border with SE On time

0000473 SE Border with LI Nybro (SE) 2016

00005 10 NO Kristiansand (NO) Border with DK 2015

00005 10 DK Border with NO Tjele (DK) On time 2014

000900 1 MI Maghtab Terminal Station Ragusa Terminal Station

0009001 II Ragusa area, Sicily (IT) Border with Malta On time2015

2015

ACER

— :\g(ncy for the Coopkr:tiont) tncrgv Regulators

Table II: List of commissioned internal investment components

0000002 PT V.Minho(PT) - 20140000059 ES Pesoz (ES) Grado (ES) Delayed 20140000101 ES Ayora (ES) Pinilla (ES) On time 20160000102 ES Campanario (ES) On time 20160000 1 1 5 ES Guillena (ES) Almaraz (ES) On time00001 16 ES Arroyo S.Servan (ES) Delayed0000146 ES Amorebieta (ES) Guefles (ES)

0000157 FR Biancon(fR) LaBocca(FR) Ontime 2015000015$ FR Trans (FR) Boutre (FR) On time 201500001 59 FR Biancon (FR) Frejus (FR) On time 20150000174 BE VanEyck(BE) Ontime 20150000175 BE Gramme(BE) VanEyck(BE) 201500002$2 DK Kasso(DK) Tjele(DK) 201400002$3 LU Schifflange(LU) Delayed 201600002$4 LU Schifflange(LU) Delayed 2015000033 1 DE Gütersloh (DE) Bechterdissen (DE) On time 20140000337 DE Mühlhausen (DE) GroBgartach (DE)0000359 DE Bärwalde (DE) Schmölln (DE)0000412 GR Lagadas(GR) 2011

”f 44

0000001 PT V.Minho (PT) Pedralva (PT) On time 2015

ACERAg(mcy for the Cooptrt Ionof trwrgv

ACERInvestment CommissioningItem Code Country Code Substation 1 Stibstation 2 Progress date

0000439 CZ Vyskov (CZ) Cechy stred (CZ) Expected ahead ofschedule 2015

0000457 PL Siedice Ujrzanów (PL) Milosna (PL) On time 20150000458 PL Elk(PL) Lomza(PL) 20150000459 PL Lomza(PL) Ontime 20150000460 PL Ostroleka(PL) Ontime 20150000461 PL Ostroleka (PL) Narew (PL) On time0000464 PL $tanislawów (PL) On time

0000471 LT Klaipeda (LI) Telsiai (LT) On time 20140000480 EE Tartu(EE) Sindi(EE) 2014

0000490 Fl Ulvila (Fl) Kristinestad (Fl) On time 20140000493 Fl Hikiä (Fl) Forssa (Fl) On time 20160000497 SE Hallsberg (SE) Barkeryd (SE) On time

0000508 GB Walpole (GB) Bramford (GB) Rescheduled0000509 NO Kristiansand (NO) Rød (NO)

0000522 GB Pelham (GB) Waltham Cross (GB) On time 20190000539 GB Beauly(GB) Denny(GB) Ontime 20150000570 FR Plaine-Haute (FR) On time 2015

0000572 FR Brennilis (FR) On time 20150000648 FR Somme (FR) On time 20150000666 AT Dümrohr (AT) Sarasdorf(AT) 20140000671 GR Polypotamo (GR) N. Makri (GR) 20130000672 GR Polypotamo (GR) N. Evia (GR) 2013

of

ACER

m Agency for tb. ( &perat ont)L 1nergy Regu1ator

ACERInvestment CommissioningItem Code Country Code Substation 1 Substation 2 Progress date

Feda, Tonstad (NO)

