TPP Task 2 Transmission system impact assesment by Lorik Haxhiu

November, 2007

European Agency for Reconstruction Contract nr 05KOS01/04/005 Studies to support the development of new generation capacities and related transmission – Kosovo UNMIK CONSORTIUM OF PÖYRY, CESI, TERNA AND DECON TASK 2 Transmission System Impact Assessment

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Studies to support the development of new generation capacities and related transmission Task 2, Transmission System Impact Assessment

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Disclaimer

While the consortium of Pรถyry, CESI, TERNA and DECON considers that the information and opinions given in this work are sound, all parties must rely upon their own skill and judgment when making use of it. The consortium members do not make any representation or warranty, expressed or implied, as to the accuracy or completeness of the information contained in this report and assumes no responsibility for the accuracy or completeness of such information. The consortium members will not assume any liability to anyone for any loss or damage arising out of the provision of this report. The report contains projections that are based on assumptions that are subject to uncertainties and contingencies. Because of the subjective judgments and inherent uncertainties of projections, and because events frequently do not occur as expected, there can be no assurance that the projections contained herein will be realized and actual results may be different from projected results. Hence the results and projections supplied are not to be regarded as firm predictions of the future, but rather as illustrations of what might happen. Parties are advised to base their actions on an awareness of the range of such projections, and to note that the range necessarily broadens in the latter years of the projections.

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Table of contents 1

TASK REPORT FOR TASK 2: TRANSMISSION SYSTEM IMPACT ASSESSMENT ...................................................................................................................6

1.1

Assess of the availability of transmission capacity for inter-regional Transfers (Part of Subtask 2.1 of ToR) .............................................................................................................7 History of Energy Exchanges on Kosovo 400 kV transmission system ..............................7 Conclusions ..........................................................................................................................8 Assess the transmission expansion plans and new interconnection projects of SEE transmission network (Part of Subtask 2.1 of ToR) .............................................................9 Development of SEE transmission network.........................................................................9 Development of SEE generation system ............................................................................11 Establishment of Transmission Network Model of SEE (Part of Subtask 2.2 of ToR).....11 SEE national Peak Loads ...................................................................................................14 Substation Loads ................................................................................................................15 Scenarios of Power Exchange ............................................................................................15 Options regarding sites, connection schemes and unit size of the new plant.....................16 Connection schemes of the new plant ................................................................................16 Options of generation unit size of the new plant................................................................18 Steady State Analysis of Interconnected Transmission Network (Part of Subtask 2.3 of ToR) ...................................................................................................................................20 Introduction Load flow studies ..........................................................................................20 Analysis of steady-state conditions of the year 2012.........................................................21 Network configuration with the 400 kV line Kosovo C (KS) – Kashar (AL) ...................22 Year 2012 Network configuration without the 400 kV line Kosovo C (KS) - Kashar(AL) .. ............................................................................................................................................28 Year 2012 Conclusion........................................................................................................31 Analysis of steady-state conditions of the year 2014.........................................................33 Year 2014 Network configuration with the 400 kV line Kosovo C (KS) - Kashar(AL) ..33 Year 2014 Network configuration without the 400 kV line Kosovo C (KS) – Kashar (AL)........................................................................................................................39 Year 2014 Conclusion........................................................................................................42 Analysis of steady-state conditions of the year 2016.........................................................44 Year 2016 Option 1 of new TPP Kosovo C: third unit 500 MW.......................................44 Year 2016 Option 3 of new TPP Kosovo C: second unit 750 MW ...................................48 Year 2016 Conclusion........................................................................................................48 Analysis of steady-state conditions of the year 2018.........................................................50 Network configuration without additional reinforcements ................................................50 Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK)...........54 Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) and with a new 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR)...............................56 Year 2018 Conclusion........................................................................................................58 Analysis of steady-state conditions of the year 2020.........................................................59 Network configuration without additional reinforcements ................................................59 Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK)...........63 Network configuration with a new 400 kV line Skopje 4 (MK)- Leskovac (SR) (Nis)(SR) ............................................................................................................................64 Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) and 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR) .................................................66

1.1.1 1.1.2 1.2 1.2.1 1.2.2 1.3 1.3.1 1.3.2 1.3.3 1.3.4 1.3.4.1 1.3.4.2 1.4 1.4.1 1.4.2 1.4.2.1 1.4.2.2 1.4.2.3 1.4.3 1.4.3.1 1.4.3.2 1.4.3.3 1.4.4 1.4.4.1 1.4.4.2 1.4.4.3 1.4.5 1.4.5.1 1.4.5.2 1.4.5.3 1.4.5.4 1.4.6 1.4.6.1 1.4.6.2 1.4.6.3 1.4.6.4

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Studies to support the development of new generation capacities and related transmission Task 2, Transmission System Impact Assessment

1.4.6.5 1.5 1.5.1 1.5.2 1.5.3 1.5.3.1 1.5.3.2 1.5.3.3 1.5.3.4 1.5.3.5 1.5.3.6 1.6 1.6.1 1.6.2 1.6.3 1.6.4 1.7 1.7.1 1.7.2 1.7.3 1.7.4 1.7.4.1 1.7.4.2 1.7.5 1.7.6 1.7.6.1 1.7.6.2 1.7.7 1.7.7.1 1.7.7.2 1.7.7.3 1.7.8 1.7.8.1 1.7.8.2 1.7.8.3 1.7.9 1.7.9.1 1.7.9.2 1.7.10 1.7.10.1 (MK) 1.7.10.2 1.7.10.3 1.7.10.4 1.7.11

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Year 2020 Conclusion........................................................................................................67 Evaluation of adequacy of Regional transmission System and its Transfer Capability (Part of Subtasks 2.2 and 2.3 of ToR) ................................................................................68 Introduction ........................................................................................................................68 Methodology of computing NTC .......................................................................................70 Definition of Transfer Capabilities of transmission network.............................................71 Target year 2012.................................................................................................................72 Target year 2014.................................................................................................................75 Target year 2016.................................................................................................................78 Target year 2018.................................................................................................................79 Target year 2020.................................................................................................................82 Conclusion..........................................................................................................................88 Capacity Allocation and Congestion Management (Part of Subtasks 2.1 of ToR)............91 Introduction ........................................................................................................................91 Congestion Management methods in SEE .........................................................................92 Work status of the Coordinated Auctions dry-run simulation in SEE ...............................94 Coordinated Auctioning: A market-base method for transmission capacity allocation in meshed network..................................................................................................................95 Transient Stability Analysis (Part of the subtask 2.2 of ToR) ...........................................97 Introduction ........................................................................................................................97 Evidence of System Stability .............................................................................................97 Transient simulation Methodology ....................................................................................98 Simulation for Validation of Dynamic Model ...................................................................99 Test of dynamic behavior of control devices .....................................................................99 Reconstruction of selected emergencies ..........................................................................100 System Disturbance..........................................................................................................102 Year 2012 Transient Stability Analysis ...........................................................................104 Option 2 of new plant Kosovo C: Unit size 600 MW......................................................104 Option 1 of new plant Kosovo C: Unit size 500 MW......................................................110 Year 2014 Transient Stability Analysis ...........................................................................116 Year 2014 Network configuration without the 400 kV line Kosovo C (KS) – Kashar (AL) ..........................................................................................................................................116 Year 2014 Network configuration with the 400 kV line Kosovo C (KS) – Kashar (AL)117 Year 2014 Conclusions ....................................................................................................119 Year 2016 Transient Stability Analysis ...........................................................................120 Option 1 of new plant Kosovo C: Unit sizes 500 MW ....................................................120 Option 3 of new plant Kosovo C: Unit size 750 MW......................................................123 Year 2016 Conclusions ....................................................................................................128 Year 2018 Transient Stability Analysis ...........................................................................129 Option 1 of new plant Kosovo C: Unit sizes 500 MW ....................................................129 Option 3 of new plant Kosovo C: third unit 750 MW .....................................................135 Year 2020 Transient Stability Analysis ...........................................................................141 Year 2020 Network configuration without the 400 kV line Kosovo C (KS) – Skopje 4 ...... ..........................................................................................................................................142 Year 2020 Network configuration with the 400 kV line Kosovo C (KS) – Skopje 4 . (MK) ...........................................................................................................................................144 Year 2020 Network configuration with the 400 kV line Nish (SR)-Leskovac (SR) – ........ Skopje 5 (MK).................................................................................................................145 Year 2020 Conclusions ...................................................................................................146 General Conclusions of Transient Stability .....................................................................147

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Studies to support the development of new generation capacities and related transmission Task 2, Transmission System Impact Assessment

1.8 1.8.1 1.8.1.1 1.8.1.2 1.8.1.3 1.8.1.4 1.8.1.5 1.8.1.6 1.9 1.10 1.11

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Short circuit analysis (Part of the Subtask 2.2 of ToR)....................................................152 Methodology and main assumption .................................................................................152 Short circuit calculation Year 2012..................................................................................152 Short circuit calculation: Year 2014.................................................................................153 Short circuit calculation: Year 2016.................................................................................153 Short circuit calculation: Year 2018.................................................................................153 Summary of short circuit calculation ...............................................................................153 Conclusion........................................................................................................................154 Cost Estimate of transmission network reinforcements...................................................155 Recommendations regarding reinforcements of national 220 kV, 110 kV transmission network.............................................................................................................................156 Recommendations regarding Protection and Equipment specification............................158

REFERENCES ...............................................................................................................................159

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TASK REPORT FOR TASK 2: TRANSMISSION SYSTEM IMPACT ASSESSMENT The Terms of reference for the project Studies to support the development of new generation capacities and related transmission – Kosovo UNMIK called for the consultant to significantly increase the level of understanding for the potential electricity market facing any expansion of lignite-fired generation capacity planned for Kosovo. The information to be generated should enhance the knowledge and understanding of the regional electricity market and generate a knowledge base for the Kosovan authorities, the foreseen project lenders and potential investors on which they would be better placed to make decisions regarding future power sector development. This report on Task 2 does not include the description of the respective consultant’s methodology and modeling tools. In this respect, we wish to refer materials presented in our tender. However, the consortium members are willing to make their methodology descriptions available to any party or stakeholder making such a request. The consortium has also refrained from evaluation power export potential to Greece and Italy, in order not to prejudice the position of any prospective investor candidate in the concurrent investor selection process by the Kosovan government. In this report on Task 2, the report structure does not strictly follows the description of Task 2 in the ToR. The Consultant has followed a more methodological numbering of the chapter based on a relationship of input-output of results between them. Nevertheless the report fully covers all the items of ToR. The internal sectioning and numbering of the report has been limited to number 2, to better reflect the sectioning of Task 2 in the ToR. Introduction to TASK 2 Scope of work The aim of this activity is to verify the feasibility of national and regional transmission system to deliver the maximum power plant capacity and to identify potential constraints, depending on large unit size, concerning transient stability of the regional system. The analyzed period is 2010 up to 2020. Specific objectives of this task are: •

Assessment of adequacy of the local and regional transmission system taking into consideration the planned reinforcement of the network and assessment of the costs related to improvement of transmission capacity necessary for delivery of the power from new plant to the potential off-taker.

•

Assessment of unit maximum size based on deterministic reliability analysis and transient stability studies and identifying the possible network reinforcements in order to be fully compliant with technical standards of security and reliability and rules adopted by UCTE.

•

Development of conceptual design and cost estimates for the new plant’s interconnection to bulk transmission system.

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1.1

November, 2007 Page 7 (160)

Assess of the availability of transmission capacity for inter-regional Transfers (Part of Subtask 2.1 of ToR) The transmission network of Kosovo power system is a part of the regional interconnected transmission systems and the 400 kV interconnection lines of Kosovo are some of the principal media with a wide regional interest for reliable electric supply and energy exchanges between neighboring power systems of Serbia, Montenegro, Macedonia, Greece, Albania, etc. The power transactions in the SEE region and exhibit considerable seasonal and daily load variations, with electricity demand being dependent on weather conditions, hydrology and it is reflected as variation of power transits on the main transmission lines. The existing transmission lines and interconnections between the national power systems of the region permit transactions ranging from 250 MW to 1600 MW, depending on the origin, destination path, and time period. The inter-regional scheduled transfers have a crucial impact on the loadability of the interconnection lines and, for generation and transmission planning purposes, it is important to consider appropriate levels of power exchanges between SEE countries. Referring to expected network situation up to 2020, the power exchange represents a random and uncertain variable and, in order to assess the availability of the transmission capacity, Consultant has performed a statistical analysis of the recorded power and energy transits on 400 kV transmission network of Kosovo during past period (2000-2006), aiming to definition of a set of inter-regional power transfers to be modeled on simulations as a first step for evaluation of technical performance of the actual, planned and reinforced network.

1.1.1

History of Energy Exchanges on Kosovo 400 kV transmission system The Consultant has performed a statistical analysis of the loadability of the 400 kV lines based on recorded direct measurements of the hourly power flows in interconnection lines. The objective of this part of the study is to investigate, for the period 2000 - 2006, the import-export energy flows of each one of the 400 kV lines in Kosovo and, thus to assess the future trend related to annual electricity volumes that would be traded between Kosovo and potential off-taker of regional utilities. The present 400 kV interconnection lines of Kosovo power system are: •

L407: 400 kV Kosovo B – Nish (SR), rated power 1330 MVA and natural transmission capacity 512 MVA; • L437: 400 kV Kosovo B – Ribarevina (MN), rated power 1330 MVA and natural transmission capacity 512 MVA; • L420: 400 kV Kosovo B – Skopje (MK), rated power 1330 MVA and natural transmission capacity 512 MVA; A summary of the main figures concerning development of the loadability of the 400 kV lines in Kosovo during the period 2000- 2006, are given in Annex 1. In Figure Figure 1-1 are illustrated the annual energy wheeling through transmission network of Kosovo, maximum and minimum powers in 400 kV lines during the period 2000-2006.

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In Tables A1.1 to A1.7 in Annex 1 are reported statistic data for loadability of the 400 kV lines during the period 2000-2006. During this period he wheeling of energy was significantly increased from North to South, loading the corridor Nish – Kosovo – Skopje. The daily and annual Load Factors continue to increase showing a trend toward full exploitation of the transfer capability of the corridor.

Figure 1-1 Period 2000-2006 Trend of power and annual electric energy wheeled through Kosovo network

1.1.2

Conclusions Historical data on power transfers realized by 400 kV transmission system of Kosovo show great variations from year to year and the tendency is that the volume of power and energy transfers is increasing year by year. The loading of interconnection lines depends on the level of electrical energy trades on the region and varies with load growth. All studies dedicated to the SEE region have reached at conclusion that actual inter-country electricity trade is at very low level and the electricity market is not developed to a great extent. Nevertheless the present level of loadability of 400 kV transmission system of Kosovo is quite high and the tendency is towards an increasing of the energy wheeling through Kosovo.

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In such conditions it is unlikely that present transmission system can provide the adequate available transfer capabilities for expected electricity exports from the new TPP Kosovo C utilising existing physical paths. In additional, the development of the electricity market in SEE will require more transfer capabilities for energy exchanges among countries. 1.2

Assess the transmission expansion plans and new interconnection projects of SEE transmission network (Part of Subtask 2.1 of ToR) The Consultant has reviewed all available studies and reports concerning the possible transmission network reinforcements on SEE region. In our study the transmission network reinforcements and interconnections projects of the so called “Common Interest Projects” have been considered. Consultant has found from different sources, different lists of projects with different time schedules of commissioning of new lines. The most probable projects and the projects in phase of construction or in phase of waiting decision are considered in the study. In particular the information on development of the regional transmission network considered in the REBIS Generation Investment Study (GIS) has been assessed. The objective of the revised Generation Investment Study GIS (2007) was the development of a long-term investment plan (2005-2020) for the SEE Region for power generation. It is an updated of the original GIS (2004) where one of the key objectives was also to identify priority investments in main transmission interconnections between the countries and sub-regions that allow optimizing investment requirements in power generation over the study horizon. Other available documents analyzed by Consultant and related to the expansion of the transmission network in SEE for the period from 2005 to 2020, are given in References.

1.2.1

Development of SEE transmission network The list of present situation (year 2005) of the interconnection lines in South East Europe is given in Table A2.1 in Annex 2. According to GIS study and the WG of UCTE System Development, the current state of the transmission investment planning regarding the projects of interconnection lines within the SEE part as well as projects of internal lines with a regional impact are the following: Status on the investments which have been decided Table 1-1 Planed interconnection lines in South East Europe Year 2010

Interconnection line Ugljevik - S. Mitrovica Kashar - Podgorica Maritsa Istok - Filipi Chervena Mogila - Stip Ernestinovo - Pecs (double) Bekescaba - Nadab (Oradea) Florina - Bitola (Filipi) - Kehros - Babaeski

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Interconnected countries BA - SR AL - MN BG - GR BG - MK HR - HU HU - RO GR - MK GR - TR

Voltage level (kV) 400 400 400 400 400 400 400 400

Conductors Type Size (mm2) ACSR 2x490 ACSR 2x490 ACSR 3x400 ACSR 3x490 ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR 3x400

Transfer Capacity (MVA) 1330 1330 1715 1330 1330 1178 1330 1715

Total length km 79 145 243 150 85 118 38 100

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Table 1-2 Planed internal lines in South East Europe Year 2010 Internal Lines Line Subotica 3 - Sombor 3 Line Tirana - Elbasan Line Fier - Vlore Line Karlovo - Plovdiv Line Arad - Nadab Lagada - Fillippi

Country Serbia Albania Albania Bulgaria Romania Greece

Voltage level (kV) 400 400 220 400 400 400

Conductors Type Size (mm2) ACSR 2x490 ACSR 2x490 ACSR 360 ACSR 3x490 ACSR 2x490 ACSR 3x400

Transfer Capacity

Total length

(MVA) 1330 1330 301 1330 1330 1178

km 56 45 26 60 35 110

Table 1-3 Planed substations in South East Europe Year 2010-2015 Project name

Country

Time schedule

New 400/110 kV Peja II 3 Substation New 400/110 kV Ferizaj Substation New 400/110 kV Sombor 3 Substation New 400/110 kV Jagodina 4 Substation New 400/110 kV Beograd 20 Substation New 400/220/110 kV Tirana 2 Substation New 220/110 kV Vlora Substation 400 kV Nadab connection Substation

Kosovo Kosovo Serbia Serbia Serbia Albania Albania Romania

to be completed by the year 2009 to be completed by the year 2012 to be completed by the year 2007 to be completed by the year 2007 to be completed by the year 2008 to be completed by the year 2008 to be completed by the year 2009 to be completed by the year 2008

Expansion of 400/110 kV Skopje 5 Substation

Macedonia

to be completed by the year 2006

Table 1-4 Planed interconnection lines in South East Europe Year 2015 Interconnection line

Interconnected Voltage level countries (kV)

Conductors Type

Size

Transfer Capacity

Total length

(mm2)

(MVA)

Kashar - Kosovo C Skopje - Vranje - (Leskovac) - (Nis)

AL - KS MK - SR

400 400

ACSR ACSR

2x490 2x490

1330 1330

215 192

Zemlak - Bitola

AL - MK

400

ACSR

2x490

1330

Status of investments under discussion or as candidate Table 1-5 Candidate lines in South East Europe Year 2015 Interconnection line Kosovo - Skopje Visegrad - Pljevlja Tumbri - Banja Luka Pecs - Sombor Maritsa East - Nea Santa Cirkovce - Héviz Žerjavinec - Cirkovce Suceava - Balti Pécs - Ernestinovo

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Interconnected Voltage level countries (kV) KS - MK 400 BA - MN 400 HR - BA 400 HU - SER 400 BU - GR 400 SLO- HU 400 HR - SLO 400 RO - MD 400 HU - HR 400

Conductors Type Size (mm2) ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR 2x490

Transfer Capacity (MVA) 1330 1330 1330 1330 1330 1330 1330 1330

Total length km 104 60 200 80

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Status of investments under study Table 1-6 Project of interconnection lines in South East Europe Year 2015 Project name Participation 400 kV interconnections from Macedonia to Albania and to SEETEC / EBRD Italy (BG,MK,AL,IT) New 400 kV Line between Serbia - Romania SR - RO Submarine 400 kV cable between Romania and Turkey RO -TR Submarine 400 kV cable between Croatia and Italy HR - IT 400 kV Line Zrenjanin - Timisoara SR - RO New 400 kV interconnection between Croatia and BosniaHR - BA Herzegovina

1.2.2

Time schedule Feasibility study ongoing Preliminary studies underway Preliminary studies ongoing Preliminary studies underway Preliminary studies under preparation Preliminary studies under preparation

Development of SEE generation system The Consortium for transmission system modeling has assumed the fifth scenario of the Updated GIS study as the main scenario of generation development plan. The main attributes of this scenario are: • • • • • •

free electricity markets, medium demand growth; medium fuel price development; rehabilitation of existing generation units according to relaxed curves; high electricity import scenario; no major hydro plant construction.

The total capacity of the rehabilitation of TPP in the region for the analyzed period is 4,573 MW and the total new capacity to be constructed (including Kosovo C) is 16,164MW Table A2.2 in Annex 2 reports the development of the generation plan of this scenario with the list of new and rehabilitated generation units along with time schedule of construction. 1.3

Establishment of Transmission Network Model of SEE (Part of Subtask 2.2 of ToR) Establishment of computer models for analysis of interconnected transmission system is carried out based on appropriate network model of SEE countries. The planned network configuration over planning period is considered, including all present and planned main transmission lines and other electric facilities. The REBIS GIS study has analyzed the expansion of the generation system optimized over a 15 year horizon (2005 - 2020) for three scenarios (isolated operation of each power system, regional operation of power systems, market conditions) using the WASP models. Only the third scenario has considered the transfer capabilities of the interconnection lines among the utility systems using the Generation and Transmission Maximization Model (GTMax). In addition to GTMax analysis, a dedicated study was carried out analyzing in more detailed the regional transmission network operation and the SECI Regional Transmission System Model in PSS/E was used. In our study the Consultant, as a starting point, has considered the same SECI model and associated data for preparation of Regional Transmission System Model. The data

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bases of SPIRA and SICRE softwares that are used in system analysis, have been interfaced with data base of PSS/E model. The configuration of 400 kV, 220 kV and for some countries also 150/110 kV, of each national transmission system has been considered. Considering the particularity of Kosovo transmission network as a part of an interconnected regional network, the dynamic performance simulations have been performed while operating in interconnection mode. In particular, the disturbances in dynamic simulation are applied in 400 kV interconnection lines, which affect in a sensible way the critical clearing times and, consequently, the stability of the rotors. Mathematic model of Kosovo transmission system includes the entire 400 kV, 220 kV and 110 kV transmission networks. In the model the loads are represented on the 110 kV busbars of each distribution substation. The mathematical model of the transmission network of the SEE interconnected system includes the equivalent multipole of UCTE and CENTREL together with Austria and Ukraine. The following national power systems are considered in detail till the level of 400 kV: •

Hungarian power system.

The main 400 kV and 220 (150/110) kV transmission systems of following countries are considered: • • • • • • • • • • •

Albanian power system; Bosnian power system; Bulgarian power system; Croatian power system; Greek power system; Macedonian power system; Montenegro power system; Romanian power system; Serbia power system; Slovenian power system; Turkish power system.

The main parameters of the mathematical model of the transmission network of SEE are reported in

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Table 1-7. The Base Cases of system configuration for each horizon year, 2012, 2014, 2016, 2018 and 2020 of the interconnected systems in SEE region have been prepared and stored into computer data base. Network models appropriate for static studies have been applied for representing the external networks of UCTE and Ukraine.

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Table 1-7 Parameters of the Transmission Network Model year 2020 Parameters of the Transmission Network Model System Albania Kosovo Bosnia Bulgaria Croatia Greece Macedonia Montenegro Romania Serbia Slovenia UCTE Hungary Turkey UKRAINA CENTRAL SEE

1.3.1

Substations

Nodes

85 49 185 506 190 759 96 26 828 277 139 98 58 718 3 3 4,020

126 70 247 662 274 992 127 44 1,072 377 209 115 98 1,106 3 3 5,525

Lines

Generators Transformers

130 69 252 744 290 910 134 30 1,171 400 224 79 49 1,043 0 0 5,525

115 74 209 625 242 860 121 35 905 284 174 92 123 1,656 6 4 5,525

63 29 73 163 100 260 34 21 267 121 79 19 58 774 0 0 2,061

Speed Voltage Governors Regulators 26 36 12 13 30 42 58 137 39 65 86 106 19 22 6 11 81 132 60 68 47 63 31 32 22 32 0 682 3 3 2 2 522 1,446

SEE national Peak Loads The demand and particularly the peak power forecasts for each country in SEE, except Kosovo, prepared in REBIS GIS study have been used for load modelling during the period 20010-2020. We have used the PwC [1] central case, Case 2. Table A2.3 in Annex 2 reports the peak power forecasts in SEE. The minimum peaks are forecasted using information from annual reports for SEE Power Utilities The forecasted national peaks corresponding to winter and summer time in year 2005, and horizon years 2010, 2015 and 2020 are given in Table 1-8. In Tables A2.4 and A2.5 of the Annex 2 are reported the peak load and minimum load in the model of the transmission network of SEE system. The peak of SEE interconnected system is defined as the sum of peak power of individual countries, i.e.: Albania, Kosovo, Bosnia and Herzegovina, Bulgaria, Croatia, Greece, Macedonia, Montenegro, Romania and Serbia Table 1-8 Peak development in SEE region 2005 Countries Albania Kosovo Bosnia Bulgaria Croatia Greece Macedonia Montenegro Romania Serbia

Winter MW 1.484 1.030 1.863 6.383 2.817 9.000 1.360 711 7.372 5.957

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2010

Summer MW 1.316 563 1.121 5.061 1.696 9.837 819 584 4.503 3.958

Winter MW 1.652 1.154 2.076 6.482 3.290 11.102 1.373 725 7.950 5.993

2015

Summer MW 1.440 694 1.250 5.379 1.909 12.134 827 596 4.886 3.981

Winter MW 1.989 1.270 2.410 7.025 3.838 12.705 1.607 737 9.234 6.393

2020

Summer MW 1.703 824 1.451 5.752 2.119 13.849 967 637 5.675 4.242

Winter MW 2.645 1.377 2.855 7.340 4.448 14.027 1.946 787 11.418 6.745

Summer MW 2.246 969 1.719 6.176 2.354 15.290 1.171 679 7.017 4.472

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1.3.2

November, 2007 Page 15 (160)

Substation Loads The individual substation peak loads for each power system are calculated for each horizon year based on total system peak power forecast, regional peak power forecasts and actual regional peak load profiles.. In order to identify the minimum hour within the two characteristic days, there are used the forecasted daily load curves for each target years, 2010, 2015 and 2020. The active and reactive loads at HV substation level for characteristic hours have been computed based on forecasted national peak, projection coefficients, national load profiles and power factor of individual load. The results of some countries near Kosovo for some selected years are reported in Annex 2 in Tables A2.6 to A2.13. The substation load forecast related to peak and light load conditions are stored in SPIRA database.

1.3.3

Scenarios of Power Exchange Inter-regional, North – South and East – West power exchanges scenarios have been developed for each target year and for pear and light load conditions. Based on results of REBIS GIS study of the future generation development of power systems in SEE and the results of SECI model and data concerning Regional Transmission System Model Region, we have prepared and implemented in the transmission-generation model ten bulk transit scenarios composed by power transfers from north to south, east to west and south to north. For each target years is prepared a table of bilateral transactions between national power systems that represents a set of power flows in transmission interconnected network to be superimposed to the expected export from Kosovo in a analyzed year. The selected Exchange Scenarios consider an increase of the total amount of power transfer inside the region (“simultaneous” transfers) as follows: • • • • • • • • • •

Expected total power transits in 2012 in peak condition of about 3350 MW; Expected total power transits in 2013 in light condition of about 2300 MW; Expected total power transits in 2014 in peak condition of about 2700 MW; Expected total power transits in 2015 in light condition of about 2200 MW; Expected total power transits in 2016 in peak condition of about 3150 MW; Expected total power transits in 2017 in light condition of about 2150 MW; Expected total power transits in 2018 in peak condition of about 3600 MW; Expected total power transits in 2019 in light condition of about 2350 MW; Expected total power transits in 2020 in peak condition of about 3600 MW; Expected total power transits in 2020 in light condition of about 2450 MW.

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Options regarding sites, connection schemes and unit size of the new plant Connection schemes of the new plant The three different alternatives for the new site of the TPP Kosovo C determine three different variants for the connection of the plant to the transmission network of Kosovo system. Site 1 – Near existing TPP Kosovo A. The single line diagram is reported in Figure 1-2. The 400 kV busbars are connected with a double line to 400 kV busbars of Kosovo B and the 220 kV of the new plant can be considered as extension of the existing 220 kV busbars of Kosovo A. The proposed reiforcement of the local transmission network include: • Two 400 MVA autotransformers 400/220 kV installed in Kosovo C TPP, increasing by 30% the total transfer capacity between 400 kV and 220 kV networks. • Two 220 kV lines connecting the 220 kV busbars of new TPP Kosovo C with existing TPP Kosovo B • To improve the reliability of the supply and to optimise the power flows it is proposed to reallocate the double line 220 kV of Pristina 4 from 220 kV busbars of Kosovo B to 220 kV busbars of new Kosovo C

Figure 1-2 Variant 1 for the new site of the TPP Kosovo C

Site 2 – Expansion to the north of plant TPP Kosovo B. The single line diagram is reported in Figure 1-3. The 400 kV and the 220 kV busbars of the new plant can be considered as extension of the existing busbars of Kosovo B. The proposed reiforcement of the local transmission network include: • Two 400 MVA autotransformers 400/220 kV installed in Kosovo C TPP, increasing by 30% the total transfer capacity between 400 kV and 220 kV networks.

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• •

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Two 220 kV lines connecting the 220 kV busbars of new TPP Kosovo C with existing TPP Kosovo B To improve the reliability of the supply and to optimise the power flows it is proposed to reallocate the double line 220 kV of Pristina 4 from 220 kV busbars of Kosovo B to 220 kV busbars of new Kosovo C

Figure 1-3 Variant 2 for the new site of the TPP Kosovo C

Site 3 – Area in the north-eastern corner of the Sibovc field in Bivolak. The single line diagram is reported in Figure 1-4. The 400 kV and the 220 kV busbars of the new plant are connected with double lines to the existing busbars of Kosovo B.

Figure 1-4 Variant 3 for the new site of the TPP Kosovo C

The proposed reiforcement of the local transmission network include:

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• • •

1.3.4.2

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Two 400 MVA autotransformers 400/220 kV installed in Kosovo C TPP, increasing by 30% the total transfer capacity between 400 kV and 220 kV networks. Two 220 kV lines connecting the 220 kV busbars of new TPP Kosovo C with existing TPP Kosovo B To improve the reliability of the supply and to optimise the power flows it is proposed to reallocate the 220 kV interconnection line Besiana (KS)Krushevac(SR) from 220 kV busbars of Kosovo B to 220 kV busbars of new Kosovo C

Options of generation unit size of the new plant

In our investigation for the determination of the maximum unit size, there are considered different sizes of individual generation units of new power plant assuming as candidate the unit size of 340 MW, 500 MW, 600 MW and 750MW. Three different options of composition of the new 2000 MW TPP Kosovo C are analyzed: • • • 1.

Option 1: Option 2: Option 3:

– 4 units 500 MWnet. –4 units 600 MWnet – 1 unit 500 MWnet and 2 units 750 MWnet

Unit size 500 MW technical data

The technical data of the analyzed generation unit 500 MWnet are:

Generator Rating: Nominal active power: Net active power: Minimum operating level: Nominal power factor: Nominal voltage: Generator subtransient impedance x”d: Generator transient impedance x’d: Generator impedance xd: Unit inertia H:

623 MVA 530 MW 500 MW 250 MW 0.85 24kV 0.24 0.38 2.56 1.8sec

The technical data of the step-up transformer are: 2.

Transformer Rating: Nominal voltage primary winding: Nominal voltage secondary winding:

625 MVA 410 kV 24 kV

Unit size 600 MW technical data

The technical data of the analyzed generation unit 600 MWnet are:

Generator Rating: Nominal active power: Net active power: Minimum operating level: Nominal power factor: Nominal voltage:

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Generator subtransient impedance x”d: Generator transient impedance x’d: Generator impedance xd: Unit inertia H:

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0.24 0.38 2.56 1.8sec

The technical data of the step-up transformer are: 3.

Transformer Rating: Nominal voltage primary winding: Nominal voltage secondary winding:

750 MVA 410 kV 24 kV

Unit size 750 MW technical data

The technical data of the analyzed generation unit 750 MWnet are:

Generator Rating: Nominal active power: Net active power: Minimum operting level: Nominal power factor: Nominal voltage: Generator subtransient impedance x”d: Generator transient impedance x’d: Generator impedance xd: Unit inertia H:

953 MVA 810 MW 750 MW 450 MW 0.85 24kV 0.2 0.36 2.5 2sec

The technical data of the step-up transformer are:

Transformer Rating: Nominal voltage primary winding: Nominal voltage secondary winding:

960 MVA 410 kV 24 kV

Voltage regulators and excitation systems

The block diagram and the parameters of the type of voltage regulator and excitation system that have been used are given in Annex 5. Governors control system

The block diagram and the parameters of the type of governor control system that is implemented in the Data Base for the new unit is given in Annex 5.

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1.4

Steady State Analysis of Interconnected Transmission Network (Part of Subtask 2.3 of ToR)

1.4.1

Introduction Load flow studies

Full active and reactive power load-flow calculations have been performed in order to correctly simulate the steady-state conditions of the transmission system assessing the ability of transmission system to deliver the electric power to load centers and imported countries under a wide variety of system operating conditions. The aim of the study is the evaluation of the overall voltage profile of the transmission network, active and reactive flows on transmission lines and transformers, bus voltage magnitudes and phase angles, line currents, line losses and other related steady-state variables. The generation and transmission systems were modeled in detail till to substations’ busbars where equivalent loads represent the distribution system. The objectives of the load flow studies were: •

To detect present weaknesses of the operating conditions identifying any overloads and excesses of the thermal limits of components, large voltage deviations, high losses in the transmission facilities, etc.;

•

To constitute a set of base cases for adequacy analysis to be compared with those in which the possible transmission improvements are to be simulated, in order to evaluate the benefits of interconnections upgrading towards the efficiency.

•

To constitute a set of base cases for calculation of transfer capability of the forecasted operation of the interconnected transmission network under a specific set of assumed operating conditions that include introduction of new generation capacities, new element of the network and development of electricity demand.

•

To constitute a set of base cases for transient stability analysis in order to assess the impact of introduction of new power plant to the dynamic behaviors of the regional system and to detect any constrain to power exports from point of view of fulfillment of technical criteria of dynamic stability.

The analysis of the load flows has considered three variants of connection to the grid and three options of unit size of the new TPP Kosovo C. The target years of the load flow studies are 2012, 2014, 2018 and the horizon year 2020 according to the expected entrance in operation of individual generation units. For options 1 and 2 of new plant it is assumed the following time schedule of construction of the new plant: • • • •

first 500 MW (600MW) unit in operation in 2012 second unit in operation in 2014 third unit in operation in 2016 fourth unit in operation in 2018

For the option 3 of new plant, the first 500MW unit is considered in operation in 2012, the second 750MW unit in 2016 and the last 750 MW unit in 2018. European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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Analysis of steady-state conditions of the year 2012

The year 2012 was assumed as the year when the first unit of new TPP Kosovo C will be put into operation. The load flow calculation was carried out based on the projected peak and light load conditions and network configuration in 2012. System configuration

The corresponding configuration of 400 kV, 220 kV, and 150/110 kV of each national transmission system has been considered. Load flow analyses were performed for the three Variants of the connection of TPP Kosovo C in transmission network. In particular, based on information for the development of SEE transmission network, the following new 400 kV interconnection lines, that have a major impact on power transits, are assumed in operation in 2012: •

New 400 kV line Kashar (AL) – Podgorica (MN);

•

New 400 kV line Stip (MK) – Chervena Mogila (BG);

•

New 400 kV line Florina (GR) – Bitola (MK);

Based on the findings of other studies and the Task 1 of this project, the Consultant has found that the role of a new 400 kV line Kosovo C (KS) – Kashar (AL) is crucial for the purpose of this project having in mind that Albania is one of the main candidate as off-taker, so it is assumed that construction of this line can be anticipated and the line should be in operation at the same time with the first unit of Kosovo C. Nevertheless there are analyzed two variant: •

New 400 kV line Kosovo C (KS) – Kashar (AL) is in operation in 2012;

•

New 400 kV line Kosovo C (KS) – Kashar (AL) is not in service in 2012;

The KOSTT has provided the data of the planned configuration of Kosovo transmission network (220kV and 110 kV). Compare to the actual configuration many new substation and network reinforcements are introduced into transmission and subtransmission network. In the following, the most important new elements in service in 2012 are listed: • • •

New 400/110 kV substation of Peja 3 with transformer capacity 300 MVA; New 220/110 kV substation of Ferizaj 2 with transformer capacity 150 MVA; New 110 kV substations of Pristina 6, Shtime, Malisheva, Rahovec and Mitrovica; • New 110 kV line Pristina 4 – Pristina 6; • New 110 kV line Lipian – Shtime; • New 110 kV line Peja 3 – Klina; • New 110 kV line Peja 3 – Istok, • New 110 kV line Suhareka- Malisheva; • New 110 kV line Malisheva – Rahovec; • New 110 kV line Rahovec – Gjakove. The introduction of two substations (Peja 3 and Ferizaj 2) together with reinforcement of the north-west part of 110 kV network, has resolved many problems related to reliability of the local network and the voltage profiles in that area.

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1.4.2.1

Network configuration with the 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Kashar (AL)

1.4.2.1.1

Peak load conditions Generation Dispatch

Power dispatch generation units in Kosovo (gross generation) for the peak load conditions is given in Table 1-9. Table 1-9 Winter 2012 Generation dispatch in Kosovo Pg MW

Power Plant Ujmani Kosovo A1 Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Total

Qg Mvar

32 36.5 126 166 166 300 300 530 1,657

16 24 91 94 94 76 76 104 574

Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is reported in Table 1-10. Table 1-10 Year 2012 Power Exchanges Scenario in winter peak in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 300

300

BiH MW

Bulgaria Romania MW

Serbia

UCTE

100

300 150 50

100 200

300 800

200 100 50 200 400 900

150

1,000 1,000

Total MW 400 0 500 250 200 200 1,800 3,350

Load flow in normal conditions

The network was analyzed from point of view of line and equipment loadings, accepted voltage levels, presence of eventually bottlenecks, excessive and unjustified losses, eventually violation of generation capability limits (especially reactive), etc. The complete analysis of N situations has been carried out for peak load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in

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Table 1-11 and

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Table 1-12 for Kosovo power system.

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Table 1-11 Year 2012 Peak load condition: Energy Exchanges Active Power

Reactive Â˝ Transit Losses Power Active Reactive (MW) (MVAr) (MVAr) (MVAr) 1,657 595

Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

138.0 -69.6 100.5 120.2 289.1

-40.6 61.6 14.5 -52.1 -16.6

1.1 0.6 0.1 0.2 2.0

-34.3 -21.2 -16.4 -14.6 -86.3

Table 1-12 Year 2012 Peak load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 Variant 2 P Q P Q (MW) (MVAr) (MW) (MVAr) 3.0 -68.4 3.0 -64.0 2.8 -7.9 2.9 -11.6 16.1 17.7 16.1 17.8 21.9 -58.6 22.0 -57.8 9.9 266.7 9.9 266.4 31.8

208.1

31.9

208.6

Variant 3 P Q (MW) (MVAr) 2.9 -67.8 2.9 -9.0 16.0 17.2 21.8 -59.6 9.9 264.7 31.6

205.2

Annex 3 shows the results of load flow calculations. The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.1 to A3.3 for each variant of connection of new plant, and in Figure A3.4 in Annex 3.

Figure 1-5 shows the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country. 1.4.2.1.2

Light load conditions

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Generation Dispatch

Table 1-13 reports the generation dispatch (gross generation) for the Kosovo system for the light load conditions. Table 1-13 Summer 2013 Generation dispatch in Kosovo Pg MW

Power Plant Ujmani Kosovo B1 Kosovo B2 Kosovo C1 Total

Qg Mvar

8 260 260 520 1,048

7 -8 -8 -29 -38

Figure 1-5 Year 2012 Power transits in SEE network during peak load condition.

Power Exchange Scenarios

The scenario of power exchanges in summer light load condition between SEE countries is reported in Table 1-14. Table 1-14 Year 2013 Power Exchanges Scenario in summer minimum in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 200

BiH MW

300

200 100

400

100 150 550

200 150 750

100 100 600

100

Load flow in normal conditions

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Bulgaria Romania

Serbia

UCTE

250 250

Total MW 200 0 900 100 150 300 650 2,300

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The load flow calculation was carried out based on the projected minimum demand and network configuration in 2012. The complete analysis of N situations has been carried out for light load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in . and Table 1-16 for Kosovo power system.

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Table 1-15 Year 2013 Light load condition: Energy Exchanges Active Power

Power Supply Generation Kosovo

Reactive Power

(MW) 1,048

(MVAr) -38

228.6 -41.4 273.7 140.2 601.1

-35.7 -34.6 23.8 -40.1 -86.6

Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Â˝ Transit Losses Active Reactive (MVAr) (MVAr)

0.6 0.1 0.2 0.3 1.2

-41.7 -25.0 -15.4 -15.6 -97.7

Table 1-16 Year 2013 Light load condition: Power Losses Variant 1 Power Losses

Variant 2

Variant 3

(MW)

(MVAr)

(MW)

(MVAr)

(MW)

(MVAr)

Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses

1.6 0.8 1.4 3.7 4.8

-84.8 -23.2 -29.8 -137.7 108.6

1.6 0.8 1.7 4.0 4.9

-79.1 -25.0 -30.8 -134.9 110.7

1.6 0.9 1.6 4.1 4.9

-82.9 -25.9 -30.9 -139.7 109.7

Total Losses of Transmission Network

8.5

-29.2

8.9

-24.2

8.9

-29.9

In Figure 1-6 are shown the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

Figure 1-6 Year 2013 Power transits in SEE network during light load condition.

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1.4.2.2

Year 2012 Network configuration without the 400 kV line Kosovo C (KS) Kashar(AL)

1.4.2.2.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.5 and in Figure A3.6 in Annex 3. A summary of load flow calculation and comparison with the results of case where the 400 kV line is in operation, is reported in the following. The power exchanges with neighboring countries are reported in Table 1-17 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-7. It can be observed that the power transited by the line is now equally shared by the 400 kV lines of Montenegro and Macedonia. Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in Table 1-18 and Table 1-19. Comparing the results of two cases can be seen that the presence of the line has decreased the power losses for Kosovo and for all the region respectively by 1.6 MW and 8.4 MW. Table 1-17 Year 2012 Peak load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

With 400kV KS-AL P Q (MW) (MVAr) 137.0 -38.4 -71.9 48.3 101.7 6.2 122.5 -50.0 289.3 -33.9

Without 400kV KS-AL P Q (MW) (MVAr) -45.5 -64.6 -20.8 32.8 169.4 -8.6 185.1 -49.7 288.2 -90.1

Table 1-18 Year 2012 Peak load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

With 400kV KS-AL P Q (MW) (MVAr) 2.9 -67.8 2.9 -9.0 16.0 17.2 21.8 -59.6 9.9 64.7 31.6

205.2

Without 400kV KS-AL P Q (MW) (MVAr) 2.9 -23.8 3.7 -3.4 16.6 19.3 23.3 -7.9 10.0 271.3 33.3

263.3

Table 1-19 Year 2012 Peak load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

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With 400kV KS-AL P Q (MW) (MVAr) 4 -1,100 576 -14,116 243 -1,672 430 -2,508 11 41 368 -1,238 0 1 1,632 -20,592 243 12,323 1,874 -8,269

Without 400kV KS-AL P Q (MW) (MVAr) 4 -1,099 579 -13,944 246 -1,650 430 -2,506 11 41 370 -1,232 0 1 1,640 -20,389 243 12,341 1,883 -8,048

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Figure 1-7 Year 2012 Case with no 400 kV line KS-AL Power flows in SEE network during peak load condition.

1.4.2.2.2

Light load conditions Load flow in normal conditions

A summary of load flow calculation is reported in the following, comparing the results with the case where the 400 kV line is in operation. The power exchanges with neighboring countries are reported in Table 1-20 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-8. Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in

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Table 1-21 and Table 1-22. The presence of the line has decreased the power losses for Kosovo and for the entire region respectively by 0.9 MW and 3.5 MW. Table 1-20 Year 2013 Light load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

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With 400kV KS-AL P Q (MW) (MVAr) 228.6 -35.7 -41.4 -34.6 273.7 23.8 140.2 -40.1 601.1 -86.6

Without 400kV KS-AL P Q (MW) (MVAr) 73.2 -11.8 8.7 -31.6 325.5 18.2 192.8 -51.3 600.2 -76.5

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Table 1-21 Year 2013 Light load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

With 400kV KS-AL P Q (MW) (MVAr) 1.6 -84.8 0.8 -23.2 1.4 -29.8 3.7 -137.7 4.8 108.6 8.5 -29.2

Without 400kV KS-AL P Q (MW) (MVAr) 1.4 -36.8 1.3 -22.7 1.8 -29.9 4.5 -89.3 4.9 112.1 9.4 22.8

Table 1-22 Year 2013 Light load condition: Total Power Losses With 400kV KS-AL Total Power Losses

Without 400kV KS-AL

(MW)

(MVAr)

(MW)

(MVAr)

Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines

2 303 88 267 12 92 0

-1,078 -15,324 -2,664 -3,100 41 -2,210 0

2 304 90 267 12 92 0

-1,078 -15,155 -2,648 -3,097 41 -2,204 0

Total transmission line Losses

763

-24,335

767

-24,141

Total Transformer Losses

141

6,353

141

6,355

Total Transmission Network Losses

904

-17,982

908

-17,786

Figure 1-8 Year 2013 Case with no 400 kV line KS-AL Power flows in SEE network during light load condition.

1.4.2.3

Year 2012 Conclusion As a starting year, the network situation of 2012-2013 was analyzed from point of view of line and equipment loadings, accepted voltage levels, presence of eventually bottlenecks, excessive and unjustified losses, eventually violation of generation capability limits (especially reactive), etc. performing load flows calculation for two

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typical load conditions. No particular problems worth to be mentioned ware found during normal operating conditions. The introduction of new 400kV Kosovo C â&#x20AC;&#x201C; Kashar (AL) has improved the voltage profile in Albania and has decreased the power losses not only in Kosovo but also in the region. The connection of new TPP Kosovo C with local 220 kV network has improved the distribution of power flows in transmission network. The loadings of 400/220 kV autotransformers of Kosovo C are 25% during peak hours so in 2012 it can be installed only one of them. Due to the introduction of 400/110 kV Peja 3 substation some neigboring 110 kV lines in the area are fully loaded during peak load conditions. It is recommended to reinforce the connection of 110 kV between Peja 1 and Peja 2 substations.

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Analysis of steady-state conditions of the year 2014

The year 2014 was assumed as the year when the second unit of new TPP Kosovo C (Option 1) will be put into operation. Peak and light load conditions were analyzed. System configuration

The configuration of the transmission system is the same as in 2012 and the 400 kV, 220 kV, and 150/110 kV networks of each national transmission system has been considered. Load flow analyses were performed for the three Variants of the connection of TPP Kosovo C in transmission network. In order to compare the role of the new 400 kV line Kosovo C (KS) - Kashar(AL), two variant are analyzed: • •

New 400 kV line Kosovo C (KS) – Kashar (AL) is in operation in 2014; New 400 kV line Kosovo C (KS) – Kashar (AL) is not in service in 2014;

The KOSTT has provided the data of the planned configuration of Kosovo transmission network (220kV and 110 kV). In order to resolve some loading problems of the 110 kV network, the Consultant has proposed some reinforcement. Majority of proposed reinforcement are not related to the construction of new TPP Kosovo C, but became necessary due to growth of the load in some areas and increase of power injection from 400/110 kV Peja 3 substation. Of course further investigation should be performed during activities of transmission network planning in order to obtaine optimal solution for development of national transmission network. In the following are given the reinforcement of 110 kV network: •

Reinforcement of 110 kV connection between substations of Prizren 1 and Prizren 2;

•

Reinforcement of 110 kV connection between substations of Kosovo A and Vushtria;

•

Reinforcement of 110 kV connection between substations of Peja 3 and Peja 1 and Peja 2;

1.4.3.1

Year 2014 Network configuration with the 400 kV line Kosovo C (KS) Kashar(AL)

1.4.3.1.1

Peak load conditions Generation Dispatch

Power dispatch of generation units in Kosovo (gross generation) for the peak load conditions is given in

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Table 1-23.

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Table 1-23 Winter 2014 Generation dispatch in Kosovo Pg MW

Power Plant Ujmani Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Total

Qg Mvar

30 126 167 167 300 300 530 520 2,140

16 59 61 61 120 120 165 164 766

Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is reported in Table 1-24. Table 1-24 Year 2014 Power Exchanges Scenario in winter peak in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 500

BiH

Bulgaria Romania

150

450 150

Serbia

UCTE

200 50

0 650

100 700

100 300

250 300

750 750

Total MW 500 0 600 350 50 0 1,200 2,700

Load flow in normal conditions

The complete analysis of N situations has been carried out for peak load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-25 and

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Table 1-26 for Kosovo power system. The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.7 and in Figure A3.8 in Annex 3. A summary is given in Figure 1-9 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country. Table 1-25 Year 2014 Peak load condition: Energy Exchanges Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

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Active Power (MW) 2,140 239.8 -17.6 337.8 100.3 660.3

Reactive Power (MVAr) 766 -26.5 49.8 10.0 -55.0 -21.7

Â˝ Transit Losses Active Reactive (MVAr) (MVAr) 1.4 0.5 0.5 0.2 2.5

-28.6 -21.8 -12.0 -14.5 -76.8

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Table 1-26 Year 2014 Peak load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 Variant 2 Variant 3 P Q P Q P Q (MW) (MVAr) (MW) (MVAr) (MW) (MVAr) 3.5 -60.2 3.5 -55.9 3.5 -59.5 4.6 2.6 4.5 2.5 4.7 2.2 18.9 26.0 18.9 26.0 18.9 26.0 27.0 -31.7 27.0 -27.4 27.1 -31.4 12.3 362.2 12.3 361.6 12.3 361.6 39.3

330.5

39.3

334.2

39.4

330.2

Figure 1-9 Year 2014 Power transits in SEE network during peak load condition.

1.4.3.1.2

Light load conditions Generation Dispatch

Table 1-27 reports the generation dispatch (gross generation) for the Kosovo system for the light load conditions. Table 1-27 Summer 2015 Generation dispatch in Kosovo Power Plant Ujmani Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Total

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Pg MW 8 245 245 500 500 1,498

Qg Mvar 7 39 39 53 53 191

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Power Exchange Scenarios

The scenario of power exchanges in summer light load condition between SEE countries is reported in Table 1-28. Table 1-28 Year 2015 Power Exchanges Scenario in summer minimum in SEE Kosovo

Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

MW 300 400 50 50

BiH

Bulgaria Romania

UCTE

Total

200 100 100 150

150 950

Serbia

100

450

150 300 450

250 250

MW 300 0 600 150 150 300 700 2,200

Load flow in normal conditions

The load flow calculation was carried out based on the projected minimum demand and network configuration in 2014. The complete analysis of N situations has been carried out and no line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-29 and Table 1-30 for Kosovo power system. Table 1-29 Year 2015 Light load condition: Energy Exchanges Active Power

Power Supply

(MW) 1,498 316.2 81.1 338.8 206.3 942.4

Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Reactive Power (MVAr) 75 -30.2 -61.3 24.6 -42.2 -109.1

Â˝ Transit Losses Active Reactive (MVAr) (MVAr) 1.1 0.2 0.4 0.6 2.3

-35.6 -24.1 -13.4 -13.2 -86.3

Table 1-30 Year 2015 Light load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 2.8 -72.6 1.4 -18.3 2.3 -26.3 6.6 -117.3 6.5 168.0 13.0

50.7

Variant 2 P Q (MW) (MVAr) 2.8 -67.5 1.4 -20.1 2.6 -27.2 6.9 -114.9 6.6 171.8 13.4

56.9

Variant 3 P Q (MW) (MVAr) 2.7 -71.6 1.6 -20.4 2.5 -27.5 6.9 -119.5 6.6 170.1 13.4

50.6

A summary of results is given in Figure 1-10 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

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Figure 1-10 Year 2015 Power transits in SEE network during light load condition.

1.4.3.2

Year 2014 Network configuration without the 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Kashar (AL)

1.4.3.2.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.9 and A3.10 in Annex 3. A summary of load flow calculation is reported in the following comparing the results with the case where the 400 kV line is in operation. The power exchanges with neighboring countries are reported in Table 1-31. Table 1-31 Year 2014 Peak load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

With 400kV KS-AL P Q (MW) (MVAr) 238.2 -26.7 -17.5 51.2 335.6 9.2 104.0 -54.1 660.3 -20.4

Without 400kV KS-AL P Q (MW) (MVAr) 2.5 -52.5 46.5 33.7 417.3 -1.8 181.9 -49.4 648.2 -70.0

Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in

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Table 1-32and Table 1-33. The introduction of the line has decreased the power losses for Kosovo and for the entire region respectively by 2.4 MW and 16.3 MW.

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Table 1-32 Year 2014 Peak load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

With 400kV KS-AL P Q (MW) (MVAr) 3.5 -59.5 4.7 2.2 18.9 26.0 27.1 -31.4 12.3 361.6 39.4 330.2

Without 400kV KS-AL P Q (MW) (MVAr) 3.3 -19.8 6.1 11.5 19.9 29.3 29.4 21.0 12.4 370.0 41.8 391.0

Table 1-33 Year 2014 Peak load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

With 400kV KS-AL P Q (MW) (MVAr) 4 -1,098 602 -13,585 261 -1,550 465 -2,277 12 45 408 -1,103 0 1 1,751 -19,568 257 13,069 2,008 -6,499

Without 400kV KS-AL P Q (MW) (MVAr) 4 -1,098 607 -13,388 266 -1,512 465 -2,273 12 45 412 -1,091 0 1 1,767 -19,316 258 13,102 2,024 -6,214

The power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-11. It can be observed that the power transited by the line is now equally shared by the 400 kV lines of Montenegro and Macedonia.

Figure 1-11 Year 2014 Case with no 400 kV line KS-AL: Power flows in SEE network during peak load condition.

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Light load conditions Load flow in normal conditions

A summary of load flow calculation is reported in the following comparing the results with the case where the 400 kV line is in operation. The power exchanges with neighboring countries are reported in Table 1-34 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-10. Table 1-34 Year 2015 Light load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

With 400kV KS-AL P Q (MW) (MVAr) 316.2 -30.2 81.1 -61.3 338.8 24.6 206.3 -42.2 942.4 -109.1

Without 400kV KS-AL P Q (MW) (MVAr) 107.7 -11.7 147.7 -56 406.3 24.7 278.9 -49.1 940.6 -92.1

Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in Table 1-35and Table 1-36. The introduction of the line has decreased the power losses for Kosovo and for the entire region respectively by 1.8 MW and 5.7 MW. Table 1-35 Year 2015 Light load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

With 400kV KS-AL P Q (MW) (MVAr) 2.8 -72.6 1.4 -18.3 2.3 -26.3 6.6 -117.3 6.5 168.0 13.0

50.7

Without 400kV KS-AL P Q (MW) (MVAr) 2.7 -26.8 2.5 -14.7 3.0 -25.8 8.1 -67.2 6.6 175.8 14.8

108.5

Table 1-36 Year 2015 Light load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

1.4.3.3

With 400kV KS-AL P Q (MW) (MVAr) 2 -1,077 311 -15,049 90 -2,617 291 -2,902 11 39 98 -2,148 0 0 804 -23,753 147 6,736 950 -17,016

Without 400kV KS-AL P Q (MW) (MVAr) 2 -1,076 314 -14,861 93 -2,590 292 -2,895 11 39 99 -2,139 0 0 811 -23,523 147 6,745 958 -16,778

Year 2014 Conclusion The transmission network situation of 2014-2015 was analyzed from point of view of line and equipment loadings, accepted voltage levels, presence of eventually bottlenecks, excessive and unjustified losses, eventually violation of generation capability limits (especially reactive), etc. performing load flows calculation for two typical load conditions.

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Figure 1-12 Year 2015 Case with no 400 kV line KS-AL Power flows in SEE network during light load condition.

No particular problems regarding the bulk transmission system (400 kV and 220 kV) in the region ware found during normal operating conditions. Some low voltage levels have been detected in south and northeast parts of Albania namely during peak load. The problem is resolved on local basis, by coordination of reactive sources and by installation of adequate reactive compensation in Albania. It was observed that in these areas of Albania is missing not only an adequate voltage support, but also active generation and this problem can not be solved only with imports of energy from abroad. The introduction of new 400kV Kosovo C – Kashar (AL) has improved the voltage profile in Albania and has decreased the power losses not only in Kosovo but also in the region. The connection of new TPP Kosovo C with local 220 kV network has improved the distribution of power flows in transmission network. The loadings of 400/220 kV autotransformers of Kosovo C are 40% during peak hours. Due to the introduction of 400/110 kV Peja 3 substation some neigboring 110 kV lines in the area are fully loaded during peak load conditions. The increase of load on northen regions (Mitrovice, Vuçitern, etc) of Kosovo has caused a full loading of the 110 kV lines upplying this area during peak load conditions. It is recommended to reinforce 110 kV connection of between Peja 3 and Peja 1, Peja 2 substations. Also dedicated planning studies shoud be performed to reinforce 110 kV network supplying northen area of Kosovo.

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Analysis of steady-state conditions of the year 2016

The year 2016 was assumed as the year when the third unit 500 MW of new TPP Kosovo C (Option 1) will be put into operation. Peak and light load conditions were analyzed. Also the Option 3 with the configuration 500 MW + 2x750 MW of the new TPP Kosovo C is analyzed. System configuration

The configuration of the transmission system takes in consideration the situation in 2015 of 400 kV, 220 kV, and 150/110 kV networks of each national transmission system. Load flow analyses were performed for the three Variants of the connection of TPP Kosovo C in transmission network. According to result of the revised REBIS GIS study additional generation units are introduced to the model of the SEE system to match the increase of power demand in each country. The same configuration of the national transmission network is considered for 110 kV including the proposed reinforcements relevant to years 2014-2015. Further investigation should be performed during activities of transmission network planning in order to obtaine optimal solution for development of national transmission network up to 2020. In order mitigate some loading problems of the 110 kV network, the Consultant has proposed some additional reinforcement. Majority of proposed reinforcement are not related to the construction of new TPP Kosovo C, but became necessary due to growth of the load in some areas and increase of power injection from 220/110 kV Ferizaj substation. In the following are given the reinforcement of 220 and 110 kV network: •

Second transformer 150 MVA at 220/110 kV substation of Ferizaj 2;

•

Reinforcement of 110 kV connection between Ferizaj 2 – Ferizaj 1 and Shtimje substations

1.4.4.1

Year 2016 Option 1 of new TPP Kosovo C: third unit 500 MW

1.4.4.1.1

Peak load conditions Generation Dispatch

Power dispatch generation units in Kosovo (gross generation) for the peak load conditions is given in Table 1-37. Table 1-37 Winter 2016 Generation dispatch in Kosovo Power Plant Ujmani Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Kosovo C3 Total

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Pg MW 30 125 160 160 290 290 530 530 530 2,645

Qg Mvar 16 100 100 100 101 101 140 140 140 937

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Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is reported in Table 1-38. Table 1-38 Year 2016 Power Exchanges Scenario in winter peak in SEE Kosovo

Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

MW 550

BiH

Bulgaria Romania

300

Serbia

UCTE

450 150

150

100 700

150

350 400

Total

150 100 1,100

800 800

MW 550 0 750 350 150 0 1,350 3,150

Load flow in normal conditions

The load flow calculation was carried out based on the projected peak demand and network configuration in 2016. The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.11 and A3.12 in Annex 3. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-39 and Table 1-40 for Kosovo power system. Table 1-39 Year 2016 Peak load condition: Energy Exchanges Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Active Power (MW) 2,643 355.0 81.0 477.6 188.1 1,101.7

Reactive Power (MVAr) 937 -9.5 22.9 -10.5 -31.6 -28.7

Â˝ Transit Losses Active Reactive (MVAr) (MVAr) 2.5 0.6 0.9 0.5 4.5

-16.5 -20.6 -7.0 -12.0 -56.1

Table 1-40 Year 2016 Peak load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 6.4 -36.6 5.3 9.3 21.2 34.3 32.9 7.0 14.8 437.0 47.7 444.0

Variant 2 P Q (MW) (MVAr) 6.4 -32.1 5.3 9.3 21.2 34.5 33.0 11.7 14.8 437.9 47.8 449.6

Variant 3 P Q (MW) (MVAr) 6.3 -35.9 5.5 8.9 21.1 34.3 32.9 7.3 14.8 436.5 47.7 443.8

Annex 1 shows the results of load flow calculations. A summary is given in Figure 1-13 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

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Figure 1-13 Year 2016 Power transits in SEE network during peak load condition.

1.4.4.1.2

Light load conditions Generation Dispatch

Table 1-41 reports the generation dispatch (gross generation) for the Kosovo system for the light load conditions. Table 1-41 Summer 2017 Generation dispatch in Kosovo Pg MW

Power Plant Ujmani Kosovo B1 Kosovo C1 Kosovo C2 Kosovo C3 Total

Qg Mvar

8 224 500 500 500 1,732

8 27 36 36 36 142

Power Exchange Scenarios

The scenario of power exchanges in summer light load condition between SEE countries is reported in Table 1-42. Table 1-42 Year 2017 Power Exchanges Scenario in summer minimum in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 450

BiH

Bulgaria Romania

450 100 100

Serbia

UCTE

200 100 100

1,100

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400

400 400

250 250

Total MW 450 0 650 200 100 100 650 2,150

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Load flow in normal conditions

The load flow calculation was carried out based on the projected minimum demand and network configuration in 2016. The complete analysis of N situations has been carried out for peak load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-43 and Table 1-44 for Kosovo power system. Table 1-43 Year 2017 Light load condition: Energy Exchanges Active Power

Power Supply

(MW) 1,732 381.1 96.7 405.5 218.7 1,102.0

Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Reactive Power (MVAr) 143 -44.9 -58.5 14.6 -43.2 -132.0

Â˝ Transit Losses Active Reactive (MVAr) (MVAr) 1.6 0.3 0.6 0.6 3.0

-30.6 -23.6 -11.4 -12.5 -78.1

Table 1-44 Year 2017 Light load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 3.7 -63.7 2.0 -13.9 3.3 -22.9 9.0 -100.4 7.7 209.8 16.8

109.

Variant 2 P Q (MW) (MVAr) 3.8 -59.1 1.9 -14.8 3.4 -22.5 9.1 -96.4 7.7 211.6 16.8

115.2

Variant 3 P Q (MW) (MVAr) 3.7 -62.4 2.2 -14.5 3.3 -22.8 9.2 -99.7 7.7 209.4 16.9

109.7

A summary of results is given in Figure 1-14 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

Figure 1-14 Year 2017 Power transits in SEE network during light load condition.

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1.4.4.2

Year 2016 Option 3 of new TPP Kosovo C: second unit 750 MW

1.4.4.2.1

Peak load conditions Generation Dispatch

Table 1-45 reports the generation dispatch (gross generation) for the Kosovo system for the peak load conditions. Table 1-45 Winter 2016 Generation dispatch in Kosovo Power Plant

Pg MW

Ujmani Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Total

Qg Mvar

30 125 160 160 290 290 530 750 2,335

16 100 100 100 101 101 140 217 875

Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is reported in Table 1-46. Load flow in normal conditions

The load flow calculation was carried out based on the projected peak demand and network configuration in 2016. The complete analysis of N situations has been carried out for peak load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-47 for Kosovo power system. Table 1-46 Year 2016 Power Exchanges Scenario in winter peak in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 550

BiH MW

Bulgaria MW

250

Romania MW

450 150

Serbia MW

UCTE MW

50 150

800

100 700

150

350 400

900 1100

Total MW 550 0 750 350 150 0 1350 3150

Table 1-47 Year 2016 Peak load condition: Energy Exchanges Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

1.4.4.3

Active Power (MW) 2,333 299.4 -39.6 403.2 134.0 797.0

Reactive Power (MVAr) 894 -7.0 43.7 -12.7 -26.9 -2.9

Â˝ Transit Losses Active Reactive (MVAr) (MVAr) 2.1 0.5 0.7 0.3 3.5

-21.2 -21.3 -9.7 -13.8 -66.0

Year 2016 Conclusion The transmission network situation of 2016-2017 was analyzed from point of view of line and equipment loadings, accepted voltage levels, presence of eventually bottlenecks, excessive and unjustified losses, eventually violation of generation

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capability limits, etc. performing load flows calculation for two typical load conditions. The overload limits of lines and transformers, the capability chart for the generation units and the accepted voltage deviation at several nodes were carefully investigated in order to assess the feasibility of the operating conditions in normal operation. No particular problems regarding the bulk transmission system (400 kV and 220 kV) in the region ware found during normal operating conditions. The problems of low voltage levels in south and northeast parts of Albania, namely during peak load, still persists and was been solved by additional reactive compensation. A reinforcement of transformer capacity is necessary to cope with the increase of load in Ferizaj area, so the consultant has added the second 150 MVA, 220/110 kV unit. Also it is recommended to reinforce 110 kV connections of between Ferizaj 2 and Ferizaj 1, Shtime substations.

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Analysis of steady-state conditions of the year 2018

The year 2018 was assumed as the year when the fourth unit of new TPP Kosovo C (Option 1) will be put into operation. Peak and light load conditions were analyzed. System configuration

The configuration of the transmission system relevant to year 2018 and the 400 kV, 220 kV, and 150/110 kV networks of each national transmission system has been considered. Load flow analyses were performed for the three Variants of the connection of TPP Kosovo C in transmission network.According to result of the revised REBIS GIS study additional generation units are introduced to the model of the SEE system to match the increase of power demand in each country. Following the new generation units the opportunity of export from Kosovo are increased and in order to increase the transmission capacity of the network toward potential off-takers, some additional reinforcements of the 400kV network have been considered: • • • •

New 400 kV line Kosovo C (KS) – Skopje 4 (MK) is not in service in 2018; New 400 kV line Kosovo C (KS) – Skopje 4 (MK) in operation in 2018; New 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR) in operation in 2018 New 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR) is not in service in 2018.