PL Siedice Ujrzanów On time 20 15/2019PL Elk Bis On time

ES Bescanó Santa Llogaia 2016

0000697

0000722

00008530000854

0000874

0000875

0000878 HU Perkáta Ontime 2015point of splitting

0000885 SK Vola (SK) 20140000887 SK Vola 2014

0000903 NO Kristiansand, Feda On time0000917 ES Grado

0000941 EE Pussi missing (EE) 20140000950 SI Krsko Bericevo (SI) On time0000954 ES Sta.Llogaia

PL Pasikurowice (PL) wiebodzice (PL)

ES

On time

Santa Llogaia

2013

ACERAg.mcy for the Cooperationc)i I’nertv Regulators

Table III: Delayed interconnection investments and related reasons

Connah’s Afier0000628 Glmsk400kV Quay 2018 IF 2020 GB 2020

Border with Delay in tendering0000668 Sisak(HR) BA HR 2017 BA N/A process N/A

Delay related tofinalisation ofagreements and

Border with coordination across0000676 Suceava (RO) MD RO 2023 MD N/A borders N/A

Delays due to otherPrati di Vizze $teinach permit granting

0000187 (IT) (AT) 2016 IT 2019 AT reasons

PERMITTING

ACERAgncy for th. Coopt’rE On

ol Lncrgv Rvu1ators

Table IV: Delayed internal investments and related reasons

Commissioningdate in Commissioni

ACER Investment Item TYNDP/REG ng date inCode Country Code Substation 1 Substation 2 2014 country Reason for delay

Ponte de0000004 PT Pedralva (PT) Lima (PT) 2015 2015

Arenales- PERMITTiNG - National law0000037 ES JM Oriol (ES) Caceres (ES) 2017 2017 changes affecting permitting

PERMITTING - National law0000038 ES Arenales (ES) 2017 2018 changes affecting permitting

0000040 ES Arkale(ES) Hemani(ES) 2015 2016

2025 (based PERMITTING - Delays due to0000042 IT Cassano (IT) Chiañ (IT) 2022 on NDP 201 6) environmental problems

NDP 2016:S. Barbara long term PERMITTING - Delays due to

0000044 IT Villanova (IT) (IT) 2020 (beyond 2023) other permit granting reasons

0000046 ES Ramis(ES) 2015 2016 Other

PERMITTiNG - National law0000051 ES Soto (ES) Tabiella (ES) 2017 2018 changes affecting permitting

of’%

ACERAg(ncv for the (opcrt ionof LEiCTIV Regulators



PERMITTING - National lawchanges affecting permitting0000052 ES Gueñes (ES) Ichaso (ES) 2020 2020

PERMITTING - National law0000053 ES Gozón (ES) 2016 2018 changes affecting permitting

PERMITTING - National law0000056 ES Solorzano (ES) 2015 2015 changes affecting permitting

PERMITTiNG - National law0000062 ES Sama (ES) 2026 2020 changes affecting permitting

BOIMENTE PERMITTiNG - National law0000064 ES PESOZ (ES) (ES) 2016 2016 changes affecting permitting

Castejón PERMITTING - National law0000068 ES Ichaso (ES) (ES) 2020 2020 changes affecting permitting

0000072 ES Aragon(ES) Peñaflor(ES) 2016 2016 Other

Magallón0000073 ES Tudela(ES) (ES) 2018 2018 Other

0000074 ES LaSema(ES) Ichaso(ES) 2017 2017 Other

Page 2$

ACERm Agetb:y for th (oopration

ol Inergv Regulators



PERMITTING - National lawchanges affecting permitting

Of

0000084 ESMoncayo

Dicastillo (ES) (ES) 2017 2017

PERMITTiNG - National law0000085 ES Amero (ES) 2029 2029 changes affecting permitting

PERMITTING - National law0000086 ES Aragón (ES) Isona (ES) 2029 2029 changes affecting permitting

PERMITTING - National law0000091 ES Isona (ES) Calders (ES) 2029 2018 changes affecting permitting

PERMITTING - Delays due toother permit granting reasons(different than law changes,environmental problems orpreparation of application files).Please explain in the relevant