The same configuration of the national transmission network, as in 2016 is considered for 110 kV including the proposed reinforcements relevant to years 2016-2017 mainly to Ferizaj area. Furthermore, in order to cope with load growth, we recommend to install the second transformer 300 MVA at 400/110 kV substation of Peja 3. 1.4.5.1

Network configuration without additional reinforcements

1.4.5.1.1

Year 2018 Option 1 of new TPP Kosovo C: fourth unit of 500 MW

1.4.5.1.1.1

Peak load conditions Generation Dispatch

Power dispatch generation units in Kosovo (gross generation) for the peak load conditions is given in Table 1-48. Table 1-48 Winter 2018 Generation dispatch in Kosovo Power Plant Ujmani Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Kosovo C3 Kosovo C4 Total

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Pg MW 28 115 144 144 290 290 530 530 530 530 3,131

Qg Mvar 16 71 73 73 126 126 173 173 173 173 1,178

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Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is reported in Table 1-49. Table 1-49 Year 2018 Power Exchanges Scenario in winter peak in SEE Kosovo

Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

MW 600

BiH

Bulgaria Romania

500

Serbia

UCTE

300 150

150

100

300 750

300 450

350 450

Total MW 600 0 800 400 200 0 1,600 3,600

200 200 1,500

450 450

Load flow in normal conditions

The load flow calculation was carried out based on the projected peak demand and network configuration in 2018. The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.13 and A3.14 in Annex 3. The complete analysis of N situations has been carried out for peak load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-50 and Table 1-51 for Kosovo power system. Table 1-50 Year 2018 Peak load condition: Energy Exchanges Active Power

Power Supply

(MW) 3,131 471.9 192.3 544.7 295.2 1,504.1

Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Reactive Power (MVAr) 1,189 -5.2 43.8 11.4 -34.8 15.2

Â˝ Transit Losses Active Reactive (MVAr) (MVAr) 3.5 1.2 1.2 1.3 7.1

-5.2 -17.3 -3.0 -6.5 -31.9

Table 1-51 Year 2018 Peak load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 10.1 -5.0 8.5 28.8 23.0 38.4 41.5 62.2 17.1 531.0 58.6

593.2

Variant 2 P Q (MW) (MVAr) 10.1 -1.8 7.6 22.4 23.9 40.8 41.6 61.5 17.0 529.8 58.6

591.2

Variant 3 P Q (MW) (MVAr) 10.0 -4.1 8.0 24.0 24.0 41.3 42.0 61.3 17.0 529.0 59.1

590.3

A summary of results of load flow calculations is given in Figure 1-15 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

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Figure 1-15 Year 2018 Power transits in SEE network during peak load condition.

1.4.5.1.1.2 Light load conditions Generation Dispatch

Table 1-52 reports the generation dispatch (gross generation) for the Kosovo system for the light load conditions. Table 1-52 Summer 2019 Generation dispatch in Kosovo Pg MW

Power Plant Ujmani Kosovo B1 Kosovo C1 Kosovo C2 Kosovo C3 Kosovo C4 Total

Qg Mvar

8 232 475 475 475 475 2,140

8 59 78 78 78 78 381

Power Exchange Scenarios

The scenario of power exchanges in summer light load condition between SEE countries is reported in Table 1-53. Table 1-53 Year 2019 Power Exchanges Scenario in summer minimum in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 500

BiH

Bulgaria Romania

500 200 100

Serbia

UCTE

200 100 100

100 1,400

Load flow in normal conditions

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400

300 300

250 250

Total MW 500 0 700 300 100 100 650 2,350

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The load flow calculation was carried out based on the projected minimum demand and network configuration in 2018. Some main results are presented in Table 1-54 and Table 1-55for Kosovo power system. Table 1-54 Year 2019 Light load condition: Energy Exchanges Active Power

Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Reactive Power

(MW) 2,140

(MVAr) 362

447.7 179.9 501.2 274.1 1,402.9

-10.1 -12.9 5.7 -39.5 -56.8

Â˝ Transit Losses Active Reactive (MVAr) (MVAr)

2.2 0.5 0.9 1.0 4.6

-23.0 -21.5 -7.9 -9.4 -61.9

Table 1-55 Year 2019 Light load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 5.5 -46.5 3.1 -7.7 4.5 -19.2 13.1 -73.4 9.3 267.2 22.4

193.8

Variant 2 P Q (MW) (MVAr) 5.5 -43.2 2.8 -9.9 4.9 -19.0 13.1 -72.0 9.3 265.0 22.5

Variant 3 P Q (MW) (MVAr) 5.6 -46.3 3.3 -8.8 4.7 -19.5 13.5 -74.6 9.3 261.5

193.0

22.8

187.0

A summary of results of load flow calculations is given in Figure 1-16 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

Figure 1-16 Year 2019 Power transits in SEE network during light load condition.

1.4.5.1.2

Year 2018 Option 3 of new TPP Kosovo C: third unit 750 MW

1.4.5.1.2.1

Peak load conditions

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Generation Dispatch

Power dispatch generation units in Kosovo (gross generation) for the peak load conditions is given in Table 1-56. Table 1-56 Winter 2018 Generation dispatch in Kosovo Power Plant Ujmani Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Kosovo C3 Total

Pg MW 28 115 144 144 290 290 530 810 810 3,161

Qg Mvar 16 75 77 77 134 134 186 261 261 1,221

Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is the same as in previous paragraph. Load flow in normal conditions

The load flow calculation was carried out based on the projected peak demand and network configuration in 2018. Some main results are presented in Table 1-57 for Kosovo power system. Table 1-57 Year 2018 Peak load condition: Energy Exchanges Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Active Power (MW) 3,161 465.0 189.4 544.9 304.3 797.0

Reactive Power (MVAr) 1,224 -12.0 31.5 1.7 -36.1 -2.9

½ Transit Losses Active Reactive (MVAr) (MVAr) 3.5 1.0 1.2 1.3 3.5

-4.8 -17.7 -3.4 -5.8 -66.0

1.4.5.2

Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK)

1.4.5.2.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.15 and A3.16 in Annex 3. A summary of load flow calculation is reported in the following comparing the results with the case where the 400 kV line is in operation. The power exchanges with neighboring countries are reported in Table 1-58 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-17. Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in Table 1-59 and Table 1-60. The introduction of the line has decreased the power losses for Kosovo and for the entire region respectively by 1.6 MW and 3.8 MW.

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Table 1-58 Year 2018 Peak load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Without 400kV KS-MK P Q (MW) (MVAr) 465.5 -8.7 189.2 39.2 544.4 10.5 304.7 -33.4 1,503.8 7.6

With 400kV KS-MK P Q (MW) (MVAr) 445.3 -4.1 155.2 50.8 613.2 -21.2 292.5 -31.4 1,506.2 -5.9

Table 1-59 Year 2018 Peak load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Without 400kV KS-MK P Q (MW) (MVAr) 10.0 -4.1 8.0 24.0 24.0 41.3 42.0 61.3 17.0 529.0 59.1 590.3

With 400kV KS-MK P Q (MW) (MVAr) 9.2 -11.2 7.7 21.6 23.7 40.5 40.6 50.8 16.9 520.6 57.5 571.4

Table 1-60 Year 2018 Peak load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

Without 400kV KS-MK P Q (MW) (MVAr) 2 -1,122 714 -12,175 338 -1,014 528 -1,941 21 78 531 -651 0 1 2,133 -16,824 302 15,518 2,435 -1,306

With 400kV KS-MK P Q (MW) (MVAr) 2 -1,122 712 -12,251 337 -1,019 527 -1,942 21 78 530 -653 0 1 2,130 -16,908 301 15,505 2,431 -1,403

Figure 1-17 Year 2018 Case with a new 400 kV line KS-MK: Power flows in SEE network during peak load condition.

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1.4.5.3

Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) and with a new 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR)

1.4.5.3.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.17 and A3.18 in Annex 3. A summary of load flow calculation is reported in the following comparing the results with the case where the 400 kV line is in operation. The power exchanges with neighboring countries are reported in Table 1-61 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in

Figure 1-18. It can be observed that for analyzed exchange and generation dispatch scenarios, the power transited by the line Leskovac (SR) – Skopje 4 (MK) is small. Transmission power losses of Kosovo are reported in Table 1-62 and are compared with previous power losses without reinforcement, with a new line Kosovo – Macedonia and with both new lines. Transmission power losses of the modeled SEE system are reported in Table 1-63. The introduction of new lines has decreased the power losses for Kosovo and for the entire region respectively by 1.9 MW and 5.56 MW. Table 1-61 Year 2018 Peak load condition : Energy Exchanges Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Active Power (MW) 3,131 445.5 151.6

Reactive Power (MVAr) 1,095 -2.7 32.6

1/2 Transit Losses Active Reactive (MVAr) (MVAr) 3.2 0.9

-8.0 -19.0

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616.8 292.5 1,506.4

-28.5 -30.8 -29.4

0.9 1.2 6.3

-21.4 -6.8 -55.2

Table 1-62 Year 2018 Peak load condition: Kosovo Power Losses Without 400kV KS-MK Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

With 400kV KS-MK & SR-MK Q P Q (MVAr) (MW) (MVAr) -11.2 9.2 -11.6 21.6 7.6 21.3 40.5 23.5 39.8 50.8 40.4 49.5 520.6 16.8 517.8

With 400kV KS-MK

P (MW) 10.0 8.0 24.0 42.0 17.0

Q (MVAr) -4.1 24.0 41.3 61.3 529.0

P (MW) 9.2 7.7 23.7 40.6 16.9

59.1

590.3

57.5

571.4

57.2

567.4

Table 1-63 Year 2018 Peak load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

Without 400kV KS-MK P Q (MW) (MVAr) 2 -1,122 714 -12,175 338 -1,014 528 -1,941 21 78 531 -651 2,133 -16,824 302 15,518 2,435 -1,306

With 400kV KS-MK With 400kV KS-MK & SR-MK P Q P Q (MW) (MVAr) (MW) (MVAr) 2 -1,122 2 -1,122 712 -12,251 712 -12,347 337 -1,019 336 -1,022 527 -1,942 527 -1,943 21 78 21 78 530 -653 529 -657 2,130 -16,908 2,128 -17,013 301 15,505 301 15,494 2,431 -1,403 2,429 -1,518

Figure 1-18 Year 2018 Case with new 400 kV lines KS-MK and MK-SR: Power flows in SEE network during peak load condition.

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Year 2018 Conclusion

The transmission network situation of 2018-2019 was analyzed from point of view of line and equipment loadings, accepted voltage levels, presence of eventually bottlenecks, excessive and unjustified losses, eventually violation of generation capability limits etc. performing load flows calculation for two typical load conditions. No particular problems regarding the bulk transmission system (400 kV and 220 kV) in the region ware found during normal operating conditions and for the power exports from Kosovo to selected importing countries. The introduction of new 400kV Kosovo C – Skopje 4 (MK) has moderately improved the voltage profile has decreased the power losses not only in Kosovo but also in the region. For analyzed exchange and generation dispatch scenarios, the introduction of new 400kV Nish-Leskovac (SR) – Skopje 4 (MK) has minor impact on active transits, a fairly impact on improvement of voltage profile and has decreased the power losses mainly in the regional transmission network. A reinforcement of transformer capacity is necessary to cope with the increase of load in northeast area, so the consultant has added the second 300 MVA, 400/110 kV unit at Peja 3 substation.

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Analysis of steady-state conditions of the year 2020

Peak and light load conditions were analyzed for horizon year 2020. The objective is to investigate the response of the transmission system when the new TPP is fully operative and the export from Kosovo occurs in conditions when the margins of transmission capacities of the interconnections are reduced due to the increase of power exchanges. System configuration

The configuration of the transmission system was assumed similar to the configuration of year 2018 and the 400 kV, 220 kV, and 150/110 kV networks of each national transmission system has been considered. Load flow analyses were performed for the three Variants of the connection of TPP Kosovo C in transmission network. According to result of the revised REBIS GIS study additional generation units are introduced to the model of the SEE system to match the increase of power demand in each country. As in 2018 some additional reinforcements of the 400kV network have been considered in order to increase the transmission capacity of the network toward potential off-takers: • • • •

New 400 kV line Kosovo C (KS) – Skopje 4 (MK) in operation in 2020; New 400 kV line Kosovo C (KS) – Skopje 4 (MK) not in service in 2020; New 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR) in operation in 2020 New 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR) not in service in 2020

1.4.6.1

Network configuration without additional reinforcements

1.4.6.1.1

Peak load conditions Generation Dispatch

Table 1-64 reports the generation dispatch (gross generation) for the Kosovo system for the peak load conditions. Table 1-64 Winter 2020 Generation dispatch in Kosovo Power Plant Ujmani Kosovo A3 Kosovo A4 Kosovo A5 Kosovo B1 Kosovo B2 Kosovo C1 Kosovo C2 Kosovo C3 Kosovo C4 Total

Pg MW 28 125 162 162 290 290 530 530 530 530 3,177

Qg Mvar 16 77 79 79 132 132 183 183 183 183 1,248

Power Exchange Scenarios

The scenario of power exchanges in winter peak condition between SEE countries is reported in Table 1-65. European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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Table 1-65 Year 2020 Power Exchanges Scenario in winter peak in SEE Import\Export

Kosovo

Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

MW 600

BiH

Bulgaria Romania

500

Serbia

UCTE

300 150

150

100

300 750

300 450

350 450

200 200 1,500

450 450

Total MW 600 0 800 400 200 0 1,600 3,600

Load flow in normal conditions

The load flow calculation was carried out based on the projected peak demand and network configuration in 2020. The complete analysis of N situations has been carried out for peak load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-66 and Table 1-67 for Kosovo power system. Table 1-66 Year 2020 Peak load condition: Energy Exchanges Active Power

Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Reactive Power

(MW) 3,177

(MVAr) 1,294

469.9 147.1 600.2 287.4 1,504.6

0.9 46.6 67.3 -21.1 93.7

Â˝ Transit Losses Active Reactive (MVAr) (MVAr)

3.5 1.0 1.5 1.2 7.1

-5.1 -18.8 -0.8 -7.3 -32.0

Table 1-67 Year 2020 Peak load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 10.9 1.5 8.4 27.7 26.1 47.3 45.4 76.5 17.9 599.3 63.3

675.8

Variant 2 P Q (MW) (MVAr) 10.8 3.8 8.3 26.9 26.1 47.4 45.2 78.2 17.9 555.9 63.0

634.0

Variant 3 P Q (MW) (MVAr) 10.8 0.4 8.7 27.8 25.9 46.8 45.3 75.0 17.8 551.1 63.1

626.1

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.19 and A3.20 in Annex 3. A summary is given in Figure 1-19 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

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Figure 1-19 Year 2020 Power transits in SEE network during peak load condition.

1.4.6.1.2

Light load conditions Generation Dispatch

Table 1-68 reports the generation dispatch (gross generation) for the Kosovo system for the light load conditions. Table 1-68 Summer 2020 Generation dispatch in Kosovo Power Plant

Pg MW

Ujmani Kosovo B1 Kosovo C1 Kosovo C2 Kosovo C3 Kosovo C4 Total

Qg Mvar

8 260 505 505 505 505 2,288

8 67 89 89 89 89 431

Power Exchange Scenarios

The scenario of power exchanges in summer light load condition between SEE countries is reported in Table 1-69. Table 1-69 Year 2020 Power Exchanges Scenario in summer minimum in SEE Import\Export Albania Kosovo Greece (& Italy) Macedonia Montenegro Serbia Croatia & Slovenia Total

Kosovo MW 550

BiH

Bulgaria Romania

550 200 100

Serbia

UCTE

200 100 100

100 1,500

Load flow in normal conditions

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400

300 300

250 250

Total MW 550 0 750 300 100 100 650 2,450

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The complete analysis of N situations has been carried out for light load conditions. No line or transformer overloads have been detected and the voltage profile is within normal limit values. Some main results are presented in Table 1-70 and Table 1-71 for Kosovo power system. Table 1-70 Year 2020 Light load condition: Energy Exchanges Active Power

Power Supply Generation Kosovo Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Reactive Power

(MW) 2,288

(MVAr) 432

481.5 197.3 523.6 298.4 1,500.8

-18.0 -29.8 21.3 -33.7 -60.2

Â˝ Transit Losses Active Reactive (MVAr) (MVAr)

2.6 0.6 1.0 1.2 5.4

-18.1 -20.3 -6.5 -7.8 -52.8

Table 1-71 Year 2020 Light load condition: Power Losses Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Variant 1 P Q (MW) (MVAr) 6.6 -36.9 3.4 -4.3 5.4 -15.1 15.4 -56.3 10.2 298.8 25.5

242.6

Variant 2 P Q (MW) (MVAr) 6.7 -32.8 3.2 -5.6 5.6 -14.5 15.4 -52.8 10.2 301.9 25.6

249.1

Variant 3 P Q (MW) (MVAr) 6.7 -35.5 3.6 -4.2 5.4 -15.0 15.6 -54.7 10.1 298.1 25.8

243.3

A summary of results of load flow calculations is given in Figure 1-20 indicating the active power flows in the main interconnection lines of SEE transmission network and the total import / export of each country.

Figure 1-20 Year 2020 Power transits in SEE network during light load condition.

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1.4.6.2 Network configuration with a new 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Skopje 4 (MK) 1.4.6.2.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.21 and A3.22 in Annex 3. A summary of load flow calculation is reported in the following comparing the results with the case where the 400 kV line is in operation. The power exchanges with neighboring countries are reported in Table 1-72 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-21. It can be observed that the power transited by the line is now equally shared by the 400 kV lines of Montenegro and Macedonia. Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in Table 1-73 and Table 1-74. The introduction of the line has decreased the power losses for Kosovo and for the entire region respectively by 1.8 MW and 5.3 MW. Table 1-72 Year 2020 Peak load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Without 400kV KS-MK P Q (MW) (MVAr) 446.5 8.1 107.9 61.5 679.5 54.4 273.4 -17.6 1,507.3 106.4

With 400kV KS-MK P Q (MW) (MVAr) 3.2 -8.3 0.9 -19.6 1.1 -19.0 1.1 -8.2 6.2 -55.1

Table 1-73 Year 2020 Peak load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Without 400kV KS-MK P Q (MW) (MVAr) 9.7 -7.5 8.3 25.7 25.1 44.3 43.1 62.6 17.6 542.0 60.7

604.6

With 400kV KS-MK P Q (MW) (MVAr) 8.9 -15.5 7.9 23.0 24.8 43.2 41.5 50.7 17.4 533.8 58.9

584.5

Table 1-74 Year 2020 Peak load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

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Without 400kV KS-MK P Q (MW) (MVAr) 2 -1,121 747 -11,945 330 -1,076 570 -1,699 22 83 565 -565 0 1 2,237 -16,322 322 16,590 2,558 268

With 400kV KS-MK P Q (MW) (MVAr) 2 -1,121 744 -12,034 329 -1,082 569 -1,702 22 83 564 -569 0 1 2,232 -16,425 321 16,573 2,553 148

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Figure 1-21 Year 2020 Case with a new 400 kV line KS-MK: Power flows in SEE network during peak load condition.

1.4.6.3

Network configuration with a new 400 kV line Skopje 4 (MK)- Leskovac (SR) (Nis)(SR)

1.4.6.3.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network is illustrated in Figures A3.23 in Annex 3. The power exchanges with neighboring countries are reported in Table 1-75 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-22. It can be observed that the power transited by the line is now equally shared by the 400 kV lines of Montenegro and Macedonia. Table 1-75 Year 2020 Peak load condition : Energy Exchanges Without 400kV SR-MK Power Exchanges

Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

With 400kV SR-MK

(MW)

(MVAr)

(MW)

(MVAr)

470.9 175.6 567.6

4.0 31.5 59.2

3.5 1.1 1.3

-5.2 -18.4 -2.6

290.6

-19.6

1.2

-7.2

1,504.7

75.1

7.1

-33.3

Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in Table 1-76 and Table 1-77. The introduction of the line has decreased the power losses only on the region by 2.9 MW.

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Table 1-76 Year 2020 Peak load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Without 400kV SR-MK P Q (MW) (MVAr) 9.7 -7.5 8.3 25.7 25.1 44.3 43.1 62.6 17.6 542.0 60.7

604.6

With 400kV SR-MK P Q (MW) (MVAr) 9.9 -7.0 8.4 25.8 25.0 44.0 43.2 62.8 17.5 540.1 60.7

602.8

Table 1-77 Year 2020 Peak load condition: Total Power Losses Total Power Losses Total Losses of 750 kV lines Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 150 kV lines Total Losses of 120 kV lines Total Losses of 110 kV lines Total Losses of 35 kV lines Total transmission line Losses Total Transformer Losses Total Transmission Network Losses

Without 400kV SR-MK P Q (MW) (MVAr) 2 -1,121 747 -11,945 330 -1,076 570 -1,699 22 83 565 -565 0 1 2,237 -16,322 322 16,590 2,558 268

With 400kV SR-MK P Q (MW) (MVAr) 2 -1,121 746 -12,049 329 -1,080 569 -1,702 22 83 564 -571 0 1 2,234 -16,438 321 16,575 2,555 137

Figure 1-22 Year 2020 Case with a new 400 kV line SR-MK: Power flows in SEE network during peak load condition.

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1.4.6.4

Network configuration with a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) and 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR)

1.4.6.4.1

Peak load conditions Load flow in normal conditions

The voltage profile and power flows in Kosovo transmission network and in the main 400 kV lines of the regional transmission network are illustrated in Figures A3.24 and A3.25 in Annex 3. The power exchanges with neighboring countries are reported in Table 1-78 and the power flows in the main interconnection lines of SEE transmission network and the total import / export of each country are given in Figure 1-23. The impact of the additional 400 kV line Nis – Skopje is marginal from the point of view of supporting power delivery from Kosovo to Macedonia. Table 1-78 Year 2020 Peak load condition : Energy Exchanges Power Exchanges Exchange with Albania Exchange with Serbia Exchange with Macedonia Exchange with Montenegro Total Exchange

Without reinforcements P Q (MW) (MVAr) 470 1 147 47 600 67 287 -21 1,504.6 93.7

With 400kV KS-MK With 400kV KS-MK & SR-MK P Q P Q (MW) (MVAr) (MW) (MVAr) 447 8 448 11 108 62 117 46 680 54 668 48 273 -18 275 -16 1,507.3 106.4 1,507.5 89.1

Transmission power losses of Kosovo and overall transmission losses of the modeled SEE system are reported in Table 1-79 and Table 1-80. Comparing with the case of doubling link Kosovo – Macedonia, the introduction of the line has decreased the power losses on the region 2.45 MW. Table 1-79 Year 2020 Peak load condition: Kosovo Power Losses Kosovo Power Losses Total Losses of 400 kV lines Total Losses of 220 kV lines Total Losses of 110 kV lines Total transmission line Losses Total Transformer Losses Total Losses of Transmission Network

Without 400kV KS-MK With 400kV KS-MK With 400kV KS-MK & SR-MK P Q P Q P Q (MW) (MVAr) (MW) (MVAr) (MW) (MVAr) 9.7 -7.5 8.9 -15.5 8.9 -15.6 8.3 25.7 7.9 23.0 7.9 22.9 25.1 44.3 24.8 43.2 24.6 42.6 43.1 62.6 41.5 50.7 41.4 49.9 17.6 542.0 17.4 533.8 17.4 531.4 60.7

604.6

58.9

584.5

58.7

581.3

Table 1-80 Year 2020 Peak load condition: Total Power Losses Without 400kV KS-MK With 400kV KS-MK With 400kV KS-MK & SR-MK P Q P Q P Q (MW) (MVAr) (MW) (MVAr) (MW) (MVAr) Total Losses of 750 kV lines 2 -1,121 2 -1,121 2 -1,121 Total Losses of 400 kV lines 747 -11,945 744 -12,034 743 -12,136 Total Losses of 220 kV lines 330 -1,076 329 -1,082 329 -1,086 Total Losses of 150 kV lines 570 -1,699 569 -1,702 569 -1,705 Total Losses of 120 kV lines 22 83 22 83 22 83 Total Losses of 110 kV lines 565 -565 564 -569 563 -574 Total Losses of 35 kV lines 0 1 0 1 0 1 Total transmission line Losses 2,237 -16,322 2,232 -16,425 2,229 -16,538 Total Transformer Losses 322 16,590 321 16,573 321 16,560 Total Transmission Network Losses 2,558 268 2,553 148 2,550 22 Total Power Losses

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Figure 1-23 Year 2020 Case with new 400 kV lines KS-MK and SR-MK: Power flows in SEE network during peak load condition.

1.4.6.5

Year 2020 Conclusion

The transmission network, situation of 2020, was analyzed from piont of view of overload of lines and transformers, the capability chart for the generation units and the accepted voltage deviations No line or transformer overloads have been detected and the voltage profile is within normal limit values. The network reinforcement with a new 400kV Kosovo C – Skopje 4 (MK) or a new 400 kV line Nish (SR) – Skopje 4 (MK) has improved the voltage profile has decreased the power losses not only in Kosovo but also in the region. Analyzing the results of power flows considering the exchange and generation dispatch scenarios and comparing the two options, a new line Kosovo – Macedonia or a new line Serbia - Macedonia, the first option of network reinforcement is superior to the second one.

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1.5

Evaluation of adequacy of Regional transmission System and its Transfer Capability (Part of Subtasks 2.2 and 2.3 of ToR)

1.5.1

Introduction

In order to evaluate the adequacy of the local and regional transmission systems and their ability to transport the power of the proposed power plant to potential load centers, the Consultant has performed technical analysis aiming to quantify the transmission transfer capabilities between Kosovo power system and other utilities and off-takers identified in Task 1. In case of SEE interconnected system the presence of looped networks has introduced additional methodological and technical challenges for the calculation of transfer capabilities. The calculation of transfer capability is based on computer simulations of the forecasted operation of the interconnected transmission network under a specific set of assumed operating conditions. Each simulation represents a single “snapshot” of the operation of the interconnected network based on the projections of many factors such as introduction of new generation capacities, new element of the network and electricity demand. The conditions on the interconnected network continuously vary in real time. The further into the future those simulations are projected, the greater is the uncertainty in assumed conditions. However, transfer capabilities determined from simulation studies are viewed as reasonable indicators of network capability. In Europe ETSO defined the following definitions of transfer capabilities that are used between the European TSOs for operation: • • • • •

Total Transfer Capacity (TTC) Net Transfer Capacity (NTC) Available Transfer Capacity (ATC) Transmission Reliability Margin (TRM) Notified Transmission Flow (NTF).

Considering the contingencies and N-1 criterion, the transfer capability was defined as the amount of electric power, incremental above normal base power transfers, that can be transferred over the interconnected transmission system so that: 1. For a given network configuration with pre-contingency operating procedures in effect, all facility loadings are within normal ratings and all voltages are within normal limits. 2. The system remains stable following a disturbance that results in the loss of any single element (line, transformer, generating unit, etc.). 3. The post-contingency system (after operation of any automatic operating systems, but before any post-contingency operator-initiated adjustments) has all facility loadings within emergency ratings and all voltages within emergency limits. The NTC and ATC are important indicators for market participants, to anticipate and plan their cross-border transactions, and for the TSOs to manage these international exchanges of electricity. The definition of the main indicators related to transfer and exchange of energy on transmission network are: •

"Total Transfer Capability (TTC): If the maximum transfer capability of the precontingency system using normal limits is less than that of all first-contingency

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cases considering emergency limits, the TTC is the more restrictive amount. •

"Transmission Reliability Margin (TRM)": The TRM is the amount of transmission capability necessary to ensure that the interconnected network is secure under a reasonable range of uncertainties in system conditions. The TRM provides for load forecast and load distribution uncertainties and variations in generation dispatch, unintended deviations of physical flows during operation due to the physical functioning of load-frequency regulation and emergency exchanges between TSOs to cope with unexpected unbalanced situations in real time

•

"Net Transfer Capability” The NTC is equal to: NTC = TTC –TRM

•

"Already Allocated Capacity (AAC)". The AAC is the total amount of allocated transmission rights, whether they are capacity or exchange programmes depending on the allocation method.

•

"Available Transfer Capability (ATC)”: The ATC is equal to: ATC = NTC – AAC = TTC -TRM -AAC

The concept of Available Transfer Capability requires the determination of what is available from a particular condition. The values of TTC, TRM and NTC are directional. They are to be computed for a given interconnection in both directions of the electricity exchange. Nonsimultaneous incremental power transfer capability analysis involves determination of the power transfer capability between two given areas of a multiarea interconnection network, subject to a given set of base case conditions and a given set of contingencies with no other incremental transfers between other areas of the multiarea interconnected system allowed. The word incremental is used in the description of power transfer capability because the base case already models the interarea power transfers. Simultaneous incremental power transfer capability analysis involves determination of the power transfer capabilities between partners of a given set of two areas of a multiarea interconnection network, subject to a given set of base case conditions and a given set of contingencies,. The word incremental is used in the description of power transfer capabilities because the base case already models a set of interarea power transfers. The problem addressed in the study for evaluation of the nonsimultaneous power transfer capability is: How much incremental power transfer from Kosovo to a selected Utility (off-taker) or direction (North, South, East, etc.) will the transmission network of the interconnected system support, given a set of base case network conditions and a set of contingencies?. That is, what is the maximum amount of incremental power that Kosovo can export to selected Utility before any transmission lines of the interconnected network is loaded beyond their respective rating, given a set of base case conditions and given a set of contingencies, with no other interarea power transfer allowed other those modeled in the base case? In this study the simultaneous power transfer capability problem is: How much incremental power transfers from Kosovo to a selected Utilities (off-takers) or directions will the transmission network of the interconnected system support, given a set of base case network conditions and a set of contingencies?. That is, what are the European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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maximum amounts of incremental power that Kosovo can export, at the same time, to selected Utilities before any transmission lines of the interconnected network is loaded beyond their respective rating, given a set of base case conditions and given a set of contingencies? Both problems consider the actual, planned and reinforced transmission network. 1.5.2

Methodology of computing NTC

When electric power is transferred between two areas the entire network responds to the transaction. The power flow on each transmission path will change in proportion to the response of the path to the transfer. Similarly, the power flow on each path will change depending on network topology, generation dispatches, customer demand levels, other transactions through the area, and other transactions that the path responds to which may be scheduled between other areas. Taking in consideration these factors, a methodology for the computation of TTC (NTC) was defined and proceeds as follows: a.

Definition of base cases: It consists in forecasted condition and planned configuration of the network for each target year (2012,2014,2016,2018 and 2020)

Base Scheduled Transfers: The scheduled electric power transfers that should be modeled are those that are considered to be representative of the base system conditions being analyzed. For each target year we have assumed a set of transactions on SEE region.

Specification of contingencies: The list of contingencies has to be determined and a significant number of contingencies most restrictive to the transfer being studied has been identified and analyzed. The most important contingencies are those related with the outages of 400 kV interconnection lines.

Determination of network response: A computer simulation is done to determine how the specified generation changes impact transmission line flows. This is done for the base case with normal limits enforced, plus all specified contingencies with emergency limits enforced.

Finding of the maximum transfer: For this point, an LP optimization problem formulation using the Power Transfer Distribution Factors (PTDF) is applied to determine the maximum transfer (or transfers), that satisfies the thermal criteria. The PTDFs give a linear prediction of power flow distribution in response to change in generation changes. These linear factors are used to predict the maximum generation change which can be allowed.

Interpretation of results: The transfer capability of a couple A-B is the maximum amount of real power that can be transferred from area A to area B by all physical paths over all interconnected systems.

Determination of TRM: A reduction of TTC by a fixed percentage (10%) is used to specify the TRM. Alternatives to this a reduction of line ratings by some fixed percentage (10-5%) will normally lower the TTC taking into account the TRM

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on base case line flows and line rating. The effects of incremental changes of line Mvar loading as a function of power transfer are considered by assuming constant power factor. Incremental bus voltage changes are also a function of power transfer, but are not explicitly constrained to be within a certain ranges. 1.5.3

Definition of Transfer Capabilities of transmission network

In the following the calculation of transfer capability is based on forecasted conditions and should be used as a nominal value. The transfer capability applicable to different load and generation conditions may be different from the nominal value thus it should be regarded as being indicative of a range of capabilities, which could prevail in actual operation. On definition of transfer capability objectives, apart of the planned new lines in the region, are taken into consideration additional reinforcements of transmission network. In order to assure the outage most restrictive to the transfer, the following transmission contingencies have been selected for testing: • •

All 400 kV and 220 kV transmission lines of Kosovo; All 400 kV transmission lines of Albania, Montenegro, Serbia, Macedonia and Greece that have an impact on power flow transfer.

In case of nonsimultaneous maximum power transfers from Kosovo we have considered three directions of export or Utilities as potential off-takers that are: • • •

Export from Kosovo to Albania; Export from Kosovo to South direction (for example Greece, Italy and/or Macedonia); Export from Kosovo to North direction, denominated as export to UCTE (for example, Hungary, Croatia, Slovenia, and/or Bosnia Herzegovina, Serbia, etc.).

In case of simultaneous power transfers from Kosovo we have considered the same directions but the approach was different: • •

First, we have calculated the maximum power transfer from Kosovo to all directions (the summary export to Albania, Greece and UCTE) without any preference and; Secondly, we have calculated and presented graphically, the so called monograms, a family of boundary transfer limits where the maximum power transfer a selected direction (for example maximum export to Albania), is calculated considering as parameters the power transfers toward two remaining directions (for example export to UCTE, and Greece).

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Target year 2012

In order to assess the impact of power flow transit on interconnected lines, the Power Transfer Distribution Factors are calculated and reported in Tables A4.1 to A4.3 in Annex 4 for the network configuration without the 400kV line Kosovo - Albania, and in Tables A4.5 to A4.7 for the configuration with the new line. The Line Outage Distribution Factors are calculated and reported in Table A4.4 in Annex 4 and Table A4.8 respectively for two configurations of the transmission network. 1.5.3.1.1

Calculation of nonsimultaneous NTC of the transmission network a. Export to Albania Without new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: • • •

Net Transfer Capability: 675 MW; Critical Contingency: Line 400 kV Zemljak B (AL) – Kardia (GR); Limiting Conditions: overload of 220 kV Fierze (AL) – Prizren (KS).

With new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: • • •

Net Transfer Capability: 988 MW; Critical Contingency: Line 400 kV Zemljak B (AL) – Kardia (GR); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

b. Export to Greece Without new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: • • •

Net Transfer Capability: 707 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

Net Transfer Capability: 1124 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

c. Export to UCTE (North direction) Without new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: • •

Net Transfer Capability: 818 MW; Critical Contingency: Line 400 kV Zemljak B (AL) – Kardia (GR);

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Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

Net Transfer Capability: 1639 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

Calculation of simultaneous NTC of the transmission network a. Export to Albania, Greece and UCTE Without new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: •

• •

Maximum Power transfer from Kosovo: 1439 MW composed by: o Power transfer to Albania: 0 MW; o Power transfer to Greece: 257 MW; o Power transfer to UCTE: 1182 MW; First set of constraints: o Critical Contingency: Line 400 kV Zemljak B (AL) – Kardia (GR); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). Second set of constraints: o Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

With new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: •

•

Maximum Power transfer from Kosovo: 1927 MW composed by: o Power transfer to Albania: 189 MW; o Power transfer to Greece: 589 MW; o Power transfer to UCTE: 1140 MW; Set of constrains: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

It can be noted that the introduction of the 400 kV Kosovo-Albania has improved the maximum transfer capability of the network. The new line has increased the maximum power transfer with 512 MW or 34% more. b. Export to Albania as function of export to Greece and UCTE Without new 400 kV line Kosovo C (KS) – Kashar (AL) The results of computer calculation in for of monograms are given in Figure 1-24. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE.

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Figure 1-24 – Year 2012 Boundary Diagrams NTC of Kosovo no KS-AL

With new 400 kV line Kosovo C (KS) – Kashar (AL)

The results of computer calculation in form of monograms are given in Figure 1-25. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE.

Figure 1-25 – Year 2012 Boundary Diagrams of NTC of Kosovo with KS-AL

The maximum power transfer from Kosovo is the red point in figure. It can be noted that the introduction of the 400 kV Kosovo-Albania has improved the maximum transfer capability of the network. The new line has increased the maximum power transfer with 512 MW or 34% more.

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Target year 2014

In order to assess the impact of power flow transit on interconnected lines, the Power Transfer Distribution Factors are calculated and reported in Tables A4.9 to A4.11 in Annex 4 for the network configuration without the 400kV line Kosovo- Albania, and in Tables A4.13 to A4.15 for the configuration with the new line. The Line Outage Distribution Factors are calculated and reported in Table A4.12 in Annex 4 and Table A4.16 respectively for two configurations of the transmission network. 1.5.3.2.1

Net Transfer Capability: 653 MW; Critical Contingency: Line 400 kV Zemljak B (AL) – Kardia (GR); Limiting Conditions: overload of 220 kV Fierze (AL) – Prizren (KS).

Net Transfer Capability: 1097 MW; Critical Contingency: Line 400 kV Zemljak (AL) – Kardia (GR); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

Net Transfer Capability: 433 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

Net Transfer Capability: 811 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

Net Transfer Capability: 526 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS);

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Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

Net Transfer Capability: 1314 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

•

Maximum Power transfer from Kosovo: 1292 MW composed by: o Power transfer to Albania: 0 MW; o Power transfer to Greece: 0 MW; o Power transfer to UCTE: 1292 MW; Set of constraints: o Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

With new 400 kV line Kosovo C (KS) – Kashar (AL) Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: •

• •

Maximum Power transfer from Kosovo: 2028 MW composed by: o Power transfer to Albania: 30 MW; o Power transfer to Greece: 129 MW; o Power transfer to UCTE: 1868 MW; First set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). Second set of constraints: o Critical Contingency: Line 400 kV Kashar(AL) – Podgorica (MN); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

It can be noted that the introduction of the 400 kV Kosovo-Albania has improved the maximum transfer capability of the network. The new line has increased the maximum power transfer with 736 MW or 57% more. b. Export to Albania as function of export to Greece and UCTE Without new 400 kV line Kosovo C (KS) – Kashar (AL) The results of computer calculation in for of monograms are given in Figure 1-26. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE. The maximum power transfer from Kosovo is the red point in figure.

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Figure 1-26 – 2014 Boundary Diagrams NTC of Kosovo no KS-AL

With new 400 kV line Kosovo C (KS) – Kashar (AL)

The results of computer calculation in form of monograms are given in Figure 1-27. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE. The maximum power transfer from Kosovo is the red point in figure. It can be noted that the introduction of the 400 kV Kosovo-Albania has improved the maximum transfer capability of the network.

Figure 1-27 – 2014 Boundary Diagrams of NTC of Kosovo with new line KS-AL

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Target year 2016

In order to assess the impact of power flow transit on interconnected lines, the Power Transfer Distribution Factors are calculated and reported in Tables A4.17 to A4.19 in Annex 4. The Line Outage Distribution Factors are calculated and reported in Table A4.20 in Annex 4. 1.5.3.3.1

Calculation of nonsimultaneous NTC of the transmission network a. Export to Albania

The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 923 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

b. Export to Greece

Net Transfer Capability: 623 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

c. Export to UCTE (North direction)

Net Transfer Capability: 637 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

Calculation of simultaneous NTC of the transmission network c. Export to Albania, Greece and UCTE

Under the presence of power exchanges between other countries and assuming N-1 conditions of the network, the following results are found: • Maximum Power transfer from Kosovo: 1645 MW composed by: o Power transfer to Albania: 66 MW; o Power transfer to Greece: 96 MW; o Power transfer to UCTE: 1482 MW; • First set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). • Second set of constraints: o Critical Contingency: Line 400 kV Kosovo(KS) – Nish (SR); European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK). d. Export to Albania as function of export to Greece and UCTE

The results of computer calculation in form of monograms are given in Figure 1-28. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE. The maximum power transfer from Kosovo is the red point in figure. It can be noted that the introduction of the 400 kV Kosovo-Albania has improved the maximum transfer capability of the network.

Figure 1-28 – 2016 Boundary Diagrams of NTC of Kosovo transmission network

1.5.3.4

Target year 2018

In order to assess the impact of power flow transit on interconnected lines, the Power Transfer Distribution Factors are calculated and reported in Tables A4.21 to A4.23 in Annex 4 for the network configuration without the 400kV line Kosovo- Macedonia, and in Tables A4.25 to A4.27 for the configuration with the new line. The Line Outage Distribution Factors are calculated and reported in Table A4.25 in Annex 4 and Table A4.28 respectively for two configurations of the transmission network. 1.5.3.4.1

Calculation of nonsimultaneous NTC of the transmission network a. Export to Albania Without a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 745 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

With new 400 kV line Kosovo C (KS) – Skopje 4 (MK)

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Net Transfer Capability: 846 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

b. Export to Greece Without new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 745 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

With new 400 kV Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 756 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Skopje 5 (MK); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Skopje 4 (MK).

c. Export to UCTE (North direction) Without new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 448 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

With new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • • 1.5.3.4.2

Net Transfer Capability: 522 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

Calculation of simultaneous NTC of the transmission network a. Export to Albania, Greece and UCTE Without new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the power transfers countries and assuming N-1 conditions of the network, gives the following results:

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Maximum Power transfer from Kosovo: 1635 MW composed by: o Power transfer to Albania: 81 MW; o Power transfer to Greece: 461 MW; o Power transfer to UCTE: 1093 MW; Set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

With new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the power transfers countries and assuming N-1 conditions of the network, gives the following results: •

• •

Maximum Power transfer from Kosovo: 2152 MW composed by: o Power transfer to Albania: 0 MW; o Power transfer to Greece: 1026 MW; o Power transfer to UCTE: 1126 MW; First set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). Second set of constraints: o Critical Contingency: Line 400 kV Dubrovo(MK) – Thessaloniki (GR); o Limiting Conditions: overload of 400 kV Bitola (MK) – Florina (GR).

It can be noted that the introduction of the 400 kV Kosovo-Macedonia has improved the maximum transfer capability of the network. The new line has increased the maximum power transfer from Kosovo with 517 MW or 32% more. b. Export to Albania as function of export to Greece and UCTE Without new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The results of computer calculation in for of monograms are given in Figure 1-29. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE. The maximum power transfer from Kosovo is the red point in figure.

Figure 1-29 – 2018 Boundary Diagrams NTC of Kosovo no KS-MK

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With new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The results of computer calculation in form of monograms are given in Figure 1-30. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE.

The maximum power transfer from Kosovo is the red point in figure. It can be noted that the introduction of a new 400 kV Kosovo-Macedonia has improved the maximum transfer capability of Kosovo mainly in South direction of the network.

Figure 1-30 – 2018 Boundary Diagrams of NTC of Kosovo with new line KS-MK

1.5.3.5

Target year 2020

In order to assess the impact of power flow transit on interconnected lines, the Power Transfer Distribution Factors are calculated and reported in Tables A4.29 to A4.31 in Annex 4 for the network configuration without the 400kV line Kosovo- Macedonia. Power Transfer Distribution Factors are calculated and reported in Tables A4.33 to A4.35 in Annex 4 for the network configuration with the 400kV line KosovoMacedonia. Power Transfer Distribution Factors are calculated and reported in Tables A4.37 to A4.39 in Annex 4 for the network configuration with the 400kV line Nish- Skopje. The Line Outage Distribution Factors are calculated and reported in Table A4.32 in Annex 4 for the network configuration without the 400kV line Kosovo- Macedonia. The Line Outage Distribution Factors are calculated and reported in Table A4.36 in Annex 4 for the network configuration with the 400kV line Kosovo- Macedonia. The Line Outage Distribution Factors are calculated and reported in Table A4.40 in Annex 4 for the network configuration with the 400kV line Nish- Skopje. 1.5.3.5.1

Calculation of nonsimultaneous NTC of the transmission network a. Export to Albania Network Configuration planned for 2020 The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results:

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Net Transfer Capability: 761 MW; Critical Contingency: Line 400 kV Zemljak (AL) – Kardia (GR); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

With a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 796 MW; Critical Contingency: Line 400 kV Zemljak (AL) – Kardia (GR); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

With a new 400 kV line Nish (SR) – Skopje 5 (MK) The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 760 MW; Critical Contingency: Line 400 kV Zemljak (AL) – Kardia (GR); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Kashar (AL).

b. Export to Greece Network Configuration planned for 2020 The calculation of the transfer capabilities taking into consideration the scheduled power exchanges between other countries and assuming N-1 conditions of the network, gives the following results: • • •

Net Transfer Capability: 744 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

Net Transfer Capability: 891 MW; Critical Contingency: Line 400 kV Kosovo (KS) – Skopje 5 (MK); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Skopje 4 (MK).

Net Transfer Capability: 703 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo C (KS) – Skopje 4 (MK).

c. Export to UCTE (North direction) Network Configuration planned for 2020

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Net Transfer Capability: 402 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

Net Transfer Capability: 426 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

Net Transfer Capability: 409 MW; Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS).

Calculation of simultaneous NTC of the transmission network a. Export to Albania, Greece and UCTE Network Configuration planned for 2020 The calculation of the transfer capabilities taking into consideration the power transfers countries and assuming N-1 conditions of the network, gives the following results: • Maximum Power transfer from Kosovo: 1618 MW composed by: o Power transfer to Albania: 25 MW; o Power transfer to Greece: 636 MW; o Power transfer to UCTE: 957 MW; • First set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). • Second set of constraints: o Critical Contingency: Line 400 kV Kashar (AL)– Podgorica (MN); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). • Third set of constraints: o Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK). With a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The calculation of the transfer capabilities taking into consideration the power transfers countries and assuming N-1 conditions of the network, gives the following results: •

Maximum Power transfer from Kosovo: 1553 MW composed by:

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o Power transfer to Albania: 40 MW; o Power transfer to Greece: 727 MW; o Power transfer to UCTE: 786 MW; First set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). Second set of constraints: o Critical Contingency: Line 400 kV Kashar (AL)– Podgorica (MN); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). Third set of constraints: o Critical Contingency: Line 400 kV Kosovo (KS) – Skopje 5 (MK); o Limiting Conditions: overload of 400 kV Kosovo C(KS) – Skopje 4 (MK).

It can be noted that the introduction of the 400 kV Kosovo-Macedonia has not improved the maximum transfer capability of the network. With a new 400 kV line Nish (SR) – Skopje 5 (MK) The calculation of the transfer capabilities taking into consideration the power transfers countries and assuming N-1 conditions of the network, gives the following results: •

•

Maximum Power transfer from Kosovo: 1553 MW composed by: o Power transfer to Albania: 609 MW; o Power transfer to Greece: 630 MW; o Power transfer to UCTE: 314 MW; First set of constraints: o Critical Contingency: Line 400 kV Kosovo C (KS) – Kashar (AL); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK); o Limiting Conditions: overload of 400 kV Kosovo (KS) – Peja (KS). Second set of constraints: o Critical Contingency: Line 400 kV Kosovo (KS) – Peja (KS) o Limiting Conditions: overload of 400 kV Kosovo (KS) – Skopje 5 (MK).

It can be noted that the introduction of the 400 kV Nish – Leskovac - Skopje has not improved the maximum transfer capability of the network. b. Export to Albania as function of export to Greece and UCTE Network Configuration planned for 2020 The results of computer calculation in form of monograms are given in Figure 1-31. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE. The maximum power transfer from Kosovo is the red point in figure.

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Figure 1-31 – 2020 Boundary Diagrams NTC of Kosovo

With a new 400 kV line Kosovo C (KS) – Skopje 4 (MK) The results of computer calculation in for of monograms are given in Figure 1-32. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE.

The maximum power transfer from Kosovo is the red point in figure.

Figure 1-32 – 2020 Boundary Diagrams of NTC of Kosovo with new line KS-MK

With a new 400 kV line Nish (SR) – Skopje 4 (MK) The results of computer calculation in for of monograms are given in Figure 1-33. The boundary diagrams illustrate the maximum power transfer toward Albania in function of the export to Greece assuming different levels for export to UCTE.

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Figure 1-33 â&#x20AC;&#x201C; 2020 Boundary Diagrams of NTC of Kosovo with new line SR-MK

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Conclusion

The transfer capacities of the regional interconnected transmission network considering projected system conditions demand growth, uses, and limits are accurately assessed for the analyzed period following the increase of electric power injection from entering in service the new units of TPP Kosovo C. The calculated monograms, to be used for determination of simultaneous and non simultaneous maximum power transfers to a selected direction, are reported in Figure A4.1 to A4.17 in Annex 4 for each of the target year and for different load conditions. The calculated values of NTC should be used for planning purposes. The uncertainties associated to the forecast of the power system state, for a given time-period in the future, may increase according to the selected time frame. Therefore the NTC value may vary (i.e. may increase or decrease) when approaching the time of programme execution due toa more accurate knowledge of generating unit schedules, interconnection-lines availability and/or the future electric power transactions that are inherently uncertain and can have significant impacts on transmission loadings. The evolution of simultaneous maximum Net Transfer Capacities of the planned and reinforced transmission network from Kosovo in directions toward selected Utilities during the period 2012-2020 is depicted graphically below in Figure 1-34. The evolution of nonsimultaneous Net Transfer Capacities of the planned and reinforced transmission network between Kosovo and selected Utilities during the period 2012-2020 is depicted graphically below in Figure 1-35 for Albania, Figure 1-36for Greece and Figure 1-37 for UCTE. From the obtained calculation results regarding all the period, can be concluded as follows: •

The NTC available to the electric power delivery from Kosovo C, is going to decrease over the study period and, without reinforcements of the transmission network can arrive at not acceptable levels representing a constraint to the amount of electric power that can be transferred over the interconnected transmission network in a reliable manner to potential off-takers.

•

Ranking the candidate lines for network reinforcement according to the amount of increase of the capability of the transmission network can be concluded that the first preference is the new 400 kV line Kosovo C- Kashar (AL). This new line allows for a significant increase of NTC in all the analyzed directions of energy transfers, even to UCTE.

•

The second additional alternative is a new 400 kV line Kosovo- Skopje that has greater impact in increasing the transmission transfer capability than a new line Nish – Skopje.

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Figure 1-34 Maximum NTC of Kosovo transmission system

Figure 1-35 Development of NTC between Kosovo and Albania

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Figure 1-36 Development of NTC between Kosovo and Greece

Figure 1-37 Development of NTC between Kosovo and UCTE

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1.6

Capacity Allocation and Congestion Management (Part of Subtasks 2.1 of ToR)

1.6.1

Introduction Congestion is a common phenomenon in the European electricity market. For example at present, of 24 interconnectors, 12 are permanently or frequently congested, 5 are occasionally congested and only 7 are seldom or never congested. A considerable amount of the existing capacity is allocated to long term contracts, especially in the areas where the market price differences at the border are the highest (borders of Italy, Netherlands and Spain).

Compared to other goods, the specificity of electric power is that the flow corresponding to a given electricity exchange cannot be controlled, but is governed by immutable physical laws. In a highly meshed network like western continental Europe’s, a single electricity exchange between France and Italy will partly flow through France-Italy interconnections, but also through France-Switzerland-Italy, and even France-Germany-Austria-Slovenia-Italy, and so on. In the UCTE area the allocation of capacities is very much dependent on network safety, reliability and co-operation agreements made in the UCTE. The calculation of available capacities is based on the application of a winter and a summer base case which is an estimation of a realistic network flow situation at a specified time. Net transfer capacities are obtained by adding to these base case loads, additional flows at each interconnector until the security limit is reached. The base case chosen and several of the UCTE rules have a big influence on the amount of capacity made available. In addition to UCTE rules, each TSO has its own rules regarding network planning and operation. Examples of differences which have a big influence on capacity made available are admissible line temperatures, application of N-1 criteria (sometimes N-2) and operations presumed to be taken after faults. The Regulation 1228/2003 of the European Parliament and the Council of 26 June 2003 on "Conditions for access to the network for cross-border exchanges in electricity" has laid down preliminary guidelines for the implementation of crossborder congestion management method. In the end of 2005, the EU-Commission provided a new draft for Guidelines on Cross-Border Congestion Management for adoption on January, 25, 2006 The main principles for a market based congestion management methods are: • • •

ensure optimal utilization of transmission capacity; give appropriate price signals to the market parties, and the TSOs involved; are non-transaction base.

Although congestion management methods (CM) for open electricity markets exist in many variations, the criteria to assess a method for resolving congestion are: • fair and non-discriminatory (for the same service, two users should pay the same price and should be treated equally); • economically efficient (individual behaviours of generation, demand and transmission operators should lead to the system optimum through relevant incentives). Appropriate incentives are likely to involve cost-reflective charges; • transparent and non-ambiguous (the method and its implementation should be clear for every participant and should be robust against gaming). Moreover, simplicity is essential if market players are to understand the rules. European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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feasible; congestion management must always be possible, because it is being a key issue for the system reliability; compatible with different types of trade and contracts (bids on a spot market or on a real time market, short-term bilateral contracts, longer term bilateral contracts…).

At present the capacity allocation methods for cross-border trade of electricity vary considerably. The following list gives an overview of the methods: ¾ Retention: Capacity is reserved for vertically integrated utilities. This applies especially to all old long term contracts. ¾ First come, first served: The capacity is allocated according to the requests until all capacity is booked. ¾ Pro-rata: Market participants make requests for capacity and then the demand for capacity is curtailed on pro-rata basis to fit the available amount. ¾ Explicit auctioning: The capacity is auctioned for different time periods (for example year, month, week, hour). The bids of the participants are stacked, highest bids first, until NTC is completely used. Several methods to fix both the clearing price and the volume of capacity allocated exist. However the price to be paid by all the accepted bidders is usually the lowest accepted bid. Once the NTC is completely used, either the process is stopped, or there is some redispatching, according to the level of the clearing price and the process may go on with the extra trade possibilities. ¾ Implicit auctioning/ market splitting: Allocation of the cross-border capacity is based on generators’ bids into the electricity spot markets. This method consists of splitting a power exchange (PEX) into geographical bid areas with limited capacities of exchange; a power pool price is set according to amounts of demand and generation offered in the whole market area. Then the TSO computes a load flow and identifies constrained lines. The interconnector capacity is allocated by the TSO on the basis of the prevailing wholesale prices in the organized power exchanges either side of the interconnector. Any remaining price difference between the two markets means that the TSO will make a profit from its “brokering” activities. ¾ Curtailment based on published NTCs: The publication of NTCs which relate to the capacity of exchanges between two areas is the minimum information which is required to be used as an indicator to allow market actors to evaluate the risks of seeing their transaction curtailed (and take adequate measures such as: swap, backup contracts, hedging, etc.).

Irrespective of any mechanism for congestion management, NTC knowledge for a given interface between two TSOs is recognized as a practical indicator of actual trading possibilities at a given time. The NTC publications as open market information are freely and periodically published by TSOs and it has to be provided to market participants. In next Table are described methods of congestion management in use in SEE between various countries in 2005 and frequency of capacity allocation. Table A4.41 in Annex 4 reports the methods of CM currently used in UCTE. 1.6.2

Congestion Management methods in SEE By signing the Treaty Establishing Energy Community, which came into force in July 2006, SEE countries agreed to follow the EC documents Regulation EC 1228/2003,

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and consequently the draft Guidelines for Congestion Management. Therefore in future period SEE TSOs have to endeavor to apply the requirements of the CM Guidelines. Table 1-81 Year 2005 Congestion Management and Capacity Allocation SEE ASSESSMENT OF CONGESTION MANAGEMENT AT EUROPEAN BORDERS (FEB 05) Conventional TC NTC (MW) of the Allocation Allocation Capacity Use it or Country 1 Country 2 Congested Winter 2005 Interconnection method frequency tradability loose it (MVA Thermal) EA/RET CRO SLO >1000 4816 d No yes occasionally FF SLO CRO >1000 4816 d No yes never RET GR IT 350 500 y,d No Yes frequently EA/PR IT GR 500 500 y,d No Yes occasionally RET/EA FYROM GR 600 1420 y No Yes occasionally RET/EA BG GR 600 1300 y No yes occasionally EA HU SCG 400 1332 y,m yes Yes frequently EA SCG HU 300 1332 y,m yes Yes EA HU RO 300 1246 y,m yes Yes EA RO HU 300 1246 Y,m yes Yes frequently EA/RET HU CRO 600 2688 y, m yes Yes frequently EA/RET CRO HU 300 2688 y,m yes yes FF/RET CRO BIH 700 NA y,m,d no never FF/RET BIH CRO 600 NA y,m,d no occasionally FF BIH CG 600 NA y,m,d no never FF CG BIH 600 NA y,m,d no never FF SR CG 1000 NA y,m,d no never FF CG SR 1000 NA y,m,d no never FF SR MA 700 NA y,m,d no never FF MA SR 700 NA y,m,d no never FF SR BO 600 NA y,m,d no never FF BO SR 600 NA y,m,d no never FF SR RO 400 NA y,m,d no never FF RO SR 400 NA y,m,d no never FF/RET CRO SR 700 NA y,m,d no never FF/RET SR CRO 500 NA y,m,d no seldom FF GR MA 400 NA y,m,d no never FF AL KO 100 NA y,m,d no FF KO AL 100 NA y,m,d no FF CG AL 250 NA y,m,d no FF AL CG 100 NA y,m,d no FF RO BO 1000 NA y,m,d no FF BO RO 700 NA y,m,d no FF AL GR 1200 NA y,m,d no FF GR AL 1200 NA y,m,d no FF BO GR 1200 NA y,m,d no FF GR BO 1200 NA y,m,d no FF KO SR 800 NA y,m,d no FF SR KO 800 NA y,m,d no FF KO MA 1200 NA y,m,d no FF MA KO 1200 NA y,m,d no Source: EFET Allocation frequency: y yearly, s semi-annually, q quarterly, m monthly, w weekly, d daily

Currently applied capacity allocation methods in SEE are presented in a document [23], and a situation October 2006, is illustrated in Figure 1-38.

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Figure 1-38 Monthly Capacity Allocation in SEE. (source SETSO TF 2006)

In SEE region the current situation (2006) of CM method applied in some of the interconnections is described in the following. Greece-Italy

In 2006, for the direction Greece to Italy, HTSO manages the allocation of 50% of the available capacity, following the method based on the explicit auctions. In this allocation procedure the eligible participants are the owners of either production or supply licenses. TERNA manages the remaining 50% of the available capacity. The available capacity for exports from Greece to Italy allocated on a long-term basis is varied by month, day and time of the period. This capacity is calculated by HTSO for meeting the security of supply requirements of the Greek System and it is approved by the Regulatory Authority for Energy. On March 2006, HTSO launched the short-term (daily) electronic allocation of the remaining available capacity, which varies by the month, day and time of the period. Greece - Albania, Bulgaria, Macedonia

In 2006, for the direction from either Albania, or Bulgaria, or Macedonia, to Greece, the available capacity is 600 MW, of whom 20 MW is allocated to the Public Power Corporation (PPC) and 200 MW is allocated to the other Eligible Market Participants by a long-term explicit auction. From March 2006, HTSO launched the short-term (daily) electronic allocation of the available capacity for exports from Greece to Albania, Bulgaria and Macedonia. 1.6.3

Work status of the Coordinated Auctions dry-run simulation in SEE SEE TSOs jointly investigate the Coordinated explicit flow-based Auctions (CA) through the dry-run implementation (DrCA) of this method during 2006, which is likely to be continued in 2007. CA method investigated and proposed for future implementation in SEE, fulfils the Guidelines' requirements, especially regarding

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market-based nature, regional coordination, and information exchange and tracking physical power flows. During the 2006, dry-run implementation of CA is performed, where SEE TSOs simulate the flow-based CA at monthly rounds. The role of the Auctioning Office is performed by the NACMPF SG companies on a rotation basis. TSOs also played the role of market actors, by placing the bids for the transmission rights. For the purposes of the simulation of bidding, clearing and revenue sharing procedures, the web-based software Dry-run Coordinated Auction Tool (DrCAT) is used, made and hosted by APG. The joint meetings of SEE TSOs with SEE Regulators (May 2006) and traders/power utilities (Sept'2006) were held in Belgrade, where these parties agreed on joint work in the investigation and the design of CA. Currently, the participation of the traders and power utilities in dry-run simulations (role: placing the bids) is in preparation, so the dry-run would be continued throughout the 2007, as a joint simulation by the TSOs and market actors, with Regulators' support and contribution. All the documents related to the dry-run can be found on ETSO web-site www.etsonet.org or on DrCAT page www.drcat.at. At this web-site there is also the page with Frequently Asked Questions. 1.6.4

Coordinated Auctioning: A market-base method for transmission capacity allocation in meshed network The Coordinated Auctioning method (CA) is used to manage congestions instead of a «classical» capacity auction sale from simple (i.e. one-border capacity sale) to more complex systems. The method is proposed to be applied to the different borders of a highly meshed system, involving multiple control areas, such as the continental European grid or SEE region.

The coordinated auctioning mechanism is likely to ensure the feasibility of complex bilateral cross-border trade and to provide an appropriate answer to the two following issues: •

handling adequately the problem of allocating scarce transmission capacity in highly meshed networks;

•

alleviating traders of the complexity of independent auctions in the main bottlenecks.

The main idea is that a simple representation of the meshed network effects (through load flow factors, so-called «Power Transfer Distribution Factors, PTDF») can take into account the main physical interactions. Thus, a standard mathematical formulation makes it possible to select the bids that represent the highest value for the market. The method is an extension of bilateral explicit auction mechanisms and one of the important properties of the proposed method is that every bidder whose bid contributes to saturate at least one bottleneck will be charged a fee. Otherwise the capacity is free of congestion charge if the bids are not participating to an active constraint. This method seems to be a valuable alternative to market splitting but to be implemented, the proposed method requires a high level of cooperation and

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coordination among TSOs; of course it is more easily feasible on «regional» congestion bottlenecks (with the involvement of the different control areas between which there are electricity exchanges that induce the majority of the flows through the bottlenecks). General Rules A) As general precondition, all different categories of market actors (e.g. individual players, traders, power exchanges, etc.) can be admitted to participate in the allocation process. The final user of the capacity needs to have adequate network access rights in the zones where he wants to exchange / place bids to or from. It is the local TSO that has the responsibility to control this, but a common database must be available to the Auction Office for verification tasks. B) A procedure has to exist for co-operation between TSOs for Congestion Management. Key steps of such a procedure are: 1. Calculations (i.e. base case load flow and network security analysis). 2. Detection of congestion problems (i.e. signalling whether there is indeed a congestion problem). 3. Determination of the consequences of a congestion (i.e. analysis of consequences). 4. Decision whether joint measures have to be taken (triggers are defined for that purpose). 5. Determination of solutions for a congestion (i.e. analysis of possible measures). 6. Decision of which measures to activate (i.e. choice of measures). 7. Implementation of the decided measures by the involved TSOs. 8. Clearing and settlement of costs.

A daily "Day Ahead Congestion Forecast" (DACF) performed by all involved TSOs the evening before execution day is needed to accomplish an ultimate control on the load flows due to formerly allocated transmission capacity. This DACF can serve as a starting point for the Congestion Management procedure (step 1).

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1.7

Transient Stability Analysis (Part of the subtask 2.2 of ToR)

1.7.1

Introduction

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Stability studies have been performed to assess system stability and to establish the stability limits following a set of critical fault on the Kosovo power system. On the framework of projected configuration of the network, these studies assess the dynamic performance of Kosovo’s transmission system modeling and simulating the dynamic behavior under the “interconnected mode” of operation. The analysis aims to identify the possible stability problems related to the introduction of the new power plant and to investigate dynamic constraints related with the unit size of the new power plant. The execution of dynamic studies in planning stages is carried on referring to the following recommendations from CIGRE (ref. Study Committee 1 “Power System Developments and Economics, Working Group 4 “Application and required developments of dynamic models to support practical planning”1); i.e. “…. the planner has the role of defining the “target dynamic behavior” of the system, to be attained by adopting the control performances identified through the dynamic analyses…. “ and “….the planner has the responsibility to identify the “minimum technical requirements” to cope with the so-called “credible contingencies” and outline the emergency actions to be triggered at the occurrence of “extreme contingencies”; all that in order to overcome/minimize the limitations in the power transfers related to dynamic constraints”. 1.7.2

Evidence of System Stability

The system will be considered stable if the following conditions are met: a) Machine Synchronism • • •

All machines in the system remain in synchronism as demonstrated by the relative rotor angles. Neither sustained nor increasing oscillations of the rotor angle are generated for any machine of the system; No loss of synchronism among machines is detected; No sustained voltage oscillations or the rotor angle are detected on any node.

b) System Damping •

The stability curves describing a transiently-limited time domain system trajectory, have been visually inspected to insure that the oscillations are damped or at least are as close to 5 % damping (neither increasing, nor decreasing in magnitude) as is possible. This value, in fact, is internationally adopted to ensure an acceptable operating condition of the system A stability simulation is deemed to exhibit positive damping if a line defined by the peak of the machine relative rotor angle swing curve will intersect a second line connecting the valley of the curves with an increase in time.

CIGRE SC1 WG 4 – Executive Summary to be published in Electra – ref. www.cigre-c1.org (WG convenor Bruno Cova)

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•

Corresponding lines on bus voltage swing curves will also intersect with an increase in time. A simulation, which satisfies these conditions, will be defined as stable. A simulation, which appears to have zero percent damping with acceptable voltage, will be defined as marginally stable. c) Simulation Time • •

Unless otherwise specified by the switching sequences, three-phase faults will be cleared in 120 msec. Duration of a stability simulation is ten seconds unless a longer time is required to ascertain stability.

d) Transient voltage and frequency performance •

1.7.3

Minimum transient frequency and duration, maximum transient voltage dips and duration, and post transient voltage deviations have been considered for each of the simulated scenarios. These parameters are measured at load buses; however, the minimum frequency and the transient voltage dip have been investigated for each case in order to evaluate the needs for eventually emergency actions.

Transient simulation Methodology Machine Representation

For dynamic and transient stability studies, a special attention was devoted to the representation of the generating units and their control systems. A detailed data set concerning the above topic consistent with available generator data was prepared before starting with time domain simulations. The power system of Kosovo and other systems in SEE are described in details, especially the following components:

Synchronous machines; Turbines; Speed governor; Excitation systems and voltage control.

The parameter data of synchronous generators for each country are given in Annex 5 in Tables A5.1 to A5.11. The types, block diagrams and parameters of excitation systems and voltage regulators used for simulation of system transient behavior, are given in Annex 5. Almost all the turbines of generation units have been modeled together with related speed governors. The type, block diagram and parameters of speed governor of Kosovo C and others, are given in Annex 5. Transmission Network modeling

Considering the particularity of Kosovo transmission network as a part of an interconnected regional network, the dynamic performance simulations have been performed while operating in interconnection mode. In particular, the simulation takes into consideration the interconnection lines, which affect in a sensible way the critical clearing times and, consequently, the stability of the rotors.

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1.7.4

Simulation for Validation of Dynamic Model

1.7.4.1

Test of dynamic behavior of control devices

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Before starting the simulation Consultant has performed a series of test aiming to check the correct transient behaviors of the control devices of the synchronous machines in the power system. Different types of voltage regulators and speed governors are tested and the results are reported in Annex. Particularly attention is dedicated to control devices of the new unit Kosovo C and the results are reported in the following. The dynamic response of the voltage regulator and excitation systems of Kosovo C is simulated for a validation of the correct behavior during transient state The excitation system performance is checked giving a step impulse of 0.05 pu of reference voltage and the transient response is reported in figure. It can be seen from the plot in Figure 1-39 the correct behavior of excitation system and the voltage on generator terminals is stabilized at the new level.