0000093 ES Mangraners (ES) Begues (ES) 2017 2018 question below

Vandellos PERMITTING - National law0000095 ES Garraf(ES) (ES) 2027 2027 changes affecting permitting

Galapagar0000125 ES Tordesillas(E$) (ES) 2016 2016

ACER

— Ag(ncy for th Cooprit onc)1 Loergy R*gu1ators



PERMITTING - National lawchanges affecting permitting0000128 ES

SSReyesLoeches (ES) (ES) 2019 2020

0000132 ES Aldeadavila(ES) Almaraz(ES) 2016 2017

Arafluelo0000133 ES Aldeadavila(ES) (ES) 2016 2017

0000134 ES Villaviciosa (ES) Almaraz (ES) 2016 2018

T.Velasco0000135 ES Picon(ES) (ES) 2016 2018

Arafluelo0000136 ES Valdecaballeros (ES) (ES) 2017 2019

Belinchon0000137 ES Trillo (ES) (ES) 2016 2018

0000138 ES Cofrentes(ES) Morata(ES) 2017 2019

Villaverde0000139 ES Afiover(ES) (ES) 2016 2018

\‘

l O%

ACERm :\g(n:y for th Cooprat ion

ol lncrgv RtguIators

0000154 FR



La Gaudière (FR)

Bouches duRhone area(FR)

Le Chaffard0000160 FR Cou1ane(FR) (FR)

2020 2021

Delays due to re-evaluation ofthe assumptions justifying theinvestment.

2016 2017

Delays due to correlation withMastaing other delayed transmission

0000169 FR Avelin(FR) (FR) 2017 2020 investments

Gavrelle Delays due to longer than0000170 FR Avelin(FR) (FR) 2017 2019 plannedpublic debate

NUP 2016: PERMITTING - Delays due to0000188 IT Brennero (IT) 2016 2020 other permit granting reasons

PERMITTING - Delays due toother permit granting reasons(different than law changes,environmental problems orpreparation of application files).Please explain in the relevant

0000190 IT Dolo (IT) Camin (IT) 2025 2024 question below

PERMITTING - Delays due to0000191 IT Polpet (IT) 2017 2023 other permit granting reasons

ACER

— Agency for thc Coopt?r;t iono1 Lncrgv Regulators



2016 2018PERMITTING - Delays due toother permit granting reasons

Villanova PERMITTiNG - Delays due to0000209 IT foggia (IT) (IT) 2019 2023 other permit granting reasons

NDP 2016:long term

(startconstruction PERMITTiNG - Delays due to

0000228 IT Assoro (IT) 2019 2024) other permit granting reasonsNDP 2016:long term

(startVillaftanca construction PERMITTING - Delays due to

0000229 IT Assoro (IT) (IT) 20 1 9 2024) other permit granting reasons

PERMITTING - Delays due to0000230 IT Patemô (IT) Priolo (IT) 2017 2024 other permit granting reasons

(Southernpart of

(Southern part of Noiway)(NO0000278 NO Norway) (NO) ) 2020 2021-2022

Delays related to acquisition of0000402 RO Sacalaz (RO) 2022 2023 or access to land

N

0000195 ITRedipuglia

West Udine (IT) (IT)

ACERAgnce For th ()()prt tOO

ol 1ncrgv RtguIators

Delays due to correlation withother delayed transmissioninvestments

PERMITTiNG - Delays due toenvironmental problems

o

0000424 RO



0000425

Medgidia S (RO)

RO400 kV Medgidia S(RO)

2016Rahman(RO)

Dobrudja(BG) split

2018

2016 2018

___________

,

400kVOHLStupina(RO)Vama(BG) PERMITTiNG - Delays due to

0000426 RO Medgidia S split 201 6 201 8 environmental problems

Medgidia(R0000428 RO Constanta (RO) 0) 2020 2022 Other

Hasle(NO)Tegneby

Rod (NO) Sylling (NO) (NO)Tegneb PERMITTING - Delays due to0000501 NO Flesaker(NO) y(NO) 2016 2017-2018 environmental problems