Figure 1-39 Kosovo C Exciter type ESST1A â&#x20AC;&#x201C; Step response

The Governor control system, of the new unit Kosovo C, has been checked to simulates the response of the governing loops to a step change in load. This activity is executed with the generator unit in isolated condition. The simulation results are reported in Figure 1-40 Some results of simulation of the dynamic response of the voltage regulator and speed governor are given in Annex 5.

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Figure 1-40 Governor type IEEEG1 – Step response on UNIT of Kosovo C G1

1.7.4.2

Reconstruction of selected emergencies

The common practice for validation of the dynamic model of a power system is the reconstruction, by computer simulations, of a real event and the comparison of the registered measurements of a set of significant electromechanical variables of the real system, with the digital simulation of the same set of variables. If the transient behavior of the selected variables from the mathematical model of the system is quite similar with on-field records, one can be confident that the model is working properly. In our study we are analyzing the dynamic performance of Kosovo’s transmission system modeling and simulating the dynamic behavior under the “interconnected mode” of operation and the problem is very complicated and complex because of the dimension of the model, the number of power system involved in SEE and the lack of the on-field records. The approach of the Consultant was the reconstruction through digital simulation of some reported emergency involving all SEE countries2. The cited source gives a list of main disturbances in operation of interconnected power systems during the year 2004 and the Consultant has selected some of them. The main and significant variable reported is the variation of the mean frequency of the interconnected system during and after a disturbance caused by a trip of a important unit or a part of the interconnected system. We have selected the year 2004 because it is the year of the resynchronization (October 10th, 2004. at 09:34h) of the Regional Electric Power Systems of Albania, Bulgaria, Greece, Kosovo, Macedonia, Montenegro, Romania, Serbia and a part of Ukraine with other European Power Systems part of 1st 2

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UCTE zone. After the resynchronization the trips of units or other disbalances into the interconnected system do not cause a frequency drop. The Consultant has reconstructed the configuration of the network before to the reconnection of the UCTE grid where most of SEE countries were part of the former 2nd UCTE zone. Some simulations have been carried out to validate the dynamic model used in the studies. The analyzed scenario represents the network operation condition in a point near to the peak for the region situation on year 2004. The results of these simulations has been compared with some events occurred in the region for The result of digital simulation of a trip of a big unit, TPP Nikola Tesla B 727.5 MVA (EPS) with a initial production of 605 MW. In the Figure 1-41 are given the plot of the variation of the frequency in TPP Nikola Tesla B (Serbia), TPP Agios Dimitrios (Greece) and TPP Kosovo B. No considerable frequency drop can be noted and the transient minimum value of mean frequency is about 49.83 Hz. This drop of frequency of about â&#x2C6;&#x2020;f = 170 mHz is quite similar with the recorded frequency drop of similar disturbances in SEE.

Figure 1-41 Variation of the frequency following the trip of N.Tesla B1

The comparison of on-field records with results obtained from digital simulations confirms the accuracy of the dynamic model used for dynamic simulation of the power system.

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Figure 1-42 Variation of the power flows on 400 kV lines following the trip of N.Tesla B1

1.7.5

System Disturbance

The analyzed system disturbances for stability studies are of the following types: 1.

Generation trips;

Three phase short circuit followed by a line trip.

Calculation of Critical Clearing Time: maximum time of permanence of a three phase fault, beyond which the rotor loses the synchronism

The first disturbance consists in simulation of unexpectedly trip of the new unit of Kosovo C with full load. The second disturbance consists in a three phase short circuit initiated by a threephase-to-ground fault on the HV bus adjacent to the major interconnection point of Kosovo and the new power plant of interest. The short circuits are supposed being correctly cleared by permanent line tripping It was assumed that the system operates in steady-state when the severe fault occurs on the line causing its tripping. The simulated switching sequence is: • •

At moment t= 0,1 sec three-phase fault is simulated at Kosovo B on the specified outgoing 400 kV lines; At moment t= 0.22 sec the fault is cleared by opening the circuit breakers at both ends of line and line is definitively open;

In order to correctly read the performed evaluations, it is important to know some aspects and restrictions or hypotheses adopted in the calculating process. The fixed fault time of 120 ms takes into consideration the following factor:

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A) fault inception time, B) relay protection time delay of the first zone including eventually teleprotection schemes (2 cycles), C) circuit-breaker interruption time (3 cycles); D) an adequate time margin in order to take into consideration the imprecision in system modeling, and system data, inaccuracy of control systems and other inaccuracy and random phenomenaâ&#x20AC;&#x2122;s (1 cycles). The third item has as objective to estimate the impact of the new power plant into the grid, examining the rotor stability of the new generating units facing three-phase faults simulated in the outcoming lines connecting the plant to the rest of the grid. In particular, the Consultant shall warrant that the Critical Clearing Times (CCTs) detected are compliant with the protection system time relays. To maintain system stability, the relay must clear the fault within the total clearing time. The maximum operating time of a line protection is assumed 2 cycles. The maximum operating time of the circuit breaker is assumed 3 cycles. Also, the maximum dropout time for phase current level detector of Breaker Failure protection scheme is assumed 1 cycle. Considering a safety margin of 1 to 2 cycles, the total clearing time for a short circuit in the busbar is 5 cycles (100 msec), if is not considered a breaker failure, to 7 cycles (140msec) for a local scheme of breaker failure and even more 10 cycles (200 msec) if we consider more complicated breaker failure schemes with a remote circuit breaker tripping. In the evaluation of the system stability using as criteria CCT we have assumed a maximum acceptable time of 130msec. A particular attention was paid to the propagation to the whole regional interconnected system of the consequences of the most severe faults to avoid that disturbance inside Kosovo power system is spread over the other partners. In the cases that have, in consequence of disturbance with the above mentioned times and characteristics, an unstable behavior or a response with no or low damped oscillations, we assume that there is not enough margin for stability of the interconnected system. Voltage regulators and excitation systems

The block diagram and the parameters of the type of voltage regulator and excitation system that have been used are given in Annex 5 in the figure A5.1 and A5.2. Governors control system

The block diagram and the parameters of the type of governor control system that is implemented in the Data Base for the new unit is given in Annex5 in the figure A5.3

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1.7.6

Year 2012 Transient Stability Analysis

1.7.6.1

Option 2 of new plant Kosovo C: Unit size 600 MW

1.7.6.1.1

Peak Load Condition

1.7.6.1.1.1

Loss of Generation

November, 2007 Page 104 (160)

The sudden trip of the largest unit, G1 of TPP Kosovo C with initial generation of 600 MW, without any preceding fault has been simulated to check the transient behavior of the transmission system. The results are illustrated in the diagrams given in Figure 1-43

Figure 1-43 Variation of the frequency following the trip of 600MW of Kosovo C

The variation of the frequency of the units of TPP Kosovo B is given in Figure 1-44. No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.94 Hz. The sudden loss of unit causes ties flow increases and the interconnection lines have picked up the lost generation. The diagram in Figure illustrates the variation of the power flows in the following interconnection lines: • • • •

400 kV Nis (SR) – Kosovo B; 400 kV Ribarevine (CG) – Peja III; 400 kV Skopje (MK) – Kosovo B; 400 kV Kashar (AL) – Kosovo C;

In any case the line loadings and voltages will not exceed rated values for the loss of the generator. No considerable frequency drop can be noted and also an absence of relevant network dynamic stresses due to the tripping of generation.

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Figure 1-44 Variation of the power flows on 400 kV lines following the trip of Kosovo C

1.7.6.1.1.2

Fault on 400 kV Kosovo B - Nis (SR) For the examined case, it can be observed that the three phase fault applied on the 400 kV line Kosovo B â&#x20AC;&#x201C; Nish brings the new unit of Kosovo C to the unstable condition (loss of synchronism). In Figure 1-45 is illustrated the plot of electrical power of G1 of TPP Kosovo C and it is clear the loss of synchronism after the first swing.

Figure 1-45 Plot of the electrical power of 600MW unit of Kosovo C

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As consequence of this phenomenon then power flows in interconnection lines show a variation over a long range spreading the disturbance in the neighboring power systems as can be seen in Figure 1-46. In Figure 1-47 is plotted the variation of the voltages on the 400 kV busbars of Kashar (ALB) and Skopje (MKD).

Figure 1-46 Active power flows on 400kV interconnection lines of Kosovo.

Figure 1-47 Variation of voltages on 400kV busbars of Kashar(AL) and Skopje (MK)

The loss of synchronism of the 600 MW unit of Kosovo C will be followed by the unit trip from the protection system of the unit. The results of simulation of trip of unit after loss of synchronism are illustrated in Figure 1-48,. After some extended oscillations the process is stabilized. The plots of the following relative rotor angles are shown in the Figure 1-49:

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• • • • •

HPP of Fierza(AL) TPP of Bitola (MK) NTP of Cernovoda (RO) TPP of Kosovo B (KS) TPP of Kardia (GR)

Figure 1-48 Active power flows on 400kV lines after trip of Kosovo C.

Figure 1-49 Rotor Angles of selected generators after trip of Kosovo C.

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1.7.6.1.2

Light load conditions

1.7.6.1.2.1

Loss of Generation

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Figure 1-50 Variation of the frequency following the trip of 500MW of Kosovo C

In the Figure 1-51 are given the plot of the variation of the frequency in TPP Kosovo B that remains in service. No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.94 Hz. 1.7.6.1.2.2 Fault on 400 kV Kosovo B - Nis (SR) In Figure 1-53 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B â&#x20AC;&#x201C; Nish is removed through opening of the faulted line. It can be observed that the new unit of Kosovo C remains in synchronism after some oscillations that last of about 5 sec.

Analyzing the rotor dynamics of the generators following the line fault, it can be noted that the rotor swings do not reach the critical angle and the frequencies are positively damped.

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Figure 1-51 Plot of the electrical power of 600MW unit of Kosovo C

The variation of power flows in interconnection lines is shown in Figure 1-54.

Figure 1-52 Active power flows on 400kV interconnection lines of Kosovo.

1.7.6.1.3 Conclusions The main considerations of the analysis of 600 MW unit size for Kosovo C are the following: Steady State analysis

The network situation in 2012 was analyzed from point of view of line and equipment loadings, accepted voltage levels, presence of eventually bottlenecks, excessive and

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unjustified losses, eventually violation of generation capability limits (especially reactive), etc. The overload limits of lines and transformers, the capability chart for the generation units and the accepted voltage deviation over the transmission network were carefully investigated in order to assess the feasibility of the operating conditions in normal operation. The voltage profile is between lower and upper acceptable limits over the regional transmission system. Transient Stability analysis

Analyzing the rotor dynamics of the generators following the line fault, it can be noted that during peak load conditions the rotor swings reach the critical angle and the new 600 MW unit of Kosovo C losses the synchronism. The digital simulations of regional power system clearly demonstrate that the system is unstable and show that the Kosovo power system has not sufficient dynamic stability margins. 1.7.6.2

Option 1 of new plant Kosovo C: Unit size 500 MW

1.7.6.2.1

Peak Load Condition

1.7.6.2.1.1

Loss of Generation

Figure 1-53 Variation of the frequency following the trip of 500MW of Kosovo C

In the figure are given the plot of the variation of the frequency in TPP Kosovo B that remains in service. No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.95 Hz.

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The sudden loss of unit causes ties flow increases and the interconnection lines have picked up the lost generation. The diagrams in Figure 1-54 illustrate the variation of the power flows in the following interconnection lines: • • • •

400 kV Nis (SR – Kosovo B; 400 kV Ribarevine (CG) – Peja III; 400 kV Skopje (MK) – Kosovo B; 400 kV Kashar (AL) – Kosovo C;

Figure 1-54 Variation of the power flows on 400 kV lines following the trip of Kosovo C

1.7.6.2.1.2

Fault on 400 kV Kosovo B - Nis (SR) In Figure 1-55 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B – Nish is removed through opening of the faulted line. It can be observed that the new 500 MW unit of Kosovo C remains in synchronism after some oscillations that last of about 5 sec.

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Figure 1-55 Plot of the electrical power of 500MW unit of Kosovo C

The plots of the following relative rotor angles are shown in the Figure 1-56: • • • • •

HPP of Fierza(AL) TPP of Bitola (MK) NTP of Cernovoda (RO) TPP of Kosovo B (KS) TPP of Kardia (GR)

Figure 1-56 Variation of Rotor Angles of selected generator.

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Analyzing the rotor dynamics of the generator of Kosovo C and other selected generators in the region, following the line fault, it can be noted in Figure that the rotor swings do not reach the critical angle and the frequencies are positively damped. The power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-57

Figure 1-57 Active power flows on 400kV interconnection lines of Kosovo.

1.7.6.2.1.3

Calculation of Critical Clearing Time The critical clearing times have been computed for Kosovo C, Kosovo B and Kosovo A main busbars. Also the critical clearing times have been computed for some main system substations in the SEE region close to the new power station.

Next table summarizes the shortest critical clearing times for faults simulated at the selected nodes of the transmission network. In Table 1-82 is reported in msec. the longest fault duration without loss of synchronism and the shortest fault duration with loss of synchronism of one or several generators. Table 1-82 Year 2012 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo Albania Macedonia Greece Serbia

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A 220kV Koman 400kV Bitola 400kV Kardia 400kV N. Tesla

1.7.6.2.2

Light load conditions

1.7.6.2.2.1

Loss of Generation

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msec 154 158 278 350 212 378 174

Unstable generator(s)

msec 156 Unit Kosovo C 160 Unit Kosovo C 280 Unit Kosovo C 352 Unit Koman G1 214 Unit Bitola G2 380 Unit Kardia G3 176 Unit N. Tesla G1

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Figure 1-58 Variation of the frequency following the trip of 500MW of Kosovo C

In the Figure 1-58 are given the plot of the variation of the frequency in TPP Kosovo B that remains in service. No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.95 Hz. 1.7.6.2.2.2 Fault on 400 kV Kosovo B - Nis (SR) In Figure 1-59 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B â&#x20AC;&#x201C; Nish is removed through opening of the faulted line. It can be observed that the new unit of Kosovo C remains in synchronism after some oscillations that last of about 5 sec.

Analyzing the rotor dynamics of the generators following the line fault, it can be noted that the rotor swings do not reach the critical angle and the frequencies are positively damped.

Figure 1-59 Plot of the electrical power of 500MW unit of Kosovo C

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The variation of power flows in interconnection lines is shown in Figure 1-60.

Figure 1-60 Active power flows on 400kV interconnection lines of Kosovo.

1.7.6.2.3

Starting Year 2012 Conclusions The main considerations of the analysis of the impact of 500 MW unit size for Kosovo C are the following:

Analyzing the rotor dynamics of the generators following the line fault, we can conclude that the system was able to maintain stability limits during two extreme load conditions and the new 500 MW unit of Kosovo C does not loss the synchronism. The modeled regional transmission system posses an adequate stability margin related to transient stability performance, current overloads of interconnection lines, oscillatory damping and post-transient voltage. The unit trip causes frequency deviations that are negligible and in a few seconds the whole system recovers to satisfactory operating conditions

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1.7.7

Year 2014 Transient Stability Analysis

1.7.7.1

Year 2014 Network configuration without the 400 kV line Kosovo C (KS) – Kashar (AL)

1.7.7.1.1

Loss of Generation

The sudden trip of the largest unit, G1 of TPP Kosovo C with initial generation of 500 MW, without any preceding fault has been simulated to check the transient behavior of the transmission system. In the Figure 1-61 are given the plot of the variation of the frequency in AEC Kozlodou (BG). No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.948 Hz.

Figure 1-61 Variation of the frequency following the trip of 500MW of Kosovo C

1.7.7.1.2 Fault on 400 kV Kosovo B - Nis (SR) In Figure 1-62 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B – Nish is removed through opening of the faulted line. It can be observed that the new 500 MW unit of Kosovo C remains in synchronism after some oscillations that last of about 5 sec.

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Figure 1-62 Plot of the electrical power of 500MW unit of Kosovo C

1.7.7.1.3

Next table summarizes the shortest critical clearing times for faults simulated at the selected nodes of the transmission network. In the Table 1-83 is reported in msec. the longest fault duration without loss of synchronism and the shortest fault duration with loss of synchronism of one or several generators. Table 1-83 Year 2014 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo Albania Macedonia Greece Serbia

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A 220kV Koman 400kV Bitola 400kV Kardia 400kV N. Tesla

msec 152 158 278 362 216 382 180

Unstable generator(s)

msec 154 Unit Kosovo C 160 Unit Kosovo C 280 Unit Kosovo A G4 364 Unit Koman G1 218 Unit Bitola G2 384 Unit Kardia G3 182 Unit N. Tesla G1

1.7.7.2

Year 2014 Network configuration with the 400 kV line Kosovo C (KS) – Kashar (AL)

1.7.7.2.1

Fault on 400 kV Kosovo B - Nis (SR) In Figure 1-63 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B – Nish is removed through opening of the faulted line. No stability problems are found.

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Figure 1-63 Plot of the electrical power of 500MW unit of Kosovo C

The variation of power flows in interconnection lines is shown in Figure 1-64. The line with the highest excursion of power flow is the 400 kV line with Skopje (MK).

Figure 1-64 Active power flows on 400kV interconnection lines of Kosovo.

1.7.7.2.2

Next Table 1-84 summarizes the shortest critical clearing times for faults simulated at the selected nodes of the transmission network. In the tables is reported in msec. the longest fault duration without loss of synchronism and the shortest fault duration with loss of synchronism of one or several generators.

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Comparing to case with the line Kosovo-Albania it can be observed a reduction of CTT for fault in 220 kV of Kosovo A. Table 1-84 Year 2014 Critical Clearing Times

Country

Kosovo

1.7.7.3

Busbar 400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A

CCT tstable tinstable msec 154 156 272

Unstable generator(s)

msec 156 Unit Kosovo C 158 Unit Kosovo C 274 Unit Kosovo A G4

Year 2014 Conclusions The main considerations of the analysis of the impact of 500 MW unit size for Kosovo C are the following:

Analyzing the rotor dynamics of the generators following the line fault, we can conclude that the system was able to maintain stability limits during two extreme load conditions and the new 500 MW units of Kosovo C does not loss the synchronism. The modeled regional transmission system posses an adequate stability margin related to transient stability performance, current overloads of interconnection lines, oscillatory damping and post-transient voltage. The unit trip causes frequency deviations that are negligible and in a few seconds the whole system recovers to satisfactory operating conditions

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1.7.8

Year 2016 Transient Stability Analysis

1.7.8.1

Option 1 of new plant Kosovo C: Unit sizes 500 MW

1.7.8.1.1

Loss of Generation

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The sudden trip of one of three units of TPP Kosovo C with initial generation of 500 MW, without any preceding fault has been simulated to check the transient behavior of the transmission system. The results are illustrated in the diagrams given in Figure 1-65.

Figure 1-65 Variation of the frequency following the trip of 500MW of Kosovo C

In the Figure are given the plot of the variation of the frequency in TPP Bitola (MK). No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.947 Hz. 1.7.8.1.2

Fault on 400 kV Kosovo B - Nis (SR) No stability problems are found after that the three phase fault applied on the 400 kV line Kosovo B â&#x20AC;&#x201C; Nish is removed through opening of the faulted line. In Figure 1-66 is illustrated the plot of electrical power of G1 of TPP Kosovo C It can be observed that the new 500 MW unit of Kosovo C remains in synchronism after some oscillations that last of about 5 sec.

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Figure 1-66 Plot of the electrical power of 500MW unit of Kosovo C

The power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-67

Figure 1-67 Active power flows on 400kV interconnection lines of Kosovo.

1.7.8.1.3

Fault on 400 kV Kosovo C - Kashar(AL) No stability problems are found after that the three phase fault applied on the 400 kV line Kosovo C â&#x20AC;&#x201C; Kashar (AL) is removed through opening of the faulted line.

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Figure 1-68 Plot of the electrical power of 500MW unit of Kosovo C

The variation of power flows in interconnection lines is shown in Figure 1-69. The line with the highest excursion of power flow is the 400 kV line with Skopje (MK).

Figure 1-69 Active power flows on 400kV interconnection lines of Kosovo.

1.7.8.1.4

Fault on 400 kV Kosovo C - Peja

No stability problems are found after that the three phase fault applied on the 400 kV line Kosovo C â&#x20AC;&#x201C; Peja is removed through opening of the faulted line. The variation of power flows in interconnection lines is shown in Figure 1-70. The line with the highest excursion of power flow is the 400 kV line with Skopje (MK).

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Figure 1-70 Active power flows on 400kV interconnection lines of Kosovo.

1.7.8.1.5

Next table summarizes the shortest critical clearing times for faults simulated at the selected nodes of the transmission network. In the Table 1-85 is reported in msec. the longest fault duration without loss of synchronism and the shortest fault duration with loss of synchronism of one or several generators. Table 1-85 Year 2016 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo Albania Macedonia Greece Serbia

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A 220kV Koman 400kV Bitola 400kV Kardia 400kV N. Tesla

msec 140 144 288 322 228 380 178

Unstable generator(s)

msec 142 Unit Kosovo C 146 Unit Kosovo C 290 Unit Kosovo A G4 324 Unit Koman G1 230 Unit Bitola G1 382 Unit Kardia G3 180 Unit N. Tesla G1

1.7.8.2

Option 3 of new plant Kosovo C: Unit size 750 MW

1.7.8.2.1

Loss of Generation

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Figure 1-71 Variation of the frequency following the trip of 750MW of Kosovo C

In the Figure 1-71 are given the plot of the variation of the frequency in Kosovo C and TPP Bitola (MK). No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.924 Hz.

Figure 1-72 Plot of the electrical power of 750MW unit of Kosovo C

1.7.8.2.2

Fault on 400 kV Kosovo B - Nis (SR) In Figure is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B â&#x20AC;&#x201C; Nish is removed through opening of the faulted line. It can be observed that the new 500 MW unit of Kosovo C remains in synchronism after some oscillations that last of about 5 sec.

Analyzing the rotor dynamics of the generator of Kosovo C and other selected generators in the region, following the line fault, it can be noted in Figure 1-73 that the rotor swings do not reach the critical angle and the frequencies are positively damped. The power flows in 400kV interconnection lines of Kosovo are reported in Figure

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Figure 1-73 Active power flows on 400kV interconnection lines of Kosovo.

1.7.8.2.3 Fault on 400 kV Kosovo C – Kashar (AL)

No stability problems are found after that the three phase fault applied on the 400 kV line Kosovo C – Kashar (AL) is removed through opening of the faulted line. In Figure 1-74 is illustrated the plot of electrical power of G2 of TPP Kosovo C and in Figure 1-75 is shown the variation of power flows in interconnection lines of Kosovo.

Figure 1-74 Active power flows on 400kV interconnection lines of Kosovo

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Figure 1-75 Plot of the electrical power of 750MW unit of Kosovo C

1.7.8.2.4

Fault on 400 kV Kosovo C – Skopje (MK)

No stability problems are found after that the three phase fault applied on the 400 kV line Kosovo C – Skopje (MK) is removed through opening of the faulted line. In Figure 1-76 is illustrated the plot of electrical power of G2 of TPP Kosovo C

Figure 1-76 Plot of the electrical power of 750MW unit of Kosovo C

1.7.8.2.5 Calculation of Critical Clearing Time The critical clearing times have been computed for Kosovo C, Kosovo B and Kosovo A main busbars. Also the critical clearing times have been computed for some main system substations in the SEE region close to the new power station.

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Table 1-86 summarizes the shortest critical clearing times for faults simulated at the selected nodes of the transmission network.

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Table 1-86 Year 2016 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo

1.7.8.3

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A

msec 152 156 298

Unstable generator(s)

msec 154 Unit G1 Kosovo C 158 Unit G1 Kosovo C 300 Unit G2 Kosovo A

Year 2016 Conclusions The simulation of transient behavior of the interconnected system is analyzed for the planned configuration of the 400 kV regional transmission system in 2015. The main reinforcement is a new 400 kV line Kosovo â&#x20AC;&#x201C; Albania.

The dynamic performance tests performed for two options of generation units of Kosovo C: a) the third unit 500 MW and b) the second unit 750 MW has demonstrated that the system was able to maintain stability limits during two extreme load conditions and the Kosovo C does not loss the synchronism. The modeled regional transmission system posses an adequate stability margin related to transient stability performance, current overloads of interconnection lines, oscillatory damping and post-transient voltage. The trip of 750 MW causes frequency deviations that are acceptable and in a few seconds the whole system recovers to satisfactory operating conditions.

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1.7.9

Year 2018 Transient Stability Analysis

1.7.9.1

Option 1 of new plant Kosovo C: Unit sizes 500 MW

1.7.9.1.1

Year 2018 Network configuration without the 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Skopje 4 (MK)

1.7.9.1.1.1

Loss of Generation

The frequency decrease following a sudden trip of a unit, G1 of TPP Kosovo C with initial generation of 500 MW, is reported in the diagram in Figure 1-77.

Figure 1-77 Variation of the frequency following the trip of 500MW of Kosovo C 1.7.9.1.1.2 Fault on 400 kV Kosovo B - Nis (SR)

The power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-78.

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Figure 1-78 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.1.1.3

Fault on 400 kV Kosovo C - Kashar(AL) In Figure 1-79 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo â&#x20AC;&#x201C; Albania is removed through opening of the faulted line. It can be observed that the new unit of Kosovo C remains in synchronism after some oscillations.

Figure 1-79 Rotor Angles of selected generators

The variation of power flows in interconnection lines is shown in Figure 1-80. The line with the highest excursion of power flow is the 400 kV line with Skopje (MK).

Figure 1-80 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.1.1.4

Fault on 400 kV Kosovo C - Peja The results of simulations are reported in Figure 1-81. No stability problems are found but comparing with similar cases in previous years can be observed that rotor angles reach highest value during the first swings.

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Figure 1-81 Plot of the electrical power of 500MW unit of Kosovo C

Figure 1-82 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.1.1.5

Calculation of Critical Clearing Time The critical clearing times have been computed for Kosovo C, Kosovo B and Kosovo A main busbars including some main system substations in the SEE region close to the new power station.

The

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Table 1-87 summarizes the shortest critical clearing times for faults simulated at the selected nodes of the transmission network. It can be noted a decrease of the CCT going to limiting values. The CCT for faults in 400 kV nodes of Kosovo is the lowest in the region.

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Table 1-87 Year 2018 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo Albania Macedonia Greece Serbia

1.7.9.1.2 1.7.9.1.2.1

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A 220kV Koman 400kV Bitola 400kV Kardia 400kV N. Tesla

msec 132 138 272 286 230 374 176

Unstable generator(s)

msec 134 Units Kosovo C 140 Units Kosovo C 274 Units Kosovo C 288 Unit Koman G1 232 Unit Bitola G1 378 Unit Kardia G3 178 Unit N. Tesla G1

Year 2018 Network configuration with the 400 kV line Kosovo C (KS) – Skopje 4 (MK) Fault on 400 kV Kosovo B - Nis (SR)

The power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-83. Comparing with the same disturbance without the new reinforcement, the oscillations of power flows are with less intensity reaching low values.

Figure 1-83 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.1.2.2

Fault on 400 kV Kosovo C - Kashar(AL) The same situation can be observed in case of faults in 400 kV line Kosovo – Albania, Figure 1-84.

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Figure 1-84 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.1.2.3

Fault on 400 kV Kosovo C - Peja

It can be observed an improvement of the situation due to the presence of this reinforcement as is shown in Figure 1-85.

Figure 1-85 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.1.2.4

Calculation of Critical Clearing Time Comparing with the network configuration without a new line Kosovo- Skopje, the CCT are moderately increased but still remain near to critical values, Table 1-88.

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Table 1-88 Year 2018 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A

msec 138 142 302

Unstable generator(s)

msec 140 Units Kosovo C 144 Units Kosovo C 304 Units Kosovo C

1.7.9.2

Option 3 of new plant Kosovo C: third unit 750 MW

1.7.9.2.1

Year 2018 Network configuration without the 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Skopje 4 (MK)

1.7.9.2.1.1

Loss of Generation

The sudden trip of the largest unit, G2 of TPP Kosovo C with initial generation of 750 MW, without any preceding fault has been simulated to check the transient behavior of the transmission system. In the Figure 1-86 are given the plot of the variation of the frequency measured in 400 kV busbars of Kosovo C and Bitola (MK). No considerable frequency drop can be noted and the transient minimum value of the mean frequency is about 49.92 Hz.

Figure 1-86 Variation of the frequency following the trip of 750MW of Kosovo C 1.7.9.2.1.2

Fault on 400 kV Kosovo B - Nis (SR) Analyzing the rotor dynamics of the generator of Kosovo C and other selected generators in the region, following the three phase line fault and line removal , it can be noted in Figure 1-87 that the rotor swings reach the critical angle and first a 750 MW unit of Kosovo C loses synchronism followed by 500 MW unit.

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Figure 1-87 Rotor Angles of selected generators

The loss of synchronism causes heavy oscillations of voltages and power flows as can be observed in Figure 1-88 where the power flows in 400kV interconnection lines of Kosovo are reported.

Figure 1-88 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.2.1.3 Fault on 400 kV Kosovo C - Kashar(AL) In case of a three phase fault applied on the 400 kV line Kosovo B â&#x20AC;&#x201C; Nish the angles of rotors of generators reach to 110 degrees, Figure 1-89. The situation is critical but the generators remains in synchronism.

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Figure 1-89 Rotor Angles of selected generators

1.7.9.2.1.4

Fault on 400 kV Kosovo C - Peja The same situation can be observed in case of a fault in 400 kV line Kosovo- Pej as indicated in Figure 1-90 and the maximum angles of generators of Kosovo C pass the 110 degree.

Figure 1-90 Plot of the angles and electrical power of 750MW unit of Kosovo C

1.7.9.2.1.5

Calculation of Critical Clearing Time The critical clearing times, (Table 1-89) have been computed for Kosovo C, Kosovo B and Kosovo A main busbars. The CCT for faults in 400kV nodes of Kosovo C is less than the minimal accepted value of 130 msec. This is another synthetic indicator demmostrating that the system has reached and overpassed the boundary of stability region. Table 1-89 Year 2018 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A

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msec 128 132 258

Unstable generator(s)

msec 130 Unit G2 Kosovo C 134 Unit G2 Kosovo C 260 Units Kosovo C

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Year 2018 Network configuration with the 400 kV line Kosovo C (KS) – Skopje 4 (MK) Fault on 400 kV Kosovo B - Nis (SR) The introduction of a new line Kosovo- Skopje allows maintaining transient stability of 750MW units of Kosovo C.

Figure 1-91 Rotor Angles of selected generators

In Figure 1-91 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B – Nish is removed through opening of the faulted line. It can be observed that the new 750 MW unit of Kosovo C remains in synchronism. The power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-92

Figure 1-92 Active power flows on 400kV interconnection lines of Kosovo.

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1.7.9.2.2.2 Calculation of Critical Clearing Time The critical clearing times given in Table 1-90 have been computed for Kosovo C, Kosovo B and Kosovo A main busbars. The CCT for faults in 400kV nodes of Kosovo C is equal to the minimal accepted value of 130 msec. Table 1-90 Year 2018 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo

1.7.9.2.3 1.7.9.2.3.1

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A

msec 130 136 286

Unstable generator(s)

msec 132 Unit G2 Kosovo C 138 Unit G2 Kosovo C 288 Unit G2 Kosovo C

Year 2018 Network configuration with the 400 kV line Nish (SR) – Skopje 4 (MK) Fault on 400 kV Kosovo B - Nis (SR) In Figure 1-93 is illustrated the plot of electrical power of G1 of TPP Kosovo C after that the three phase fault applied on the 400 kV line Kosovo B – Nish is removed through opening of the faulted line. The 750 MW unit of Kosovo C lose synchronism but compared with the case without the line the only difference is that the second unit does not lose synchronism immediately but after some oscillation.

The reinforcement of the network with the line Nish – Skopje is less effective that a new line Kosovo – Skopje.

Figure 1-93 Rotor Angles of selected generators

The asynchronous oscillations of the power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-94 1.7.9.2.3.2

Calculation of Critical Clearing Time The calculation of the critical clearing times confirms the results of time domain simulations. The CCTs for three phase faults in 400 kV busbars of Kosovo C are presented below and are less then the accepted values of 130 msec.

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Table 1-91 Year 2018 Critical Clearing Times CCT Country Busbar tstable tinstable Kosovo

400 kV Kosovo C 400 kV Kosovo B 220 kV Kosovo A

msec 128 132 260

Unstable generator(s)

msec 130 Unit G2 Kosovo C 134 Unit G2 Kosovo C 262 Unit G1 Kosovo C

Figure 1-94 Active power flows on 400kV interconnection lines of Kosovo.

1.7.9.2.4

Year 2018 Conclusions The year 2018 is assumed to be the year when all generating units of Kosovo C will be in operation. Two options of Kosovo C have been tested concerning the stability of the system with respect to severe disturbances through time domain dynamic simulations.

Transient stability is ensured for Option 1 with four units of 500 MW even in case of the most severe disturbances without loss of synchronism, and return to steady state. The calculation of the critical clearing time to the most critical location in the network (400 kV busbars of Kosovo C) confirms such results. On the other hand, the time domain simulations of regional power system clearly demonstrate that the system is unstable for the Option 3 of Kosovo C with a 500 MW unit and two 750MW units and, applying the same set of severe disturbances, is found that the Kosovo power system has not sufficient dynamic stability margins. The calculation of the critical clearing time confirms this result. Two variants of network reinforcement were analyzed to increase the transient stability of the system: a) introduction of a new 400 kV line Kosovo – Skopje and b) a new 400 kV line Nish – Skopje. A moderate improvement has been observed for the first case but the situation remained at the limit of stability. The second reinforcement does not have any impact and the Kosovo C remains still unstable for the considered disturbances. Apart of network reinforcements, to enhance the transient stability and increase the stability margins in 2018, the new power plant has to be provided with adequate

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automatic controls (AVR and speed governors) and adequate relay protection schemes including the outgoing lines in terms of their speed of action.