Waltham0000523 GB Hackney(GB) Cross(GB) 2021 2019

0000532 GB Hunterston(GB) Deeside(GB) 2016 2016

ACER

Agncv for the (()c)prat tonttt 1’ttergv Rgu1ators

2017 2019 Other

Formentera0000747 ES Toremte (Ibiza)(ES) (ES) 2016 2018

0000748 CZ Hradec (CZ) Chrast (CZ) 2026 2025

0000753 CZ Detmarovice (CZ) 202 1 2025

0000829 HU Szigetcsép(HU) 2016 2017 Delayintenderingprocess

Delays due to correlation withBrasov 400 other delayed transmission

0000832 RO Stalpu400kV kV 2024 2025 investments

0000857 IT Volpago (IT) 2020 2020

Sogndal0000927 NO Aurland(NO) (NO) 2018 2019-2020 Other

0000646

0000686

FR



HU

Sud-Aveyron

DebrecenlKisvárda(HU)

2018 2019

o44

ACERAg4mcy for th. (O)pTh()fl

()t Lrwrc’ RecuIatürs

Table V: Rescheduled internal investments (excluding investments “under consideration”) and related reasons

CommissioningACER date in Reason forInvestment Item TYNDP/REG Commissioning rescheduling in eachCode Country Code Substation 1 Substation 2 2014 date country country I EU

V. P. Aguiar (byCarrapatelo)

Estarreja (byCarrapatelo)

29 Due to the expected delay ofthe connection ofnew RES generation in North and Center of Portugal.

0000008 PT 2017 2020Changes on generationsideChanges on thegeneration side (inrelation to new

Ribeira de Pena renewable-based0000009 PT (PT) Guarda (PT) 2025 >2025 generation)29

Changes on generation0000010 PT Seia(PT) 2021 2021-2023 side

Changes on generation0000012 PT Penela (PT) 2016 2021-2023 side

Seia (By Penela (By Changes on generation0000013 PT Arganil/Gois) Arganil/Gois) 2016 2021-2023 side

Paraimo I Changes on generation0000014 PT Penela (PT) Batalha(PT) 2016 2021-2023 side

Changes on thegeneration side (inrelation to newrenewable-based

00000 1 6 PT Guarda (PT) 202 1 2023/2024 generation)

ACERAg(nc\ for th (oprionof Energy Rcgulators

Changes on thegeneration side (inrelation to newrenewable-based

0000019 PT Seia (PT) Guarda (PT) 2025 >2025 generation)

Changes on the demand0000020 PT Alm. Bispo (PT) 2021 2023-2025 side

Rio Maior (by Fanhôes (by Changes on the demand0000021 PT A.Bispo) A.Bispo) 2021 2023 side

Changes on the demand0000022 PT Pegôes(PT) 2018 2018 side

0000065 ES GOZON (ES) SAMA (ES) 2026 2020 Changes on demand side

0000100 ES Cofrentes(ES) Ayora(ES) 2016 2016

0000104 ES Romica (ES) Manzanares (ES) 2030 2030 Other

0000120 ES LaRibina(ES)

Galapagar0000126 ES Moraleja Segovia 2030 2026

0000018 PT


Falagueira (PT) Pego (PT) 2019Changes on generation

2023 side

ACER

m .\geny for thL’ (()OW1t LOfl

of Inergv Rgu1ators

30 After completion ofthe main parts by 2015, additional interventions are planned to start in 2017 and being completed in the long term.

of 41\)

0000129

0000140

Fuencarral (ES)


Galapagar (ES) 2017

Morata (ES) Almaraz (ES) 2020 2020

2016

0000141 ES Olmedilla (ES) Morata (ES) 2030 2020

Other

_____________

,

by 2015

(commissioned),parts in the long

00001 66 IT Turin (IT) 2019 term Other3°Changes in the overallplanning data input(generation, demand and

0000213 HR Konjsko(HR) 2016 2020 transmission)

Changes on generation0000430 RO Suceava(RO) Gadalin(RO) 202 1 2023 side

Changes due to other0000433 RO Teleajen (RO) 2019 2020 transmission investments

ACERm Agency for the (:t)opL’r1El()n

ol LnCrV RegUlatOTS

Changes due tocorrelation with otherrescheduled transmission

2030 investments3’

31 The realisation ofthis investment is linked to realisation ofthe PCI 3.18.1 Interconnection between Kisvárda area (FLU) and Vel’ké Kapuany (SK).

Page


0000437 $KVelké Kapuany

Lemeany ($K) (SK) 2018

‘ Changes due to other0000445 CZ Tynec (CZ) Krasilcov (CZ) 2025 after 2035 transmission investments

Changes on generation0000472 LT Panevezys (LT) Musa (LT) 2022 2023 side

Changes on generation0000505 GB Bramford (GB) Twinstead (GB) 2022 2018 side

Changes on generation0000528 GB Gravir(GB) Beauly(GB) 2018 2020 side

Changes on generation0000529 GB Gravir(GB) Beauly(GB) 2018 2020 side

Changes on generation0000545 GB Wylfa (GB) Pembroke (GB) 2025 2022 side

Trawsfynydd Changes on generation0000546 GB Pentir(GB) (GB) 2020 2018 side

Changes on generation0000547 GB Wylfa (GB) Pentir (GB) 2023 2023 side

ACERAg(ncy for the (oop’rt ionol tncrgy Rcgulators

CommissioningACER date in Reason forInvestment Item TYNDP/REG Commissioning rescheduling in eachCode Cotintrv Code Substation 1 Substation 2 2014 date country country I EU

Under UnderConsideration Consideration

0000560 GB (GB) (GB) 2020

Changes on generation000065 1 PT Guarda (PT) Fundâo (PT) 2022 2024 side32

0000735 HU Albertfalva(HU) 2018 2019 Other33

0000742 CZ Tynec (CZ) Cechy stred (CZ) 2025 after 2035

0000745 CZ Prosenice (CZ) Krasikov (CZ) 2026 after 2035Changes in the overallplanning data input

(generation, demand and0000838 HU Kerepes (HU) 2025 2023 transmission)

Changes in the overallplanning data input(generation, demand and

0000839 HU Kerepes (HU) Zugló (HU) 2025 2023 transmission)

32 Due to the expected delay on the connection of new RES generation in the Center of Portugal.33 New transformer needed for connection ofNew Csepel III powerplant. The powerplant’s investment has been postponed.

of

ACER— Agncy for tht Coop’rat ion

ot tnergy 1uIator


0000840 HU Paks II (HU) 2023

0000841 HU PaksII(HU) Albertirsa(HU) 2024 2023 Other35

0000842 HU Paks II (HU) Paks (flU) 2024 2023 Other36

Székesfehérvár Changes on demand0000913 HU (HU) 2023 2024 side37

34 New substation needed for connection ofNew Paks II powerplant. The substation has to be ready till the power plant’s commissioning.35 New transmission line needed for connection ofNew Paks II powerplant. The transmission line has to be ready till the power plant’s commissioning.36 New transmission line needed for connection ofNew Paks II powerplant. The transmission line has to be ready till the power plant’s commissioning.37 Originally expected demand growth did not realise.