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Year 2020 Transient Stability Analysis

The calculations concerning the transient stability of the system with respect to severe disturbances are performed through time domain dynamic simulations only for Option 1 of new power plant , configuration with four 500 MW units. 1.7.10.1

Year 2020 Network configuration without the 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Skopje 4 (MK)

1.7.10.1.1

Loss of Generation

The sudden trip of one or two units of TPP Kosovo C with initial generation of 500 MW, without any preceding fault has been simulated to check the transient behavior of the transmission system. The results are illustrated in the diagrams given in Figure 1-95. In the Figure are given also the plot of the variation of the frequency in Kardia (GR)..

units of

Figure 1-95 Frequency variation following the trip of one (a) and two (b) Kosovo C

1.7.10.1.2

Fault on 400 kV Kosovo B - Nis (SR)

The power flows in 400kV lines of Kosovo are reported in

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Figure 1-96.

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Figure 1-96 Active power flows on 400kV interconnection lines of Kosovo. 1.7.10.1.3

Fault on 400 kV Kosovo B - Skopje (MK)

The power flows in 400kV interconnection lines of Kosovo are reported in Figure 1-97.

Figure 1-97 Active power flows on 400kV interconnection lines of Kosovo. 1.7.10.1.4

Fault on 400 kV Kosovo C - Kashar(AL)

The variation of power flows in interconnection lines is shown in Figure 1-98.

Figure 1-98 Active power flows on 400kV interconnection lines of Kosovo.

1.7.10.1.5

Fault on 400 kV Kosovo C - Peja

The variation of power flows in interconnection lines is shown in Figure 1-99.

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Figure 1-99 Active power flows on 400kV interconnection lines of Kosovo.

1.7.10.1.6

Calculation of Critical Clearing Time The maximum time of permanence of a three phase fault in the 400 kV busbars of Kosovo C is 0.14 sec.

1.7.10.2

Year 2020 Network configuration with the 400 kV line Kosovo C (KS) â&#x20AC;&#x201C; Skopje 4 (MK)

1.7.10.2.1

Fault on 400 kV Kosovo C - Kashar(AL)

The variation of power flows in interconnection lines is shown in Figure 1-100.

Figure 1-100 Active power flows on 400kV interconnection lines of Kosovo.

1.7.10.2.2

Calculation of Critical Clearing Time Due to network reinforcement the maximum time of permanence of a three phase fault in the 400 kV busbars of Kosovo C is increased to 0.145 sec.

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1.7.10.3

Year 2020 Network configuration with the 400 kV line Nish (SR)-Leskovac (SR) â&#x20AC;&#x201C; Skopje 5 (MK)

1.7.10.3.1

Fault on 400 kV Kosovo C - Kashar(AL)

The variation of power flows in interconnection lines is shown in Figure 1-101.

Figure 1-101 Active power flows on 400kV interconnection lines of Kosovo.

1.7.10.3.2

Fault on 400 kV Kosovo C - Skopje(MK)

The variation of power flows in interconnection lines is shown in Figure 1-102.

Figure 1-102 Active power flows on 400kV interconnection lines of Kosovo.

1.7.10.3.3

Fault on 400 kV Kosovo C - Peja

The variation of power flows in interconnection lines is shown in Figure 1-103.

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Figure 1-103 Active power flows on 400kV interconnection lines of Kosovo.

1.7.10.3.4

Calculation of Critical Clearing Time The maximum time of permanence of a three phase fault in the 400 kV busbars of Kosovo C is 0.14 sec. This value is equal with the CCT case without network reinforcement.

1.7.10.4

Year 2020 Conclusions The transient stability analysis in year 2020 concerning the configuration of new power plant with four units 500MW has been performed to check if the system is able to withstand the consequences of a severe disturbance avoiding the loss of synchronism, and to return to steady state. Analyzing the rotor dynamics of the generators following the line fault, we can conclude that the system was able to maintain stability limits and the generation unit of Kosovo C does not loss the synchronism. The modeled regional transmission system posses an adequate stability margin related to transient stability performance.

The unit trip causes frequency deviations that are negligible and in a few seconds the whole system recovers to satisfactory operating conditions.

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General Conclusions of Transient Stability

Assuming the following time schedule regarding transmission network reinforcement: o New 400 kV line Kosovo C (KS) – Kashar (AL) in service in 2012; o New 400 kV line Kosovo C (KS) – Skopje 4 (MK) in service in 2018; o New 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR) in operation in 2018 or earlier.

The general conclusions of transient stability analysis are: Option 1.

The digital simulations of the interconnected regional power system demostrate that transient stability is ensured for Option 1 with four units of 500 MW even in case of the most severe disturbances without loss of synchronism. Option 2

The digital simulations of interconnected regional power system clearly demonstrate that the system is unstable when the first unit 600 MW enters in service and show that the Kosovo power system has not sufficient dynamic stability margins. Analyzing the rotor dynamics of the generators following the line fault, it can be noted that during peak load conditions the rotor swings reach the critical angle and the 600 MW unit of Kosovo C losses the synchronism even in case of network reinforcement. Option 3

System is unstable for the Option 3 of Kosovo C with a 500 MW unit and two 750MW units (2018) and applying the same set of severe disturbances it is found that the Kosovo power system has not sufficient dynamic stability margins. Situation remained at the limit of stability for Option 3 even in case of introduction of a new 400 kV line Kosovo – Skopje in 2018. A new 400 kV line Nish – Skopje does not have any impact in improving the dynamic behaviour and the Kosovo C remains still unstable for the considered disturbances. So the Consultant’s recommended option for Kosovo C is the Option 1 with four units of 500 MWnet each.

1.7.12 Reserve Considerations (added November) Primary Control Reserve

To ensure network security in the UCTE synchronous grid, after the most severe outage considered, the total needed Primary Control Reserve is pre-determined at a value of 3000 MW (see Figure 1). For an acceptable frequency deviation of 200 mHz this leads to a generation characteristic of 15000 MW/Hz, on average. For this goal, all generators on which Primary Control Reserve is allocated should obviously be in service. The Primary Control Reserve must be physically distributed as evenly as possible between the different regions. According to Grid Code of KOSTT, in the Kosovan power system frequency and active power control shall be provided by the following means: • Automatic response from generating units operating in a free European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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governor frequency sensitive mode (Primary Reserve); • Automatic generation control of generating units equipped with automatic load frequency control (Secondary Reserve); • Demand control (part of Tertiary Reserve) The estimation of the KOSTT’ Primary Control Reserve

Figure 1 Present distribution of Primary Control Reserve in UCTE Table 1 Zone 1 Geographical Distribution of Reserves Control Area ELIA RWE REE RTE GRTN ELES HEP JPCC TenneT APG REN ETRANS CEPS MAVIR PSE-O Burstun Island SEPS HTSO EMS+EPCG MEPSO KESH NEK Transeletrica KKEK TOTAL

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Country B D E F I SLO HR BiH NL A P CH CZ H PL UA SK GR CS MK AL BG RO KS

Primary Reserve MW 97 704 351 634 327 15 14 13 109 62 53 77 90 37 163 9 34 57 42 6 6 43 60 10 3013

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Secondary Control Reserve

The goal of Secondary Control Reserve is to restore frequency and cross – border ex-change to the set values and therefore also to free up the Primary Reserve within 15 minutes after the occurrence of an imbalance. The Secondary Control Reserve is activated within the automatic process of the Load Frequency Control. According to UCTE rules, the amount of Secondary Control Reserve needed is determined by each TSO on its own on the basis of the individual situation within the CONTROL AREA / BLOCK. The reserve amount must be sufficient to follow the rules / requirements concerning Load – Frequency Control as defined in the UCTE Operation Handbook, Policy 1. Concerning the amount of reserve needed, there is only a minimum requirement in the UCTE Operation Handbook that corresponds with the control of the load noise. In CONTROL AREAS / BLOCKS of different sizes, load variations of varying magnitude must be corrected in less than 15 minutes. To this end, the recommended minimum reserve related to load variations should be based according to the following formula:

R = aLmax + b2 − b R = the recommendation for SECONDARY CONTROL RESERVE in MW Lmax = the maximum anticipated load in MW for the CONTROL AREA / BLOCK The parameters a and b are established empirically with the following values for the UCTE: a = 10 MW and b = 150 MW The same formula is introduced in KOSTT Grid Code. Tertiary Control Reserve

According to UCTE rules, each CONTROL AREA / BLOCK must have access to sufficient Tertiary Reserve to follow up Secondary Control within a short period of time after an incident. An adequate control reserve must be available at all times to cover the loss of a generating unit. If the loss of the largest generating unit is not already covered by the requisite Secondary Control Reserve, a Tertiary Control Reserve (minute reserve) will be required to offset the shortfall. Tertiary Control is any automatic or manual change in the working points of generators or loads participating. Changes may be achieved by: • • • •

connection and tripping of power stations, increasing or reducing the output of generators in service; redistributing the output from generators participating in secondary control; changing the power interchange programme between interconnected undertakings; load control (e.g. centralised telecontrol or controlled LOAD-SHEDDING).

There are two different modes of Tertiary Control Reserve activation: •

Schedule Activated Tertiary Control Reserve: The Tertiary Control Reserve is activated with relation to a pre - defined time frame of exchange schedules, e.g. 15 min.

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Directly Activated Tertiary Control Reserve: The Tertiary Control Reserve can be activated at any time, independent from a time frame of to exchange schedules. The activation procedure results in a dynamically changing exchange pattern. The Secondary Control Reserve is activated within the automatic process of the Load Frequency Control whereas the Directly Activated Tertiary Control Reserve is a manually activated exchange schedule.

Estimation of the KOSTT’s reserve requirements

According to Grid Code of KOSTT, in the Kosovan power system frequency and active power control shall be provided by load control using the ABC rota load shedding for normal day-to-day operation and other demand control means as detailed in the demand control code for emergency situations. The amount of Tertiary Control Reserve in the Kosovan power system is estimated to be sufficient to compensate for the loss of the largest generating unit connected to the power system and the tertiary control may be obtained from the following measures: a) Generating units in the Kosovan power system; b) Dispatchable loads in the Kosovan power system; c) Other power systems. In the following table is reported the summary of the estimation of the amounts of the control reserve for different scenarios of the new thermo power plant Kosovo C. Having in mind the particularities of the Kosovo power system and the levels of possible exports, the Consultant has estimated the requirements regarding the amounts of Tertiary Control Reserve based on the options b) and c) foreseen in the Grid Code of KOSTT. Two estimations are performed for the tertiary reserve, the first one considering the load shedding and by updating the total exchanges schedule (exports), and the second one based on the controlled load shedding as a direct activated Tertiary Control Reserve. Table 2 KOSTT’s reserve requirements KOSTT’ reserve requirements

Existing Kosovo Power System

Existing Kosovo System and one 500 MW unit 10 197

Existing Kosovo System and two 320 MW units 10(1) 203

Existing Kosovo System and two 500 MW units

Primary Reserve MW 6 Secondary Reserve MW 182 Tertiary Reserve reducing 300 (3) 50 (3) MW 340 (2) Export Tertiary Reserve maintaining MW 340 (2) 600 (5) 350 (5) Export (1) to be revised according to UCTE recommandation at future year where two units will be in operation (2) Load Shedding (3) Load Shedding and a manually activated exchange schedule (null export) 4) Load Shedding and manually activated exchange schedule (reduction of export to 150 MW) (5) Load Shedding (export 300 MW) (6) Load Shedding (export 650 MW)

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10(1) 209 210(4) 560(6)

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REFERENCES

1. 2. 3. 4. 5. 6. 7.

UCTE Operation Handbook– Policy 1: Load-Frequency Control and Performance 2006 KOSTT: Grid Code - Balancing Code. UCTE Group Geographical Distribution of Reserves: Basic Framework and Current State July 2005 UCTE Group Geographical Distribution of Reserves: Border – Crossing Exchange of Primary Control Reserve July 2005 UCTE Group Geographical Distribution of Reserves: Border – Crossing Exchange of Secondary Control Reserve July 2005 UCTE Group Geographical Distribution of Reserves: Border – Crossing Exchange of Directly activated Tertiary Control Reserve July 2005 UCTE Group Geographical Distribution of Reserves: Border – Crossing Exchange of Schedule activated Tertiary Control Reserve July 2005

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Short circuit analysis (Part of the Subtask 2.2 of ToR)

The objective of short-circuit study is the assessment of the impact of the new power plant Kosovo C on projected levels of short-circuit currents at the busbars of the Kosovo and other SEE countries. The aim is detection the busbars where the total short-circuit current exceeds the permissible value imposed by circuit breaker duties. A detailed short circuit study is carried out for the years 2012, 2014, 2016 and 2018 taking into consideration the new plant and other interconnection reinforcements over the study period. 1.8.1

Methodology and main assumption In order to define the maximum short-circuit currents of the transmission system of Kosovo and SEE regional interconnected system, all network components are considered in operation as well as all generating units available for power production during peak load conditions.

The maximum r.m.s. symmetrical subtransient component of the total short-circuit current is provided for a three-phase and single phase to earth faults applied in turn to each 400 kV, 220 kV up to 110 kV busbar. To this scope power generation units are considered with their subtransient reactance X"d. According to IEC standard calculation method, the detailed results of shortcircuit calculations for all substations’ busbars including the level of short circuits currents and other related values are provided in Annex 6. The short-circuit currents are evaluated under no-load conditions (no currents from/to loads and shunt devices connected to the systems) and zero fault impedance. According to IEC 909 standard, for each short-circuit case, the network has been reduced to the Thevenin's equivalent network and a value of 1.1 bus-bar nominal voltage has been used for the Thevenin's equivalent generator. The Table 0-1 reports the main technical characteristics such as breaking capacity of circuit breakers currently installed in Kosovo power system. Table 0-1 Breaking Capacity of installed circuit breakers in Kosovo Rated Voltage kV 420 245 123 123 123 123 123 123 123

1.8.1.1

Rated Current kA 2,000 2,000 2,000 1,250 1,250 2,000 1,250 1,000 600

Breaking Capacity of Circuit-breakers kA MVA 40 27,713 31.5 12,003 40 7,621 6,700 5,000 3,500 3,500 2,500 2,500

Short circuit calculation Year 2012 The detailed results of short-circuit calculations for all substations’ busbars of Kosovo including the level of short circuits currents up to 110 kV level and other related values are provided in Annex 6 . The three-phase and single phase to earth short circuits are calculated for three variants of sites of the TPP Kosovo C and

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connections to transmission network and are given in Annex 6 in Table A6.1 to Tables A6.2. 1.8.1.2

Short circuit calculation: Year 2014 The detailed results of short-circuit calculations for all substations’ busbars of Kosovo including the level of short circuits currents up to 110 kV level and other related values are provided in Annex 6. The three-phase and single phase to earth short circuits are calculated for three variants of sites of the TPP Kosovo C and connections to transmission network and are given in Annex 6 in Table A6.3 to Tables A6.4.

1.8.1.3

Short circuit calculation: Year 2016 The detailed results of short-circuit calculations for all substations’ busbars of Kosovo including the level of short circuits currents up to 110 kV level and other related values are provided in Annex 6. The three-phase and single phase to earth short circuits are calculated for three variants of sites of the TPP Kosovo C and connections to transmission network and are given in Annex 6 in Table A6.5 to Tables A6.6.

1.8.1.4

Short circuit calculation: Year 2018 The detailed results of short-circuit calculations for all substations’ busbars of Kosovo including the level of short circuits currents up to 110 kV level and other related values are provided in Annex 6. The three-phase and single phase to earth short circuits are calculated for three variants of sites of the TPP Kosovo C and connections to transmission network and are given in Annex 6 in Table A6.7 to Tables A6.8.

1.8.1.5

Summary of short circuit calculation The maximum values of short-circuit currents and their locations are calculated for 400 kV and 220 kV buses of Kosovo network and given in Table 0-2. The table summarizes the increase of maximum three-phase short circuit level over the study period and for all variants of new plant connection. From results obtained it is found that location of the maximal short circuit level is at 220kV busbars of Kosovo B in case of Variant 2 of connection of Kosovo C. Table 0-2 Kosovo maximum short circuit currents Variant 1

Year

Variant 2

Three-phase Bus Name

2014

Kosovo C 400 Kosovo C 220 Kosovo C 400 Kosovo C 220

Ik" kA 22.54 30.21 25.30 30.02

2016

Kosovo C 400 Kosovo C 220

27.59 19,111 32.42 12,354

2018

Kosovo C 400 Kosovo C 220

30.29 20,983 22.48 8,565

2012

Sk MVA 15,613 11,513 17,525 11,438

Singlephase Bus Name Ik" kA 23.66 Kosovo B 400 32.54 Kosovo B 220 27.44 Kosovo B 400 32.31 Kosovo B 220 Kosovo B 220(*) 30.65 Kosovo B 400 34.84 Kosovo B 220 Kosovo B 220(*) 34.11 Kosovo B 400 24.36 Kosovo B 220 Kosovo B 220(*)

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Variant 3

Three-phase Ik" kA 22.80 30.13 25.28 30.89 27.43 27.56 33.54 29.24 30.49 33.71 29.38

Sk MVA 15,795 11,482 17,516 11,772 10,451 19,091 12,779 11,143 21,122 12,847 11,196

Singlephase Bus Name Ik" kA 24.15 Kosovo B 400 31.71 Kosovo B 220 27.54 Kosovo B 400 32.75 Kosovo B 220 29.08 30.63 Kosovo B 400 35.65 Kosovo B 220 31.00 34.37 Kosovo C 400 35.99 Kosovo B 220 31.22

Sk MVA 15,848 11,724 17,533 11,634

Singlephase Ik" kA 24.06 32.57 27.19 32.44

27.41 18,991 33.09 12,607

29.84 35.16

30.35 21,026 33.25 12,669

34.22 35.44

Three-phase Ik" kA 22.88 30.77 25.31 30.53

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Additional calculation were performed opening the double line 220 kV connecting Kosovo B with Kosovo C and the results are including in the table (*). The level of short circuit currents is reduced. 1.8.1.6

Conclusion The short circuit levels are going to grow over the study period in Kosovo transmission network due to the introduction of the new generating units of Kosovo C. The level of short circuit current depends from the variant of connection of the new plant to the existing transmission network but the differences are more evident for the 220 kV network (see Variant 2)

On the basis of the results obtained from short circuit calculation conclusion is that regarding the 400 kV transmission networks the levels of short circuit currents remain within the breaking capacities of installed circuit breakers. The levels of short circuit currents are expected to be very high in 220 kV network of Kosovo B exceed the breaking capacity of the installed circuit breakers and in order to ensure an adequate reliability, is recommended to study the replacement some existing 220 kV circuit breakers.

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Cost Estimate of transmission network reinforcements

The cost estimate is based on estimation done in pre-feasibility studies, if they exist, and on the basis of prevailing prices and latest at the time analysis. A) 400 kV line Kosovo C (KS) – Kashar (AL)

The total estimated costs are summarized and presented in Table 2.94. The summary is given for the three sections of the 400 kV interconnection line and the two line’s bays, at two terminals, i.e., at 400 kV Kosovo C substation and 400 kV Kashar substation. The total cost of the line is estimated to be 39.3 M€ where the foreign cost is 24.79 M€ and local cost is 12.51 M€. Table 0-3 Estimated Total Costs of 400 kV line Kosovo C (KS) – Kashar (AL) 400 kV Interconnection Line Project 400 kV line bay cost at Kosovo C S/S 400 kV line bay cost at Kashar S/S First section Kosovo B - Albanian border (85.5 km) Second section Albanian border - Vau Dejes (75.5 km) Third section Vau Dejes – Kashar (78 km) TOTAL

Total Cost

Foreign cost

Local cost

1.000 €

330,0 330,0

205,0 205,0

125,0 125,0

17.111

11.354

5.757

15.110

10.026

5.084

6.418

4.999

1.419

39.299

26.789

12.510

B) 400 kV line Skopje 4 (MK)- Leskovac (SR) - (Nis)(SR)

The total estimated costs are summarized and presented in Table 2.95. The summary is given for the 400 kV interconnection line and costs at two terminals, i.e., at 400 kV Nis 2 substation and 400 kV Skopje substation. The total cost of the line with a total length of 195 km, is estimated to be 40.3 M€ where the foreign cost is estimated 26.75 M€ and local cost is 13.54 M€. Table 0-4 Estimated Total Costs of 400 kV line Nis – Leskovac (SR) - Skopje(MK) 400 kV Interconnection Line Project 400 kV line bay cost & other costs at Nis S/S 400 kV line bay cost & other costs at Skopje S/S 400 kV line Nis –Leskovac (Vranje) – Skopje (195 km) TOTAL

Total Cost

Foreign cost

Local cost

1.000 €

650,0

410,0

240,0

650,0

410,0

240,0

39.000

25.935

13.065

40.300

26.755

13.545

C) New 400 kV line Kosovo C (KS) – Skopje 4 (MK)

The total estimated costs are summarized and presented in Table 2.96. The summary is given for the 400 kV interconnection line and costs at two terminals, i.e., at 400 kV Kosovo C substation and 400 kV Skopje substation. The total cost of the line with a total length of 110.2 km, is estimated to be 22.7 M€ where the foreign cost is estimated 15.06 M€ and local cost is 7.63 M€.

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Table 0-5 Estimated Total Costs of 400 kV line Kosovo C (KS) – Skopje 4 (MK) 400 kV Interconnection Line Project 400 kV line bay cost at Kosovo C S/S 400 kV line bay cost at Skopje S/S 400 kV line Kosovo C -Skopje (110.2 km) TOTAL

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Total Cost

Foreign cost

Local cost

1.000 € 330,0 330,0 22.040

1.000 € 205,0 205,0 14.657

1.000 € 125,0 125,0 7.383

22.700

15.067

7.633

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Recommendations regarding reinforcements of national 220 kV, 110 kV transmission network

The KOSTT has provided the data of the planned configuration of Kosovo transmission network (220kV and 110 kV). Compare to the actual configuration many new substations and network reinforcements are introduced into planned transmission and sub-transmission network, and the most important are the new 400/110 kV substation of Peja 3 and the new 220/110 kV substation of Ferizaj 2 The introduction of two substations together with reinforcements of some parts of 110 kV network, has resolved many problems related to reliability of the local network and improved the voltage profiles. Consultant has proposed some reinforcements for 220 kV and 110 kV national transmission network for each target year. The connection of new TPP Kosovo C with local 220 kV network has improved the distribution of power flows in transmission network. Majority of proposed reinforcement are not related to the construction of new TPP Kosovo C, but became necessary due to growth of the load in some areas and increase of power injections from 400/110 kV Peja 3 and 220/110 kV Ferizaj 2 substations. Further investigation should be performed during activities of transmission network planning in order to obtaine optimal solutions for development of national transmission network up to 2020. The proposed reinforcements are briefly given in the following: 1. Target years 2012-2014: • Reinforcement of 110 kV connection between substations of Prizren 1 and Prizren 2; • Reinforcement of 110 kV connection between substations of Kosovo A and Vushtria; • Reinforcement of 110 kV connection between substations of Peja 3 and Peja 1 and Peja 2; 2. Target year 2016: • Second transformer 150 MVA at 220/110 kV substation of Ferizaj 2; • Reinforcement of 110 kV connections between Ferizaj 2 – Ferizaj 1 and Shtimje substations. 3. Target years 2018-2020: • Second transformer 300 MVA at 400/110 kV substation of Peja 3. 4. The levels of short circuit currents are expected to be very high in 220 kV network, exceeding the breaking capacity of the installed circuit breakers and is recommended to study the replacement some existing 220 kV circuit breakers. 5. Circuit breakers of new 400/220 kV substation of Kosovo C to be commissioned, must possess adequate breaking capacity based on the calculated levels of short circuit current.

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Recommendations regarding Protection and Equipment specification

The results of network analysis mainly dynamic and short circuit studies (Critical Clearing Times, Short Circuit Calculations and Breaking Capacity) must be considered during the phase of preparation of the technical specification of the new power plant Kosovo C. Technical specification of a new protection relay system and control systems of new plant (Primary Controllers, Voltage Controllers, Power System Stabilizers, etc) control is a very important task in order to achieve an optimal network operation. For example the protection features definition significantly depends on location of relays in the network and not only on the characteristics of the single component (line, transformer, generator, etc.) to be protected. The aim of technical specification is to give an indication as clear as possible of the necessary requirements in order to: • ensure the adequate performance to the involved devices; • guarantee the compatibility with other devices interacting with the protection (e.g. breakers, measuring transformers, data acquisition systems, etc.); • guarantee the setting co-ordination with all the other protection system in the network; • improve the network reliability by optimally detecting component anomalies. The technical specification must take into account the characteristics of the interconnected network and specific steady-state and transient operating condition of the new power plant in order improve the relay functional behaviour. In the following, a possible detailed index for a numerical transmission line protection technical specification is proposed. Scope and Application field Reference documents and standards General characteristics of the electrical system General description of the protection functions Distance protection : a) Protection zone requirements ; Zone 1,2,3 and 4 requirements ; Extended zone and zone extension requirements ; Starting, Operating times and Release time; b) Minimum operation current requirements and Measuring precision; c) Trip command requirements; d) Protection behavior with overload, following manual line breaker reclosing and Functional requirements with respect to external auto-reclosure unit 6. High resistance earth fault protection a) Operating principle; b) Measuring precision and Release time; c) Trip command requirements, Protection behavior following manual line breaker reclosing and Functional requirements with respect to external autoreclosure unit 7. Teleprotection schema requirements of Distance protection and High resistance earth fault protection 8. Power swing blocking function

1. 2. 3. 4. 5.

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REFERENCES 8. REBIS:GIS Volume 2 Electricity Demand Forecast December 2004. 9. REBIS:GIS Volume 3 Generation and Transmission Study December 2004. 10. REBIS:GIS Volume 6 PSSE Appendix December 2004. 11. Update of generation investment study, Report by the World Bank Group , contract no 713 8967, by South East Europe Consultants, Belgrade, 2007 Summary report and Main report) 12. Energy Sector Technical Assistance Project ESTAP, WB study Consortium CESI, EIMV, Ramboll, RE, 2002 13. Albania Energy Sector Study, World Bank Project, Consortium DECON, EdF, LDK, 2003 14. Pre-feasibility study report “Interconnection line 400 kV between Kosovo and Albania, launched by KEK and carried out by IEE (Institut za Elektroprivredu i Energetiku), Zagreb, November 2001. 15. Feasibility Study Update of 400 kV Transmission line Elbasan – Tirana – Podgorica, Fichtner, 2003 16. Feasibility Study of 400 kV Transmission line Elbasan – Tirana – Podgorica, Fichtner, 2001 17. The SECI Regional Electricity Interconnection Planning Study Final Report; (February 2003). 18. Review of Electricity Supply and demand in South East Europe. Prepared by EKC Belgrade, 2004 19. Electricity Supply for Kosovo - Medium to Long Term Strategy for the Improvement of the Power Generation in Kosovo, KfW study STEAG Consortium, 2001 20. Kosovo Electric Power System Development Strategy, Energy Strategy and Policy Committee, 2002 21. TEN-E Priority Projects, EC 22. Design Option For Implementation of A Coordinated Transmission Open Discussion Paper - First Draft-February 2002 23. Coordinated use of Power Exchanges for Congestion Management in Continental Europe: Market Design and Role of Power Exchanges Open Discussion paper Draft -February 2002 24. ETSO Comments on the European Commission's discussion document "Congestion Management" Rome 8-9 July 2003 25. ETSO position on the "Co-coordinated Cost" cross-border capacity allocation proposal February 2003 26. Coordinated Congestion Management an ETSO Vision - February 2002 27. Evaluation of congestion management methods for cross-border transmission. Florence Regulators Meeting 11/1 999 28. Outline proposals for a Coordinated Congestion Management Scheme based on the ETSO Vision September 2002 29. Position Paper on Congestion Management Florence Forum, May 7th &9th, 2001 April 30th 2001 30. Reconciliation of market splitting with coordinated auction concepts Technical issues -Draft Discussion Paper February 2002 31. Draft Guidelines for Congestion Management, EC, 2006 ("Electricity cross-border Committee opinion on draft congestion management guidelines after the written procedure which ended 8 June 2006") European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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32. [ETSO TF/NACMPF SG, Overview of currently applied methods for crossborder transmission capacity allocation in South-east Europe - situation October 2005 33. Regulation on Cross-Border Exchanges in Electricity 1228/2003 34. Congestion Management methods in SEE and work status of the Coordinated Auctions dry-run simulation - situation SETSO TF October 2006

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Disclaimer

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Table of Contents 1.

ANNEX 1 STATISTICAL ANALYSIS OF 400 KV TRANSMISSION NETWORK4

2. ANNEX 2 PLANNED DEVELOPMENT OF GENERATION AND TRANSMISSION NETWORK IN SEE ........................................................................ 9 3.

ANNEX 3 STEADY STATE ANALYSIS ............................................................ 21

ANNEX 4 TRANSFER CAPABILITY CALCULATION RESULTS.................... 34

ANNEX 5 TRANSIENT STABILITY ANALYSIS ............................................... 69

1.1

Generators Data..........................................................................................................69

1.2

Voltage regulators and excitation systems ...............................................................79

1.3

Check of the Excitation’s system performance........................................................ 80

1.4 Check of the Governor’s performance ..................................................................... 83 Introduction .......................................................................................................................... 83 Governors implemented in the Data Base: ........................................................................... 83 6.