Page 4O

2024 Other34

0000631 IF

0000760 IF

0000772 IF

0000799 SF

Border with AT

Dunstown (IF)

North West Ireland

Border with DK

Border with NO

of’

ACER:\tencv for th t.oc)prat wnof• Energy Regulators

Table VI: Cancelled interconnector investments and related reasons

0000024 IT tbd (IT) Other

0000800

ACER

Investment

Item Code Country Code Substation 1 Substation 2 Reasons for cancellation

SF

Border with GB

Irish midlands (IF) Border with GB Changes on the demand side

(IF) Border with GB

Station SF3

Gmndfors

0000947 LT Visaginas (LT) Border with LV -

0000947 LV Border with FT Liksna (LV) Changes on the generation side

0000949 SF Border with LV SF3 -

ACER

Agency for the ((()prH onol Inergv RguIators

Table VII: Cancelled internal investments and related reasons

0000067

0000088

0000089

0000090

0000108

0000109

0000110 ES

ES

Costa Verde (ES)

Escatron (ES) La Secuita (ES)

ACERInvestment Countr

Item Codey

Code Substation 1 Substation 2 Reasons for cancellation

Cartuja (ES)

ES Els Aubals (ES) National laws

La Secuita (ES)

Cordoba (ES)

Cartuja Arcos

Cartuja-Pto Sta0000 1 1 1 ES Maria (ES) Facinas (ES)

0000 1 1 2 ES Guadaira (ES)

0000 1 1 3 ES Don Rodrigo (ES) Guadaira (ES)

0000 1 1 8 ES Caparacena (ES) La Ribina (ES)

0000119 ES Baza(ES)

Valdemingomez0000143 ES (ES)

0000367 DE Goldshöfe (DE) BUnzwangen (DE)

0000388 HU Gyor (HU) Changes on the demand side

ACER

Ag(ncy for the Cooprat ionol ncrgv Rgu1ators

ACER

Investment Countr

Item Code y Code Substation 1 Substation 2 Reasons for cancellation

Gyor (HU) Changes on the demand side

Page

43’k.:

0000389 HU

000045 1 PL Plewiska (PL)

0000495 SE Ekhyddan (SE) Barkeryd (SE) Changes due to other transmission investments

0000506 GB Bramford (GB) Sizewell C (GB)

Amagervierket Glentegârd & H.C.00005 1 6 DK (DK) Ørstedwerket (DK) Changes due to other transmission investments

0000525 GB Tilbury (GB) Elstree (GB)

West Weybridge0000527 GB (GB) Beddington(GB)

0000561 SE Dingtuna (SE) Karislund (SE) Changes on the generation side

0000562 SE Forsmark (SE) Râsten (SE) Changes on the generation side

0000563 SE Ràsten (SE) Ostfora (SE) Changes on generation side

0000564 SE Forsmark (SE) Stackbo (SE) Changes on the generation side

AuraNiklandet0000595 NO (NO) Fáberg (NO) Other

0000599 PL Krajnik(PL) Other

55 4 /11 kV0000601 BG Svoboda(Krusañ) Changes on the generation side

0000602 BG 55 4 /1 1 kV Vidno Changes on the generation side

0000603 BG Vidno (BG) Svoboda (BG) Changes on the generation side

ACER

— Ag(ncy for th (tprtlonOL [:ncrgy Rtgu1ators

IN-OUT inSvoboda on actual 4

0000604 BG kV OHL Is

Forssa (FI)Lieto0000608 Fl Rauma (Fl) (FI)Ulvila (Fl)

Under0000623 SE consideration (SE)

0000629 SE Rábäcken (SE) Trolltjäm (SE) Changes due to other transmission investments

0000652 ES Almazan Medinaceli -

0000654 ES Cordoba Cordoba -

0000670 GR Aliveri(GR) Larimna (GR)

0000833 HR Emestinovo -

0000860 BE Lixhe Herderen -

000088 1 IE Carrickmines (IE) Dunstown (IE) -

0000889 IE Carrickmines (IE) Changes due to the overall planning process and inputs

0000904 BG Svoboda (BG) splitting point Changes on the generation side

ofk

ACERInvestment CountrItem Code y Code Substation I Substation 2 Reasons for cancellation

Dobrudja Changes on generation side

transmission networks on the implementation of …€¦ · border commercial capacities (i.e. ntc)....

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