ANNEX 6 RESULTS OF SHORT CIRCUIT CALCULATION............................ 92

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1. Annex 1 Statistical Analysis of 400 kV transmission network

Figure A 1.1 Period 2000-2006 Energy wheeling through Kosovo transmission network

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Figure A 1.2 Period 2000-2006 Maximum and Minimum Power flows Kosovo transmission network

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Average

Annual Energy Export

MWh 74,023 998,208

Annual Energy Import

18.5

% 47.4 92.5

Max Daily

0.80

% 9.45 0.02

Annual Average Export

2.34

% 1.65 22.20

Annual Average Import

Average

Annual Energy Export

Annual Energy Import

47.1

% 84.0 120.6

Max Daily

8.71

% 33.18 0.03

Annual Average Export

6.78

% 0.01 50.37

Annual Average Import

Load Factor Min Daily Import

105,353

400 kV Interconnection Line Loadability Year 2000 Energy Transit

Table A 1.1 Year 2000 Statistical data on Loadability of 400 kV transmission system Kosovo

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Interconnection Line

Max Daily Export

MWh 424,800 794

Annual Net Average

35,817

Max

-191

MWh 961 -2,733

Natural Capacity

-5,744

MWh -4,098 -11,362

MWh 5,819 531

MW -316 -538

2,276

-328

-8

MW 354 190

MW 40 -114

211

-239

MW 512 512

Active Power Transit Max Max Daily Daily Min Average Average Export Import MW MW 242 -171 22 -473

512

Min Daily Import

305,111

MWh 547 2,265,160

Min Daily Import

MWh 4,595 -8,663

Average

MWh 1,677,403 0

Annual Energy Export

MWh 206 3,161,957

Annual Energy Import

% 117.8 118.6

Max Daily

% 37.30 0.00

Annual Average Export

% 0.00 70.31

Annual Average Import

Load Factor Max Daily Export

MWh 1,492,286 1,168

400 kV Interconnection Line Loadability Year 2001 Energy Transit

Table A 1.2 Year 2001 Statistical data on Loadability of 400 kV transmission system Kosovo

400 kV Kosovo B â&#x20AC;&#x201C; Skopje L420 400 kV Kosovo B - Nish L407 400 kV Kosovo B - Ribarevina L437

Interconnection Line

Annual Net Average

391,630

Max

237

MWh 4,087 -6,203

Natural Capacity

-7,557

MWh -547 -14,818 241

MWh 10,321 572

MW -142 -819

5,793

-393

MW 628 190

MW 170 -258 361

-315

MW 512 512

Active Power Transit Max Max Daily Daily Min Average Average Export Import MW MW 430 -23 24 -617

512

Max Daily Export

MWh -123 -14,573

Load Factor Annual Net Average

MWh 14,478 -1,498

2.98

Max

MW 191 -361

19.58

Natural Capacity

Active Power Transit Max Max Daily Daily Min Average Average Export Import MW MW 603 -5 -62 -607

61.2

MW -174 -823

133,840

MW 729 71

880,581

MW 512 512

2,046

314

-4,401

-310

7,524

416

512

-183

400 kV Interconnection Line Loadability Year 2002 Energy Transit

Table A 1.3 Year 2002 Statistical data on Loadability of 400 kV transmission system Kosovo

400 kV Kosovo B - Skopje L420 400 kV Kosovo B - NishL407 400 kV Kosovo B - Ribarevina L437

Interconnection Line

400 kV Kosovo B - Skopje L420 400 kV Kosovo B - Nish L407 400 kV Kosovo B - Ribarevina L437

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Natural Capacity

620

Max

-743

-160

247

455

-226

-500

-20

-301

186

5,921

10,927

-5,414

-12,006

-473

1,541

-7,214

4,458

745,501

1,628,062

183,116

2,633,046

887

MWh

Annual Energy Import

48.2

97.7

88.9

Max Daily

16.58

0.00

36.20

Annual Average Export

4.07

58.55

0.02

Annual Average Import

Load Factor

November, 2007 Page 7 (96)

Table A 1.4 Year 2003 Statistical data on Loadability of 400 kV transmission system Kosovo

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Interconnection Line

512 72 -320

400 kV Interconnection Line Loadability Year 2003 Active Power Transit Energy Transit Max Max Annual Max Min Annual Daily Daily Min Average Net Daily Daily Energy Average Average Average Export Import Export Export Import MW MW MW MWh MWh MWh MWh

512 354

Annual Energy Import

Max Daily

Annual Average Export

Annual Average Import

Load Factor

512

Max

65.95

Natural Capacity

288

0.03

4.85

0.01

1,848,402

103.5

14.85

% 5,063

2,965,909

54.0

% 619

1,131

217,939

41.10

10,679

-8,123

667,820

% 211

-12,719

1,233

86.9

-1,952

-3,391

MWh 445

-338

6,633

-58

-530

-81

-141

708

-641

276

-287

512 512

525

Annual Energy Import

Annual Average Export

Annual Average Import

Load Factor Annual Energy Export

Energy Transit Min

Power Transit

Interconnection Line Loadability Year 2005

Table A 1.6 Year 2004 Statistical data on Loadability of 400 kV transmission system Kosovo

512

Table A 1.5 Year 2004 Statistical data on Loadability of 400 kV transmission system Kosovo

400 kV Kosovo B - Skopje L420 400 kV Kosovo B - Nish L407 400 kV Kosovo B - Ribarevina L437

Interconnection Line

400 kV Kosovo B - Skopje L420 400 kV Kosovo B - Nish L407 400 kV Kosovo B Ribarevina L437

400 kV Line

Max

0.00 51.06

Natural Capacity

12.33

% 62.16 0.00

1.31

58,731

554,560

-263

135 2,795,643 0 -783 0 2,296,214

MWh

474 -123

MWh 512 512

512

MW Kosovo B - Skopje Kosovo B - Nish

Kosovo B - Ribarevina

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512

Natural Capacity

387

491

Max

-144

-630

-218

304

-152

399

-38

-579

-335

243

7,295

-3,650

9,566

-904

-13,904

1,993

-8,031

5,833

744,056

2,129,511

16,630

2,931,466

596

MWh

Annual Energy Import

59.4

113.2

77.8

Max Daily

16.54

0.00

47.35

Annual Average Export

0.37

65.18

0.01

Annual Average Import

Load Factor

512

400 kV Interconnection Line Loadability Year 2003 Active Power Transit Energy Transit Max Max Annual Annual Max Min Daily Daily Average Min Energy Net Daily Daily Average Average Export Average Export Import Export Import MW MW MW MWh MWh MWh MWh

Table A 1.7 Year 2006 Statistical data on Loadability of 400 kV transmission system Kosovo

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Interconnection Line

400 kV Kosovo B - Skopje L420 400 kV Kosovo B - Nish L407 400 kV Kosovo B Ribarevina L437

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2. Annex 2 Planned development of generation and transmission network in SEE Table A 2.1 List of interconnection lines in South East Europe Year 2005 Interconnection line Zemlak – Kardia V.Dejes - Podgorica Fierze - Prizren Kosovo B - Nis Kosovo B - Ribarevina Mostar4 - Konjsko Ugljevik - Ernestinovo Gradacac - Djakovo Prijedor - Mraclin Mostar4 - Zakucac Prijedor2 - Medjuric TE Tuzla - Djakovo Trebinje - HE Dubrovnik Trebinje - HE Dubrovnik Trebinje - HE Perucica Sarajevo20 - HE Piva** Visegrad - Pozega Blagoevgrad - Lagad (Thesaloniki) Varna - Isaccea* Dobruja - Isaccea Kozlodui - Tintareni (double) Sofia - Nis Maritsa Istok - Hamitabat Maritsa Istok - Babeski Arachtos - Galatina HVDC Zerjavinec - Heviz (double) Zerjavinec - Cirkovce Gyor - Wien Sud (double) Gyor - Wien Sud Gyor - Neusiedl God - Levice Gyor - Gabcikovo Albertirsa - Zapadoukrainska Dubrovo - Thessaloniki Skopje - Kosovo B Skopje - Kosovo A Skopje - Kosovo A Podgorica - Trebinje Arad - Sandorfalva Isaccea - Vulcanesti* Portile de Fier - Djerdap Isaccea - Pivdenoukrainska* Rosiori - Mukachevo S. Mitrovica - Ernestinovo Subotica - Sandorfalva Maribor - Keinchtal (double) Podlog - Obersielach Divaca - Meline Krsko - Tumbri (double) Divaca - Pehlin Divaca - Redipuglia Divaca - Padriciano Mukachevo - Sajoszeged Mukachevo - Kisvarda Mukachevo - Tiszalok (Source REBIS GIS Volume 6)

Interconnected countries AL - GR AL - MN AL - KS KS - SR KS - MN BA - HR BA - HR BA - HR BA - HR BA - HR BA - HR BA - HR BA - HR BA - HR BA - MN BA - MN BA - SER BG - GR BG - RO BG - RO BG - RO BG - SER BG - TR BG - TR GR - IT HR - HU HR - SI HU - AT HU - AT HU - AT HU - SK HU - SK HU - UA MK - GR MK - KS MK - KS MK - KS MN - BA RO - HU RO - MOLD RO - SER RO - UA RO - UA SER - HR SER - HU SI - AT SI - AT SI - HR SI - HR SI - HR SI - IT SI - IT UA - HU UA - HU UA - HU

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Voltage level (kV) 400 220 220 400 400 400 400 220 220 220 220 220 220 220 220 220 220 400 750 400 400 400 400 400 400 400 220 400 220 220 400 400 750 400 400 220 220 400 400 400 400 750 400 400 400 400 220 400 400 220 400 220 400 220 220

Conductors Size (mm2) ACSR 2x500 ACSR 360 ACSR 360 ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR 360 ACSR 360 ACSR 360 ACSR 360 ACSR 360 ACSR 2x240 ACSR 2x240 ACSR 360 ACSR 2x490 ACSR 360 ACSR 2x500 ACSR 5x300 ACSR 3x400 ACSR 500/300 ACSR 2x500 ACSR 3x400 ACSR 2x500 HVDC ACSR 2x490 ACSR 360 ACSR 2x500 ACSR 360 ACSR 360 ACSR 2x500/ 3x350 ACSR 2x500/ 3x450 ACSR 5x400 ACSR 2x490 ACSR 2x490 ACSR 360 ACSR 360 ACSR 2x490 ACSR 450/500 ACSR 3x400 ACSR 2x967 ACSR 5x400 ACSR 2x450 ACSR 2x490 ACSR 2x490 ACSR 2x490 ACSR 490 ACSR 2x490 ACSR 2x490 ACSR 490 ACSR 2x490 ACSR 490 ACSR 2x490 ACSR 400 ACSR 400 Type

Transfer Capacity (MVA) 1309 301 301 1330 1330 1318 1318 300 300 300 300 300 491 491 301 366 301 1309 2390 1715 2490 1330 1715 1309 500 1318 300 2563 305 305 1440 1440 5360 1330 1330 301 301 1330 1212 1715 1330 5360 1212 1330 1330 1330 366 1318 1318 350 1330 366 1386 308 308

length km I to border 21 47 26 39.8 73 41 39 19 49 34 65 7 7 20 61 18 72 150 81 14 37 59 50 / 99 19 59 59 55 88 29 268 55 36 18 18 60 5 5 1 5 39 41 27 26 46 41 16 47 39 10 8 54 97

border to II 80 21 45 84.6 53.1 69 53 27 66 50 32 27 5 5 42 23 51 102 85 150 102 86 90 77 / 69 51 63 63 27 36 15 254 60 68 65 65 21 52 54 2 395 36 52 21 37 20 26 32 6 10 2 142 10 35

total 101 68 71 124.4 126.1 110 92 46 66 99 66 92 12 12 63 84 69 174 235 231 116 123 149 127 0 168 70 122 122 82 124 44 522 115 104 82 82 81 57 59 3 400 75 93 48 63 65 66 48 53 49 11 150 64 132

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 10 (96)

Table A 2.2 Generation development plan of the updated GIS study Year

Peak Load

Rehabilitation TPP Turceni N. Tesla A4

MW 272 280

2007

28,553

2008 2009

28,927 29,234

N. Tesla A6 Paroseni 4

280 120

2010

29,649

Varna 1

200

2011

30,242

Varna 2

200

2012

30,864

2013

31,535

Varna 3 N. Tesla B1 Varna 4

200 580 200

2014

32,282

2015

33,151

Varna 5 N. Tesla B2 Varna 6

200 580 200

Bitola 1

207

2016 2017

34,072 35,026

Kostolac B1 Bitola 2

320 207

2018

36,002

Kostolac B2

320

2019

37,024

2020 Total

38,049

Bitola 3

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

207 4,573

New capacity TPP Bucharest Sud Bucharest Sud Cernovoda 2 Bucharest West G1 Vlora Maritsa Est 1 G1 Maritsa Est 1 G2 Bucharest West G2 Cernovoda 3 Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Belene Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP

MW Country 100 Romania 100 Romania 664 Romania 100 Romania 132 Albania 275 Bulgaria 275 Bulgaria 100 Romania 664 Romania 480 Albania 480 480 480 480 480 480 930Bulgaria 480Croatia 480Croatia 480 480

Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP Combined Cycle TPP

288Macedonia 288 480Bulgaria 480

Combined Cycle TPP Lignite Sub Critical Kolubara B G1 Kolubara B G2 Imported Coal Supercritical Lignite Sub Critical Lignite Sub Critical Imported Coal Supercritical Combined Cycle TPP Lignite Sub Critical Imported Coal Supercritical Lignite Sub Critical Imported Coal Supercritical Imported Coal Supercritical

480Romania 450 320 320 470 450 450 470 288 450 470 450 470 470 16,164

November, 2007 Page 11 (96)

2005 MW 1,518 1,055 1,881 6,452 2,912 1,418 714 7,414 5,928

2006

10,787

MW 1,565 1,081 1,902 6,497 3,007 1,401 717 7,500 5,923

2007

11,240

MW 1,585 1,107 1,952 6,517 3,101 1,389 719 7,623 5,979

2008

11,690

MW 1,618 1,130 2,006 6,518 3,196 1,379 722 7,768 5,986

2009

12,134

MW 1,652 1,154 2,076 6,482 3,290 1,373 725 7,950 5,993

2010

12,546

MW 1,719 1,171 2,114 6,591 3,400 1,405 727 8,148 6,073

2011

12,923

MW 1,775 1,189 2,178 6,699 3,510 1,455 730 8,382 6,153

2012

13,246

MW 1,842 1,212 2,247 6,752 3,619 1,501 732 8,639 6,233

2013

13,577

MW 1,922 1,235 2,321 6,861 3,729 1,552 735 8,918 6,313

2014

13,849

MW 1,989 1,270 2,410 7,025 3,838 1,607 737 9,234 6,393

2015

14,126

MW 2,099 1,291 2,481 7,162 3,960 1,667 747 9,604 6,464

2016

14,408

MW 2,220 1,312 2,568 7,256 4,082 1,730 757 10,011 6,534

2017

14,696

MW 2,352 1,333 2,659 7,301 4,204 1,797 767 10,448 6,604

2018

14,990

MW 2,493 1,355 2,766 7,351 4,326 1,870 777 10,915 6,674

2019

15,290

MW 2,645 1,377 2,855 7,340 4,448 1,946 787 11,418 6,745

2020

2015

2016

2020

10,304

MW 1.922 1.235 2.321 6.861 3.729 10.081 1.552 735 8.918 6.313 2.459 6.659 43.666

MW 1.922 1.235 2.321 6.555 3.729 11.554 1.552 735 8.166 6.313 1.822 8.284 4.934 33.877 44.081

MW 1.989 1.270 2.410 7.025 3.838 10.400 1.607 737 9.234 6.393 2.500 6.840 44.903

MW 1.989 1.270 2.410 7.025 3.838 11.920 1.607 737 9.234 6.393 1.852 8.364 5.068 34.215 46.423

MW 2.099 1.291 2.481 7.162 3.960 10.702 1.667 747 9.604 6.464 2.539 6.973 46.177

MW 2.099 1.291 2.481 6.843 3.960 12.266 1.667 747 8.794 6.464 1.881 8.445 5.166 34.547 46.611

MW 2.352 1.333 2.659 7.301 4.204 11.332 1.797 767 10.448 6.604 2.618 7.246 48.798

MW 2.352 1.333 2.659 6.975 4.204 12.988 1.797 767 9.567 6.604 1.940 8.608 5.369 35.221 49.247

MW 2.645 1.377 2.855 7.340 4.448 12.000 1.946 787 11.418 6.745 2.700

7.530

51.561

MW 2.645 1.377 2.855 7.013 4.448 13.753 1.946 787 10.455 6.745 2.001 8.773 5.579 35.907 52.024

System Network System Network System Network System Network System Network Peak Model Peak Model Peak Model Peak Model Peak Model

2014

Table A 2.4 Peak power forecast for target years Network Model MW 1.775 1.189 2.178 6.400 3.510 10.856 1.455 730 7.675 6.153 1.762 8.126 4.753 33.209 41.921

2018

MW 1,484 1,030 1,863 6,383 2,817 1,360 711 7,372 5,957

41.543

6.310

MW 1.775 1.189 2.178 6.699 3.510 9.472 1.455 730 8.382 6.153 2.378

System Peak

2012

9,837

Table A 2.3 Peak power forecast in South East Europe

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Peak Albania Kosovo BiH Bulgaria Croatia Macedonia Montenegro Romania Serbia Grecia

Albania Kosovo Bosnia Bulgaria Croatia Greece Macedonia Montenegro Romania Serbia Slovenia UCTE Hungary Turkey SEE

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 12 (96)

Table A 2.5 Minimum power forecast for target years Network Model

System Min

MW 988 560 1.117 3.348 2.018 8.442 755 399 5.549 2.906 1.474 6.542 4.134 26.768 26.081

Network Model

MW 1.164 606 1.256 3.670 2.224 9.077 856 409 6.622 2.968 1.520 6.668 4.296 27.289 28.853

System Min

MW 1.164 606 1.256 3.506 2.224 9.077 856 409 6.064 2.968 1.520 6.668 4.296 27.289 28.131

Network Model

2020

System Min

MW 988 560 1.117 3.504 2.018 8.442 755 399 6.060 2.906 1.474 6.542 4.134 26.768 26.748

2018

Network Model

MW 798 490 1.017 3.148 1.822 7.973 667 381 4.925 2.780 1.420 6.418 3.978 26.256 23.999

2016

System Min

MW 798 490 1.017 3.295 1.822 7.973 667 381 5.378 2.780 1.420 6.418 3.978 26.256 24.600

2015

Network Model MW 686 432 964 3.020 1.689 7.629 579 369 4.650 2.685 1.399 6.315 3.902 26.004 22.702

2014

System Network System Min Model Min MW 686 432 964 3.161 1.689 7.629 579 369 5.079 2.685 1.399 6.315 3.902 26.004 23.271

MW 555 347 837 2.752 1.540 6.750 494 351 4.501 2.108

MW 653 420 905 2.884 1.641 7.279 543 360 4.410 2.462 1.375 6.255 3.799 26.085 21.557

20.235

MW 555 347 837 2.629 1.540 6.750 494 351 4.121 2.108 1.347 6.138 3.660 25.571 19.733

MW 653 420 905 3.019 1.641 7.279 543 360 4.816 2.462 1.375 6.255 3.799 26.085 22.098

2012

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Albania Kosovo Bosnia Bulgaria Croatia Greece Macedonia Montenegro Romania Serbia Slovenia UCTE Hungary Turkey SEE

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

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Table A 2.6 Year 2012 Loads at HV nodes at substation in Albania Code AB1A411 AB2A411 AB3A411 ABCA411 ABEA411 ABIA411 ABUA411 ACEA411 ADRA411 AE1A411 AERA411 AF1A411 AF2A411 AF3A411 AFAA411 AFKA411 AFRA411 AGJA411 AGKA411 AGRA411 AIBA411 AK1A411 AK2A411 AK3A411 AK4A411 AK5A411 AK6A411 AK7A411 AK8A411 AK9A411 AKEA411 AKRA411 AKUA411 AL1A411 ALAA411 ALEA411 ALIA411 ALUA411 AMAA411 AMEA411 AP1A411 APEA411 APOA411 APRA411 AQEA411 AR1A411 AREA411 ARRA411 ARUA411 AS1A411 AS4A411 AS5A411 AS6A411 ASEA411 ASHA411 ASUA411 ATEA411 ATIA211 ATIA411

Name ABUSHA5 ABULQI5 ABALSH5 ABCURR5 ABELSH5 ABISTR5 ABURRL5 ACERIK5 ADRENO5 AELBS15 AERSEK5 AFIER 5 AFKRUJ5 AFIBER5 AFARRZ5 AFKUQE5 AFRZVJ5 AGJIRO5 AGKUQ 5 AGRAMS5 AIBE 5 AKALIM5 AKURBN5 AKASH15 AKORCE5 AKAVAJ5 AKAJAN5 AKUCOV5 AKAFAR5 AKRAHS5 AKELCY5 AKRUJE5 AKUKES5 ALAC1 5 ALAC2 5 ALEZHA5 ALIBRZ5 ALUSHN5 AMARIN5 AMEMAL5 APERME5 APESHK5 APOGRD5 APRENJ5 AQENDE5 ARENCI5 AREPSI5 ARRAZB5 ARUBIK5 ASHKD25 ASHUTR5 ASHKZT5 ASELEN5 ASELIT5 ASHKD15 ASUC 5 ATEPEL5 ATIRAN2 ATIRAN5

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Peak condition P Q MW Mvar 7.25 2.33 29.77 11.65 23.30 -13.92 19.42 6.47 5.18 2.59 19.42 9.06 19.42 9.06 32.36 15.53 0.39 0.26 68.60 31.07 2.59 1.04 64.72 -27.84 16.83 7.77 23.30 9.06 22.01 10.36 11.65 9.06 5.83 2.33 31.07 -11.33 3.75 1.04 6.47 3.88 5.18 2.59 9.06 5.18 2.07 1.30 54.36 23.30 62.13 25.89 58.25 25.89 11.65 3.88 71.19 -0.97 7.77 3.88 3.88 2.20 5.44 1.68 12.94 6.47 29.77 -11.33 23.30 9.06 19.42 10.36 32.36 15.53 6.47 1.81 58.25 -0.97 19.42 12.94 10.36 5.18 6.73 2.27 32.36 -13.92 28.48 11.65 6.08 1.55 90.61 38.83 5.44 1.42 4.92 1.17 6.47 2.59 16.83 7.77 49.19 22.01 3.24 0.78 77.66 38.83 38.83 19.42 99.67 45.30 71.19 25.89 5.18 3.75 5.83 2.59 80.25 38.83 55.66 28.48

Min condition P Q MW Mvar 2.27 0.73 9.32 3.65 7.29 -4.36 6.08 2.03 1.62 0.81 6.08 2.84 6.08 2.84 10.13 4.86 0.12 0.08 21.47 9.72 0.81 0.32 20.25 -8.71 5.27 2.43 7.29 2.84 6.89 3.24 3.65 2.84 1.82 0.73 9.72 -3.55 1.18 0.32 2.03 1.22 1.62 0.81 2.84 1.62 0.65 0.41 17.01 7.29 19.44 8.10 18.23 8.10 3.65 1.22 22.28 -0.30 2.43 1.22 1.22 0.69 1.70 0.53 4.05 2.03 9.32 -3.55 7.29 2.84 6.08 3.24 10.13 4.86 2.03 0.57 18.23 -0.30 6.08 4.05 3.24 1.62 2.11 0.71 10.13 -4.36 8.91 3.65 1.90 0.49 28.36 12.15 1.70 0.45 1.54 0.36 2.03 0.81 5.27 2.43 15.39 6.89 1.01 0.24 24.31 12.15 12.15 6.08 31.19 14.18 22.28 8.10 1.62 1.18 1.82 0.81 25.12 12.15 17.42 8.91

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment AUTA411 AUZA411 AV1A411 AV2A411 AVLA411 AVOA411

AUTRAK5 AUZNOV5 AVDEJS51 AVDVJT5 AVLORE5 AVOJNI5

64.72 25.89 0.52 5.44 71.19 6.08

25.89 12.94 0.26 2.85 25.89 2.59

November, 2007 Page 14 (96) 20.25 8.10 0.16 1.70 22.28 1.90

8.10 4.05 0.08 0.89 8.10 0.81

Table A 2.7 Year 2012 Loads at HV nodes at substation in Kosovo Code KBEP411 KCRP411 KD1P411 KD2P411 KD3P411 KDEP411 KDJP411 KDRP411 KFEP211 KFKP411 KG1P411 KG2P411 KGNP411 KHGP911 KHGP912 KISP411 KKLP411 KKVP411 KLIP411 KM1P411 KMAP411 KMIP411 KP0P411 KP2P411 KP3P411 KP4P411 KP5P411 KP6P411 KP7P411 KP8P411 KP9P411 KPOP211 KRAP411 KSHP411 KSRP411 KSUP411 KT1P611 KT2P821 KT2P822 KT2P823 KT2P911 KTKP611 KTKP612 KU1P411 KURP411 KVAP411 KVUP411

Name KBERIV5 KCRKVO5 KDRENA5 KDJAK25 KDJJAN5 KDECAN5 KDJAK15 KDRAGA5 KFERON2 KFKOSO5 KGNJI55 KGNJIL5 KGNJI45 KHGAZIG1 KHGAZIG2 KISTOK5 KKLINA5 KKVITI5 KLIPLJ5 KMALIS5 KMAZGI5 KMITR25 KPRIZ35 KPEC2 5 KPRIS65 KPRIS55 KPEC 5 KPRIS15 KPRIS25 KPRIS35 KPRIZ15 KPODUJ2 KRAHAV5 KSHTIM5 KSREKA5 KSUPKO5 KTKOSCG1 KTKOSAG3 KTKOSAG4 KTKOSAG5 KTKOSAG1 KTKOSBG1 KTKOSBG2 KUROS15 KUROSE5 KVALAC5 KVUCIT5

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Peak condition P Q MW Mvar 17.49 5.83 23.33 7.77 19.44 6.48 29.16 9.72 11.66 3.89 27.21 9.07 34.99 11.66 38.88 12.96 15.55 5.18 19.44 6.48 15.55 5.18 38.88 12.96 17.49 5.83 5.51 2.20 5.51 2.20 17.49 5.83 25.27 8.42 25.27 8.42 46.65 15.55 15.55 5.18 15.55 5.18 29.16 9.72 42.76 14.25 40.82 13.61 19.44 6.48 13.61 4.53 48.60 16.20 58.32 19.44 52.48 17.49 44.71 14.90 48.60 16.20 54.43 18.14 29.16 9.72 27.21 9.07 29.16 9.72 13.61 4.53 30.00 20.00 16.00 10.00 16.00 10.00 16.00 10.00 6.40 3.00 30.00 20.00 30.00 20.00 38.88 12.96 44.71 14.90 48.60 16.20 38.88 12.96

Min condition P Q MW Mvar 5.13 1.71 6.84 2.28 5.70 1.90 8.55 2.85 3.42 1.14 7.98 2.66 10.26 3.42 11.40 3.80 4.56 1.52 5.70 1.90 4.56 1.52 11.40 3.80 5.13 1.71 1.62 0.65 5.13 7.41 7.41 13.68 4.56 4.56 8.55 12.54 11.97 5.70 3.99 14.25 17.10 15.39 13.11 14.25 15.96 8.55 7.98 8.55 3.99 30.00

1.71 2.47 2.47 4.56 1.52 1.52 2.85 4.18 3.99 1.90 1.33 4.75 5.70 5.13 4.37 4.75 5.32 2.85 2.66 2.85 1.33 20.00

30.00 30.00 11.40 13.11 14.25 11.40

20.00 20.00 3.80 4.37 4.75 3.80

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 15 (96)

Table A 2.8 Year 2012 Loads at HV nodes at substation in Montenegro Peak condition P Q Code JA1N411 JBAN411 JBEN411 JBUN411 JCEN411 JDAN411 JETN411 JHNN411 JKAN411 JMON411 JNIN411 JP1N411 JP2N411 JP3N411 JP4N411 JPLN811 JRIN411 JTIN411 JULN411

Name JANDRI51 JBAR 51 JBERAN51 JBUDVA51 JCETIN51 JDANIL51 JETREB51 JHNOVI51 JKAP 51 JMOJKO51 JNIKSI51 JPODG151 JPLJEV51 JPODG351 JPODG451 JTPLJEG1 JBPOLJ51 JTIVAT51 JULCIN51

MW 5.87 39.92 27.00 23.48 27.00 9.39 0.90 36.40 199.59 10.57 69.18 73.87 31.61 53.92 37.48 14.45 21.13 31.61 16.44

Mvar 3.52 9.39 9.39 7.04 8.13 4.70 0.45 11.65 79.47 5.87 30.53 19.96 9.39 5.87 7.04 9.93 7.04 8.13 4.70

Min condition P Q MW 2.83 19.22 13.00 11.30 13.00 4.52 0.44 17.52 96.08 5.09 33.30 35.56 15.22 25.95 18.04 6.96 10.17 15.22 7.91

Mvar 1.70 4.52 4.52 3.39 3.91 2.26 0.22 5.61 38.26 2.83 14.69 9.61 4.52 2.83 3.39 4.78 3.39 3.91 2.26

Table A 2.9 Year 2012 Loads at HV nodes at substation in Macedonia Code AERH411 BERH411 BI1H411 BI2H411 BI3H411 BUCH411 CNTH411 DELH411 DRAH411 FENH411 G-BH411 GEVH411 GO1H411 GOSH411 G-PH411 ISTH411 JU1H411 JUGH411 KA1H411 KAVH411 KICH411 KOCH411 KOZH411 K-PH411 KU1H411 KU2H411 KUMH411 K-VH411 MADH411 M-KH411

Name AERODROM BEROVO BITOLA 1 BITOLA 3 BITOLA 4 BUCIM CNTRLN DELCEVO DRACEVO FENI G.BABA GEVGELIJ GOSTIV 2 GOSTIVAR G.PETROV ISTOK JUGOHROM JUG NOVA KAVADA 2 KAVADARC KICEVO KOCANI KOZLE K.PALANK KUMAN 2 KUMAN 3 KUMAN 1 K.VODA MADZAR M.KAMENI

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Peak condition P Q MW Mvar 33.03 11.89 5.90 2.63 9.49 3.43 37.89 13.56 16.91 6.06 11.41 4.31 18.35 6.62 6.30 2.87 13.96 5.03 65.25 32.47 31.59 11.33 23.69 8.86 8.38 3.03 28.56 10.29 37.49 13.40 13.24 4.71 77.46 18.67 19.86 7.10 18.19 6.54 3.91 1.44 17.23 6.54 27.36 10.53 35.98 12.92 11.89 5.34 21.46 7.66 21.46 7.66 28.56 10.29 11.01 3.99 20.58 7.42 9.09 4.07

Min condition P Q MW Mvar 11.21 4.03 2.00 0.89 3.22 1.16 12.86 4.60 5.74 2.06 3.87 1.46 6.23 2.25 2.14 0.97 4.74 1.71 22.15 11.02 10.72 3.85 8.04 3.01 2.84 1.03 9.69 3.49 12.73 4.55 4.49 1.60 26.29 6.34 6.74 2.41 6.17 2.22 1.33 0.49 5.85 2.22 9.29 3.57 12.21 4.39 4.03 1.81 7.28 2.60 7.28 2.60 9.69 3.49 3.74 1.35 6.99 2.52 3.09 1.38

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment NEGH411 OH1H411 OHRH411 O-PH411 OSLH411 PETH411 POLH411 PR1H411 PR2H411 PR3H411 PRIH411 PROH411 RADH411 RAFH411 RESH411 SAMH411 SK1H411 SK2H411 SK3H411 SK4H411 SOPH411 SPIH411 ST1H411 ST2H411 ST3H411 STIH411 STRH411 SUSH411 SUVH411 TE1H411 TEAH411 TETH411 TO1H411 TOPH411 USJH411 VALH411 V-BH411 VE1H411 VE2H411 VELH411 V-GH411 VRUH411 ZAPH411 ZGRH411 ZLZH411

NEGOTINO OHRID 2 OHRID 1 O.POLE OSLOMEJ PETROVEC POLOG PRILEP 2 PRILEP 3 PRILEP 4 PRILEP 1 PROBISTI RADOVIS RAFINERI RESEN SAMOKOV SK 1 SK 2 SK 3 SK 4 SOPOTNIC SPILJE STIP 2 STRUM 1 STRUM 2 STIP 1 STRUGA SUSICA SUVODOL TETOVO 2 TEARCE TETOVO 1 TOPAANA TOPILNIC USJE VALANDOV V.BOLNIC VELEC C VELES 2 VELES V.GLAVIN VRUTOK ZAPAD ZGROPOLC ZLZ-SVR

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

14.20 11.25 31.43 9.49 3.27 13.24 12.76 15.63 10.45 10.45 13.08 15.40 9.49 2.47 10.69 3.27 32.55 21.46 5.74 0.72 5.98 9.89 12.44 21.94 11.09 17.15 30.87 6.14 14.68 17.31 10.93 49.38 20.58 6.54 8.14 6.38 21.30 17.63 9.81 9.81 36.69 1.99 34.54 2.47 138.80

5.11 3.43 9.57 3.43 1.28 4.71 4.63 5.90 3.91 3.91 4.87 5.74 3.43 0.80 3.83 1.20 11.57 7.50 1.20 0.24 2.15 3.51 4.47 7.90 3.99 6.14 11.09 2.23 5.90 6.22 3.91 17.71 7.42 2.07 3.43 2.63 7.66 6.94 3.83 3.83 13.16 0.72 12.36 0.56 48.26

November, 2007 Page 16 (96) 4.82 3.82 10.67 3.22 1.11 4.49 4.33 5.31 3.55 3.55 4.44 5.23 3.22 0.84 3.63 1.11 11.05 7.28 1.95 0.24 2.03 3.36 4.22 7.45 3.76 5.82 10.48 2.09 4.98 5.88 3.71 16.76 6.99 2.22 2.76 2.17 7.23 5.98 3.33 3.33 12.45 0.68 11.72 0.84 47.11

1.73 1.16 3.25 1.16 0.43 1.60 1.57 2.00 1.33 1.33 1.65 1.95 1.16 0.27 1.30 0.41 3.93 2.55 0.41 0.08 0.73 1.19 1.52 2.68 1.35 2.09 3.76 0.76 2.00 2.11 1.33 6.01 2.52 0.70 1.16 0.89 2.60 2.36 1.30 1.30 4.47 0.24 4.20 0.19 16.38

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 17 (96)

Table A 2.10 Year 2018 Loads at HV nodes at substation in Albania Code AB1A411 AB2A411 AB3A411 ABCA411 ABEA411 ABIA411 ABUA411 ACEA411 ADRA411 AE1A411 AERA411 AF1A411 AF2A411 AF3A411 AFAA411 AFKA411 AFRA411 AGJA411 AGKA411 AGRA411 AIBA411 AK1A411 AK2A411 AK3A411 AK4A411 AK5A411 AK6A411 AK7A411 AK8A411 AK9A411 AKEA411 AKRA411 AKUA411 AL1A411 ALAA411 ALEA411 ALIA411 ALUA411 AMAA411 AMEA411 AP1A411 APEA411 APOA411 APRA411 AQEA411 AR1A411 AREA411 ARRA411 ARUA411 AS1A411 AS4A411 AS5A411 AS6A411 ASEA411 ASHA411 ASUA411 ATEA411 ATIA211 ATIA411

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Peak condition P Q MW Mvar 9.61 3.08 39.46 10.00 30.88 -20.00 25.74 8.58 6.86 3.43 25.74 12.01 25.74 10.00 42.89 20.58 0.52 0.35 90.92 41.17 3.43 1.37 85.78 -90.00 22.31 10.29 30.88 12.01 29.17 5.00 15.44 12.01 7.72 3.08 41.17 -30.00 4.98 1.37 8.58 5.15 6.86 3.43 12.01 0.00 2.75 1.72 72.06 30.88 82.35 34.31 77.20 34.31 15.44 5.15 94.35 -1.29 10.29 5.15 5.15 2.91 7.21 2.23 17.15 8.58 39.46 -15.01 30.88 12.01 25.74 13.72 42.89 20.58 8.58 2.40 77.20 -1.29 25.74 17.15 13.72 -10.00 8.92 3.00 42.89 -20.00 37.74 15.44 8.06 2.06 120.09 51.47 7.21 1.88 6.52 1.55 8.58 3.43 22.31 10.29 65.20 29.17 4.29 1.03 102.94 51.47 51.47 25.74 132.10 60.04 94.35 34.31 6.86 4.98 7.72 3.43 106.37 51.47 73.77 37.74

Min condition P Q MW Mvar 4.03 1.30 16.56 6.48 12.96 -7.74 10.80 3.60 2.88 1.44 10.80 5.04 10.80 5.04 18.00 8.64 0.22 0.14 38.16 17.28 1.44 0.58 36.00 -15.49 9.36 4.32 12.96 5.04 12.24 5.76 6.48 5.04 3.24 1.30 17.28 -6.30 2.09 0.58 3.60 2.16 2.88 1.44 5.04 2.88 1.15 0.72 30.24 12.96 34.56 14.40 32.40 14.40 6.48 2.16 39.61 -0.54 4.32 2.16 2.16 1.22 3.02 0.94 7.20 3.60 16.56 -6.30 12.96 5.04 10.80 5.76 18.00 8.64 3.60 1.01 32.40 -0.54 10.80 7.20 5.76 2.88 3.74 1.26 18.00 -7.74 15.84 6.48 3.38 0.86 50.41 21.60 3.02 0.79 2.74 0.65 3.60 1.44 9.36 4.32 27.36 12.24 1.80 0.43 43.21 21.60 21.60 10.80 55.45 25.20 39.61 14.40 2.88 2.09 3.24 1.44 44.65 21.60 30.96 15.84

AUTRAK5 AUZNOV5 AVDEJS51 AVDVJT5 AVLORE5 AVOJNI5

85.78 34.31 0.68 7.21 94.35 8.06

34.31 17.15 0.35 3.78 34.31 3.43

November, 2007 Page 18 (96) 36.00 14.40 0.29 3.02 39.61 3.38

14.40 7.20 0.14 1.58 14.40 1.44

Table A 2.11 Year 2018 Loads at HV nodes at substation in Kosovo Code KBEP411 KCRP411 KD1P411 KD2P411 KD3P411 KDEP411 KDJP411 KDRP411 KFEP211 KFKP411 KG1P411 KG2P411 KGNP411 KHGP911 KHGP912 KISP411 KKLP411 KKVP411 KLIP411 KM1P411 KMAP411 KMIP411 KP0P411 KP2P411 KP3P411 KP4P411 KP5P411 KP6P411 KP7P411 KP8P411 KP9P411 KPOP211 KRAP411 KSHP411 KSRP411 KSUP411 KT1P611 KT1P612 KT1P613 KT2P821 KT2P822 KT2P823 KTKP611 KTKP612 KU1P411 KURP411 KVAP411 KVUP411

Name KBERIV5 KCRKVO5 KDRENA5 KDJAK25 KDJJAN5 KDECAN5 KDJAK15 KDRAGA5 KFERON2 KFKOSO5 KGNJI55 KGNJIL5 KGNJI45 KHGAZIG1 KHGAZIG2 KISTOK5 KKLINA5 KKVITI5 KLIPLJ5 KMALIS5 KMAZGI5 KMITR25 KPRIZ35 KPEC2 5 KPRIS65 KPRIS55 KPEC 5 KPRIS15 KPRIS25 KPRIS35 KPRIZ15 KPODUJ2 KRAHAV5 KSHTIM5 KSREKA5 KSUPKO5 KTKOSCG1 KTKOSCG2 KTKOSCG3 KTKOSAG3 KTKOSAG4 KTKOSAG5 KTKOSBG1 KTKOSBG2 KUROS15 KUROSE5 KVALAC5 KVUCIT5

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Peak condition P Q MW Mvar 19.51 12.19 26.16 8.73 21.80 7.26 32.72 10.91 13.07 4.37 30.53 10.17 39.24 13.07 43.59 14.54 17.43 5.82 21.80 7.26 17.43 5.82 43.59 14.54 19.51 12.19 6.14 2.47 6.06 2.41 19.51 12.19 28.33 9.43 28.33 9.43 52.32 17.43 17.43 5.82 17.43 5.82 32.72 10.91 47.96 15.99 45.78 15.25 21.80 7.26 15.25 5.07 54.51 18.17 65.40 21.80 58.87 19.62 50.15 16.73 54.51 18.17 61.03 20.36 32.72 10.91 30.53 10.17 32.72 10.91 15.25 5.07 30.00 20.00 60.00 40.00 60.00 40.00 16.00 10.00 16.00 10.00 16.00 10.00 30.00 20.00 30.00 20.00 43.59 14.54 50.15 16.73 54.51 18.17 43.59 14.54

Min condition P Q MW Mvar 8.27 2.75 11.04 3.68 9.20 3.06 13.79 4.59 5.52 1.84 12.88 4.30 16.56 5.52 18.40 6.14 7.36 2.46 9.20 3.06 7.36 2.46 18.40 6.14 8.27 2.75 2.62 1.05 8.27 11.95 11.95 22.08 7.36 7.36 13.79 20.24 19.31 9.20 6.43 22.99 27.59 24.83 21.15 22.99 25.75 13.79 12.88 13.79 6.43 30.00 30.00 30.00

2.75 3.99 3.99 7.36 2.46 2.46 4.59 6.74 6.43 3.06 2.15 7.67 9.20 8.27 7.05 7.67 8.58 4.59 4.30 4.59 2.15 20.00 20.00 20.00

30.00

20.00

18.40 21.15 22.99 18.40

6.14 7.05 7.67 6.14

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Table A 2.12 Year 2018 Loads at HV nodes at substation in Montenegro Code JA1N411 JBAN411 JBEN411 JBUN411 JCEN411 JDAN411 JETN411 JHNN411 JKAN411 JMON411 JNIN411 JP1N411 JP2N411 JP3N411 JP4N411 JPLN811 JRIN411 JTIN411 JULN411

Name JANDRI51 JBAR 51 JBERAN51 JBUDVA51 JCETIN51 JDANIL51 JETREB51 JHNOVI51 JKAP 51 JMOJKO51 JNIKSI51 JPODG151 JPLJEV51 JPODG351 JPODG451 JTPLJEG1 JBPOLJ51 JTIVAT51 JULCIN51

Peak condition P Q MW Mvar 6.17 3.70 41.97 9.88 28.39 9.88 24.69 7.41 28.39 8.54 9.88 4.94 0.95 0.48 38.26 12.25 209.83 83.55 11.11 6.17 72.73 32.09 77.67 20.98 33.23 9.88 56.68 6.17 39.40 7.41 15.19 10.44 22.22 7.41 33.23 8.54 17.28 4.94

Min condition P Q MW Mvar 3.21 1.92 21.82 5.13 14.76 5.13 12.83 3.85 14.76 4.44 5.13 2.57 0.49 0.25 19.89 6.37 109.09 43.44 5.77 3.21 37.81 16.68 40.38 10.91 17.28 5.13 29.47 3.21 20.48 3.85 7.90 5.43 11.55 3.85 17.28 4.44 8.98 2.57

Table A 2.13 Year 2018 Loads at HV nodes at substation in Macedonia Code AERH411 BERH411 BI1H411 BI2H411 BI3H411 BUCH411 CNTH411 DELH411 DRAH411 FENH411 G-BH411 GEVH411 GO1H411 GOSH411 G-PH411 ISTH411 JU1H411 JUGH411 KA1H411 KAVH411 KICH411 KOCH411 KOZH411 K-PH411 KU1H411 KU2H411 KUMH411 K-VH411 MADH411 M-KH411 NEGH411 OH1H411 OHRH411 O-PH411 OSLH411

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Peak condition P Q MW Mvar 40.78 14.68 7.29 3.25 11.72 4.23 46.79 16.75 20.88 7.49 14.09 5.32 22.66 8.18 7.78 3.55 17.24 6.21 80.58 40.10 39.01 13.99 29.26 10.94 10.34 3.74 35.27 12.71 46.30 16.55 16.35 5.81 95.65 23.05 24.53 8.77 22.46 8.08 4.83 1.77 21.28 8.08 33.79 13.00 44.43 15.96 14.68 6.60 26.50 9.46 26.50 9.46 35.27 12.71 13.59 4.93 25.42 9.16 11.23 5.02 17.54 6.31 13.89 4.23 38.81 11.82 11.72 4.23 4.04 1.58

Min condition P Q MW Mvar 17.12 6.16 3.06 1.36 4.92 1.78 19.65 7.03 8.77 3.14 5.92 2.23 9.51 3.43 3.27 1.49 7.24 2.61 33.83 16.83 16.38 5.87 12.28 4.59 4.34 1.57 14.81 5.33 19.44 6.95 6.87 2.44 40.16 9.68 10.30 3.68 9.43 3.39 2.03 0.74 8.93 3.39 14.19 5.46 18.65 6.70 6.16 2.77 11.13 3.97 11.13 3.97 14.81 5.33 5.71 2.07 10.67 3.85 4.71 2.11 7.36 2.65 5.83 1.78 16.30 4.96 4.92 1.78 1.70 0.66

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment PETH411 POLH411 PR1H411 PR2H411 PR3H411 PRIH411 PROH411 RADH411 RAFH411 RESH411 SAMH411 SK1H411 SK2H411 SK3H411 SK4H411 SOPH411 SPIH411 ST1H411 ST2H411 ST3H411 STIH411 STRH411 SUSH411 SUVH411 TE1H411 TEAH411 TETH411 TO1H411 TOPH411 USJH411 VALH411 V-BH411 VE1H411 VE2H411 VELH411 V-GH411 VRUH411 ZAPH411 ZGRH411 ZLZH411

PETROVEC POLOG PRILEP 2 PRILEP 3 PRILEP 4 PRILEP 1 PROBISTI RADOVIS RAFINERI RESEN SAMOKOV SK 1 SK 2 SK 3 SK 4 SOPOTNIC SPILJE STIP 2 STRUM 1 STRUM 2 STIP 1 STRUGA SUSICA SUVODOL TETOVO 2 TEARCE TETOVO 1 TOPAANA TOPILNIC USJE VALANDOV V.BOLNIC VELEC C VELES 2 VELES V.GLAVIN VRUTOK ZAPAD ZGROPOLC ZLZ-SVR

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16.35 15.76 19.31 12.91 12.91 16.16 19.01 11.72 3.05 13.20 4.04 40.19 26.50 7.09 0.89 7.39 12.21 15.37 27.09 13.69 21.18 38.12 7.59 18.13 21.38 13.50 60.98 25.42 8.08 10.05 7.88 26.30 21.77 12.12 12.12 45.32 2.46 42.66 3.05 171.41

5.81 5.71 7.29 4.83 4.83 6.01 7.09 4.23 0.99 4.73 1.48 14.28 9.26 1.48 0.29 2.66 4.33 5.52 9.75 4.93 7.59 13.69 2.76 7.29 7.69 4.83 21.87 9.16 2.56 4.23 3.25 9.46 8.57 4.73 4.73 16.26 0.89 15.27 0.69 59.60

November, 2007 Page 20 (96) 6.87 6.62 8.11 5.42 5.42 6.78 7.98 4.92 1.28 5.54 1.70 16.88 11.13 2.98 0.37 3.10 5.13 6.45 11.37 5.75 8.89 16.01 3.19 7.61 8.98 5.67 25.60 10.67 3.39 4.22 3.31 11.04 9.14 5.09 5.09 19.03 1.03 17.91 1.28 71.97

2.44 2.40 3.06 2.03 2.03 2.52 2.98 1.78 0.41 1.98 0.62 6.00 3.89 0.62 0.12 1.12 1.82 2.32 4.09 2.07 3.19 5.75 1.16 3.06 3.23 2.03 9.18 3.85 1.08 1.78 1.36 3.97 3.60 1.98 1.98 6.82 0.37 6.41 0.29 25.02

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3. Annex 3 Steady State Analysis

Figure A 3.1 Year 2012 Variant 1 of TPP Kosovo C Peak load condition

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Figure A 3.2 Year 2012 Variant 2 of TPP Kosovo C Peak load condition

Figure A 3.3 Year 2012 Variant 3 of TPP Kosovo C Peak load condition

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Figure A 3.4 Year 2012 400kV SEE Regional network Peak load condition

Figure A 3.5 Year 2012 Peak load condition Variant 3 no KS-AL line

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Figure A 3.6 Year 2012 400kV SEE Regional network Peak load condition No KS-AL

Figure A 3.7 Year 2014 Variant 3 of TPP Kosovo C Peak load condition

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Figure A 3.8 Year 2014 400kV SEE Regional network Peak load condition

Figure A 3.9 Year 2014 Peak load condition Variant 3 no KS-AL line

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Figure A 3.10 Year 2014 400kV SEE Regional network Peak load condition No KS-AL

Figure A 3.11 Year 2016 Variant 3 of TPP Kosovo C Peak load condition

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Figure A 3.12 Year 2016 400kV SEE Regional network Peak load condition

Figure A 3.13 Year 2018 Variant 3 of TPP Kosovo C Peak load condition

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Figure A 3.14 Year 2018 400kV SEE Regional network Peak load condition

Figure A 3.15 Year 2018 New 400kV line Kosovo-Skopje Peak load condition

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Figure A 3.16 Year 2018 400kV SEE Regional network New 400kV line Kosovo-Skopje

Figure A 3.17 Year 2018 New 400kV lines Kosovo-Skopje and Nis-Skopje Peak load condition

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Figure A 3.18 Year 2018 400kV SEE Regional network New 400kV lines Kosovo-Skopje and Nis-Skopje

Figure A 3.19 Year 2020 Variant 3 of TPP Kosovo C Peak load condition

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Figure A 3.20 Year 2020 400kV SEE Regional network Peak load condition

Figure A 3.21 Year 2020 New 400kV line Kosovo-Skopje Peak load condition

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Figure A 3.22 Year 2020 400kV SEE Regional network New 400kV line Kosovo-Skopje

Figure A 3.23 Year 2020 New 400kV line Nish-Skopje Peak load condition

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Figure A 3.24 Year 2020 New 400kV lines Kosovo-Skopje and Nis-Skopje Peak load condition

Figure A 3.25 Year 2020 400kV SEE Regional network New 400kV lines Kosovo-Skopje and Nis-Skopje

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4. Annex 4 Transfer Capability Calculation Results Table A 4.1 Year 2012 PTDF Export to Albania no line KS-AL Nr

Line Code

2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067 15 PP26152 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 20.5 32.0 29.5 -28.6 -41.9 -36.3 9.8 20.1 2.0 -2.3 -0.7 -16.6 -7.4 12.7 40.2 29.2 8.6 5.5 6.1 11

Table A 4.2 Year 2012 PTDF Export to Greece no line KS-AL Nr

Line Code

Nome End 1 Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Network Element Nome End 2 Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 21.9 15.3 13.7 -46.8 -10.5 18.8 19.2 38.7 -2.5 -5.6 -2.4 -6.2 -2.2 4.8 -13.2 10.4 0.6 -7.9 15.6 0

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Table A 4.3 Year 2012 PTDF Export to UCTE no line KS-AL Nr

Line Code

Nome End 1 Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 31.1 28.6 27.1 -24.4 9.0 -7.4 6.3 11.7 9.3 -2.0 -0.6 -7.1 5.1 5.8 7.1 14.7 0.8 0.0 0.0 -22

Table A 4.4 Year 2012 LODF Export to Albania no line KS-AL LODF (%) 2 3 4 5 6 7 8 9 10

AN10170 AF10002 PP16147 HP10053 NN10132 HF10147 PM10056 HF10030 AP20065

2 AN10170

3 AF10002 60.7

48.7 27.2 19.3 31.2 -19.7 1.1 -9.0 15.8

-36.4 -39.6 -33.5 42.0 2.6 19.5 26.4

4 PP16147 20.4 -21.3

5 HP10053 11.1 -19.7 -22.0

-29.3 -68.6 15.7 29.3 8.0 -6.5

-18.6 28.1 -34.6 15.6 6.4

6 NN10132 30.5 -25.3 -88.4 -31.6 18.9 33.0 9.6 -17.4

7 HF10147 -7.9 14.0 8.2 19.6 7.7 9.3 55.0 -4.4

8 PM10056 -0.4 5.0 20.7 -46.9 20.8 18.4 10.5 -6.5

Table A 4.5 Year 2012 PTDF Export to Albania Nr

Line Code

1 PA10054 2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067 15 PP26152 1 AA10236 2 NN16110 3 AA20232

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana

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Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709

PTDF % 39.4 12.3 19.3 17.9 -17.1 -25.5 -22.0 5.9 12.1 1.2 -1.4 -0.4 -10.0 -4.5 7.6 24.6 17.8 5.2

9 HF10030 -4.1 7.3 4.6 11.2 4.3 59.3 5.7 -2.4

10 AP20065 32.4 37.5 -13.2 17.8 -35.3 -20.4 -11.7 -10.0

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Line Code 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400

November, 2007 Page 36 (96)

Imax A 2021 2021 1920

PTDF % 3.3 3.7 7

Table A 4.6 Year 2012 PTDF Export to Greece Nr

Line Code

1 PA10054 2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067 15 PP26152 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 15.5 18.6 10.5 9.4 -42.3 -4.4 24.6 17.7 35.5 -2.8 -5.2 -2.3 -3.8 -1.1 2.9 -19.6 6.1 -0.7 -8.7 14.6 -1

Table A 4.7 Year 2012 PTDF Export to UCTE Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

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Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 16.6 27.6 23.4 22.4 -19.6 15.8 -1.5 4.7 8.3 9.0 -1.6 -0.4 -4.5 6.3 3.8 0.6 10.1 -0.6 -0.9 -1.0 -24

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Table A 4.8 Year 2012 LODF Export to Albania LODF (%)

PA10054

AN10170

1 PA10054

-36.7

AF10002 PP16147 HP10053 NN10132

HF10147

PM10056

HF10030

AP20065

-41.2

24.6

-17.2

28.9

8.7

14.3

4.8

-31.6

35.3

29.1

3.8

40.0

-4.3

6.4

-2.2

16.8

-11.0

-25.2

-13.2

16.9

8.4

9.0

24.7 -3.4

2 AN10170

-41.7

3 AF10002

-35.5

27.0

4 PP16147

31.7

32.9

-17.4

5 HP10053

-27.8

5.5

-45.0

-20.0

6 NN10132

29.4

36.0

-16.4

-70.3

7 HF10147

19.7

-8.9

43.9

9.6

30.2

11.7

8 PM10056

19.9

8.4

10.4

21.8

-29.2

24.4

7.2

9 HF10030

9.6

-3.9

20.5

5.0

16.6

6.1

53.1

7.5

10 AP20065

-16.6

7.9

15.5

-2.1

3.4

-11.4

-2.9

-3.6

-15.6

-90.1

5.3

19.1

3.1

-20.9

21.6

-36.7

12.3

9.2

5.1

17.8

2.9

-23.5

12.9

58.1

-13.4

-13.0

4.5

Table A 4.9 Year 2014 PTDF Export to Albania no line KS-AL Nr

Line Code

Nome End 1 Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 20.9 31.9 29.5 -29.1 -41.7 -37.1 10.0 20.6 1.9 -2.6 -0.7 -17.0 -7.4 13.3 40.7 29.1 8.5 5.6 6.3 11.0

Table A 4.10 Year 2014 PTDF Export to Greece no line KS-AL Nr

Line Code

2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067 15 PP26152

Nome End 1 Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Network Element Nome End 2 Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren

Vnom kV 400 400 400 400 400 400 400 400 400 220 220 220 220 220

Imax A 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200

PTDF % 22.4 15.4 13.9 -47.4 -10.6 18.6 19.4 39.2 -2.6 -5.9 -2.5 -6.4 -2.2 5.0

-6.3 -6.5

-1.6

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Line Code 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

November, 2007 Page 38 (96)

Vnom kV 400 400 220 400 400 400

Imax A 1949 1920 709 2021 2021 1920

PTDF % -13.1 10.4 0.6 -7.9 15.8 0.3

Table A 4.11 Year 2014 PTDF Export to UCTE no line KS-AL Nr

Line Code

Nome End 1 Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 30.2 27.3 26.0 -23.6 8.7 -7.0 6.1 11.2 9.1 -2.1 -0.6 -6.8 4.9 5.8 6.8 14.1 0.7 0.0 -0.1 -21.2

Table A 4.12 Year 2014 LODF Export to Albania no line KS-AL LODF (%) 2 3 4 5 6 7 8 9 10

AN10170 AF10002 PP16147 HP10053 NN10132 HF10147 PM10056 HF10030 AP20065

2 AN10170 49.4 25.4 20.2 29.9 -20.3 0.4 -9.3 17.0

3 AF10002 60.7 -36.3 -40.4 -33.4 42.8 3.1 19.7 27.7

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

4 PP16147 20.2 -21.1 -29.0 -68.2 15.6 29.0 7.9 -6.5

5 HP10053 10.9 -19.1 -21.8 -18.5 27.8 -35.0 15.4 6.5

6 NN10132 30.2 -24.9 -88.5 -31.2 18.6 32.7 9.5 -17.3

7 HF10147 -8.0 14.1 8.4 19.6 7.9 9.5 55.1 -4.6

8 PM10056 1.1 2.3 25.4 -39.8 22.6 15.1 8.5 -5.6

9 HF10030 -4.1 7.2 4.7 11.3 4.4 59.5 5.8 -2.5

10 AP20065 42.3 46.7 -5.4 17.6 -42.8 -25.1 -4.8 -12.7

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 39 (96)

Table A 4.13 Year 2014 PTDF Export to Albania Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1919.993

PTDF % 39.2 12.5 19.3 18.1 -17.4 -25.5 -22.5 6.0 12.4 1.1 -1.5 -0.4 -10.3 -4.5 8.0 24.9 17.8 5.3 3.4 3.8 6.6

Table A 4.14 Year 2014 PTDF Export to Greece Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1919.993

PTDF % 15.5 19.1 10.7 9.6 -42.8 -4.5 24.5 17.8 35.9 -2.9 -5.4 -2.4 -4.0 -1.1 3.1 -19.6 6.2 -0.7 -8.7 14.8 -1.3

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 40 (96)

Table A 4.15 Year 2014 PTDF Export to UCTE Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

PTDF

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1919.993

% 15.9 26.8 22.5 21.6 -19.0 15.2 -1.4 4.6 8.1 8.7 -1.7 -0.5 -4.4 6.0 3.8 0.6 9.8 -0.5 -0.9 -1.0 -23.1

Table A 4.16 Year 2014 LODF Export to Albania LODF (%)

PA10054

AN10170

1 PA10054

-39.1

AF10002 PP16147 HP10053 NN10132

HF10147

PM10056

HF10030

AP20065

-41.7

24.0

-17.0

28.3

8.9

14.6

4.8

-31.6

36.8

28.8

3.8

39.7

-4.4

8.1

-2.2

17.0

-11.1

-24.7

-13.2

17.2

4.6

9.1

25.9

2 AN10170

-41.2

3 AF10002

-36.3

27.1

4 PP16147

31.5

35.2

-19.2

5 HP10053

-28.3

5.4

-44.5

-19.8

6 NN10132

29.2

37.7

-18.1

-70.0

-13.0

7 HF10147

20.1

-8.8

43.9

9.6

29.9

11.6

8 PM10056

20.2

8.5

9.4

21.6

-29.6

24.3

7.5

9 HF10030

9.8

-3.8

20.5

5.0

16.3

6.0

53.1

4.9

10 AP20065

-16.9

6.8

18.5

-2.3

3.6

-11.3

-3.1

-1.5

-15.6

-90.3

5.5

23.8

3.2

-3.8

-20.7

21.8

-29.5

12.6

10.3

5.3

18.4

3.1

-23.9

9.1

58.2

-14.1

4.7

Table A 4.17 Year 2016 PTDF Export to Albania Nr

Line Code

1 PA10054 2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790

PTDF % 39.7 14.9 20.9 19.1 -20.1 -26.4 -24.5 6.7 13.8 1.4 -1.5 -0.4 -10.9 -5.6

-7.0 -6.9

-1.7

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Line Code

15 PP26152 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 220 400 400 220 400 400 400

November, 2007 Page 41 (96)

Imax A 1200 1949 1920 709 2021 2021 1919.993

PTDF % 8.0 25.0 18.2 5.1 3.7 4.2 7.0

Table A 4.18 Year 2016 PTDF Export to Greece Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1919.993

PTDF % 15.7 20.4 11.2 9.9 -44.7 -4.6 23.9 18.2 36.9 -2.9 -5.4 -2.4 -4.1 -1.4 3.1 -19.5 6.3 -0.7 -8.6 15.0 -1.2

Table A 4.19 Year 2016 PTDF Export to UCTE Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021

PTDF % 16.2 28.4 23.4 22.2 -20.3 15.3 -1.8 4.8 8.6 9.1 -1.6 -0.5 -4.4 5.8 3.8 0.7 10.0 -0.5 -0.9 -1.0

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Line Code 6 CN10019

Nome End 1 Trebinie

Network Element Nome End 2 Podgorica

November, 2007 Page 42 (96)

Vnom kV 400

PTDF

Imax A 1919.993

% -23.4

Table A 4.20 Year 2016 LODF Export to Albania LODF (%)

PA10054

AN10170

1 PA10054

-40.0

AF10002 PP16147 HP10053 NN10132

HF10147

PM10056

HF10030

AP20065

-38.6

24.4

-17.1

28.0

8.8

13.8

4.6

-32.3

35.0

28.3

3.7

39.4

-4.3

7.1

-1.9

21.1

-12.3

-24.5

-12.6

17.5

8.4

9.9

32.0

2 AN10170

-40.5

3 AF10002

-35.1

27.2

4 PP16147

30.7

36.7

-16.1

5 HP10053

-26.1

5.5

-50.0

-22.3

6 NN10132

28.3

38.7

-15.5

-70.1

-13.0

7 HF10147

18.5

-8.9

46.5

10.7

30.1

11.4

8 PM10056

18.4

8.6

14.8

24.1

-30.7

24.4

7.4

9 HF10030

8.9

-3.7

21.7

5.5

16.4

5.9

52.8

6.5

10 AP20065

-16.0

6.7

15.9

-2.3

3.3

-10.8

-2.8

-2.2

-15.8

-90.3

5.3

19.5

2.6

-3.3

-20.7

22.3

-33.8

13.4

12.6

17.1

2.6

-28.4

11.1

57.9

-17.7

5.1

4.2

Table A 4.21 Year 2018 PTDF Export to Albania Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 38.8 16.1 20.9 19.0 -21.3 -27.0 -25.3 7.1 14.7 1.7 -1.9 -0.5 -11.5 -6.1 8.4 25.3 18.1 5.3 3.8 4.3 7.7

-6.8 -8.7

-1.1

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 43 (96)

Table A 4.22 Year 2018 PTDF Export to Greece Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 15.5 20.9 11.3 9.9 -45.1 -4.9 23.7 18.3 37.4 -2.8 -5.7 -2.5 -4.4 -1.6 3.3 -19.5 6.2 -0.6 -8.6 15.1 -0.9

Table A 4.23 Year 2018 PTDF Export to UCTE Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 16.6 30.7 24.5 23.0 -22.3 15.5 -2.7 5.3 9.7 9.7 -1.9 -0.5 -5.2 5.7 4.3 0.8 10.2 -0.5 -0.8 -0.9 -23.7

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 44 (96)

Table A 4.24 Year 2018 LODF Export to Albania LODF (%)

PA10054

AN10170

1 PA10054

-36.2

AF10002 PP16147 HP10053 NN10132

HF10147

PM10056

HF10030

AP20065

-37.3

22.9

-15.6

28.0

8.8

14.1

4.8

-21.4

36.9

28.0

3.8

38.2

-4.5

6.5

-2.2

45.1

-10.7

-24.2

-14.9

16.8

6.8

8.9

51.9

2 AN10170

-40.4

3 AF10002

-35.3

29.0

4 PP16147

30.3

32.2

-16.7

5 HP10053

-26.2

6.5

-50.1

-18.4

6 NN10132

27.4

34.9

-15.3

-70.4

-11.7

7 HF10147

18.6

-9.9

47.0

8.6

30.5

13.3

8 PM10056

18.3

8.6

14.9

20.3

-27.1

27.7

8.2

9 HF10030

8.9

-4.2

22.0

4.4

16.5

6.8

53.4

7.2

10 AP20065

-15.9

8.5

16.3

-1.8

3.0

-12.3

-3.3

-3.6

-14.4

-90.0

5.8

20.7

3.3

7.6

-23.9

21.5

-36.3

12.2

15.8

18.1

3.1

-48.0

12.6

58.9

-29.1

5.4

5.1

Table A 4.25 Year 2018 PTDF Export to Albania new KS-MK Nr

Line Code

1 PA10054 2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067 15 HP10001 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Skopje Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Kosovo Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 400 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1600 1949 1920 709 2021 2021 1920

PTDF % 37.5 12.1 18.8 17.6 -11.6 -26.1 -24.7 7.3 15.0 2.6 -1.4 -0.3 -10.9 -4.9 -11.6 26.5 17.6 5.4 3.6 4.1 7.3

Table A 4.26 Year 2018 PTDF Export to Greece new KS.MK Nr

Line Code

1 PA10054 2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170 7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600

PTDF % 12.5 16.5 9.2 8.3 -27.5 -4.6 21.4 20.0 40.4 -0.3 -3.8 -1.6 -4.2

1.2 -15.2

-1.8

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Line Code

14 AN20067 15 HP10001 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 VDeja Skopje Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Podgorica Kosovo Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

Vnom kV 220 400 400 400 220 400 400 400

November, 2007 Page 45 (96)

Imax A 790 1600 1949 1920 709 2021 2021 1920

PTDF % -1.2 -27.5 -16.9 5.5 -0.4 -8.6 15.1 -0.7

Table A 4.27 Year 2018 PTDF Export to UCTE new KS-MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Skopje Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 400 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1600 1949 1920 709 2021 2021 1920

PTDF % 14.8 27.7 22.9 22.1 -13.2 15.8 -3.7 6.1 11.1 10.9 -1.5 -0.3 -5.1 6.2 -13.2 2.4 9.9 -0.4 -0.8 -0.9 -23.7

Table A 4.28 Year 2018 LODF Export to Albania new KS-MK LODF (%) 1 PA10054 2 AN10170 3 AF10002 4 PP16147 5 HP10053 6 NN10132 7 HF10147 8 HP10001 9 HF10030 10 AP20065

1 PA10054 -39.8 -36.4 28.1 -15.6 26.0 20.4 -15.5 9.9 -16.0

2 AN10170 -36.5

3 AF10002 -39.5 35.7

28.4 32.6 3.4 35.2 -9.8 3.5 -4.2 8.0

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

-17.4 -30.2 -16.1 48.9 -30.4 23.1 16.1

4 PP16147 21.5 27.8 -11.4 -10.4 -70.2 9.4 -10.1 4.8 -2.4

5 6 7 8 9 10 HP10053 NN10132 HF10147 HP10001 HF10030 AP20065 -6.4 27.0 9.8 -6.4 5.4 -32.6 1.4 38.8 -4.5 1.4 -2.3 8.4 -9.4 -14.6 18.0 -9.6 9.7 20.5 -5.6 -90.5 6.1 -5.5 3.6 -11.4 -12.8 13.2 62.3 7.6 10.0 -4.6 5.8 -4.7 3.4 -16.0 11.5 13.6 11.9 57.6 -12.1 60.4 -12.8 13.4 7.7 10.2 6.3 7.0 51.6 6.4 -5.5 1.8 -11.8 -3.3 1.9 -1.8

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 46 (96)

Table A 4.29 Year 2020 PTDF Export to Albania Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 39.3 14.2 19.7 17.9 -19.0 -25.9 -22.6 6.4 13.3 1.4 -1.6 -0.5 -10.6 -4.7 8.4 24.6 17.7 5.1 3.3 3.9 7.1

Table A 4.30 Year 2020 PTDF Export to Greece Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 16.1 21.1 11.3 9.8 -45.6 -4.8 25.5 18.9 38.1 -3.0 -5.8 -2.5 -4.3 -1.3 3.4 -20.1 6.2 -0.7 -13.8 15.7 -1.1

Table A 4.31 Year 2020 PTDF Export to UCTE Nr

Line Code 1 PA10054 2 PM10056 3 PP16147 4 NN10132 5 HP10053 6 AN10170

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Network Element Nome End 2 Kashar Nis Peja Ribarevina Kosovo Podgorica

Vnom kV 400 400 400 400 400 400

Imax A 1600 1600 1600 1920 1600 1920

PTDF % 16.8 30.5 23.9 22.4 -21.7 15.5

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Line Code

7 AF10002 8 HF10030 9 HF10147 10 HB10149 11 HP20126 12 HP20124 13 AP20065 14 AN20067 15 PP26152 1 AA10236 2 NN16110 3 AA20232 4 FF11981 5 FF11887 6 CN10019

Nome End 1 Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Network Element Nome End 2 Kardia Thessaloniki Florina CMogila Kosovo Ferizaj Prizren Podgorica Prizren Kashar Podgorica Kashar Kardia Ag.Dimitrios Podgorica

November, 2007 Page 47 (96)

Vnom kV 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

PTDF

Imax A 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

% -1.7 5.1 9.3 9.6 -1.8 -0.5 -4.8 6.3 4.3 0.5 9.9 -0.6 -1.0 -1.0 -23.4

Table A 4.32 Year 2020 LODF Export to Albania LODF (%)

PA10054

AN10170

1 PA10054

-40.3

AF10002 PP16147 HP10053 NN10132

HF10147

PM10056

HF10030

AP20065

-41.2

23.4

-15.7

26.8

3.2

12.2

-0.3

-61.1

37.6

27.7

3.1

38.9

-1.0

7.5

0.8

50.7

-12.6

-22.2

-15.3

5.9

3.8

-0.7

-28.1 -17.9

2 AN10170

-40.7

3 AF10002

-38.1

23.0

4 PP16147

31.1

31.6

-18.7

5 HP10053

-28.6

12.0

-47.4

-20.6

6 NN10132

27.8

34.2

-16.9

-70.1

7 HF10147

19.8

-14.6

46.9

9.4

30.8

10.1

8 PM10056

21.8

6.4

9.9

23.7

-29.2

24.6

1.6

9 HF10030

9.4

-7.0

21.8

4.8

16.7

5.0

42.9

5.1

10 AP20065

-16.5

9.2

17.3

-2.0

3.2

-11.3

-0.6

-2.6

-14.7

-90.5

1.2

18.6

-0.8

-19.2

31.8

-31.2

23.4

77.8

1.3

16.3

-0.4

-57.8

9.0

46.7

-76.1

-1.4

-32.6

-11.9

Table A 4.33 Year 2020 PTDF Export to Albania new KS-MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Skopje Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 400 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1600 1949 1920 709 2021 2021 1920

PTDF % 37.6 11.8 18.6 17.2 -10.5 -25.9 -23.9 7.3 15.0 2.6 -1.1 -0.2 -10.8 -4.6 -13.1 25.9 17.4 5.3 3.4 4.0 7.3

-43.0 0.4

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November, 2007 Page 48 (96)

Table A 4.34 Year 2020 PTDF Export to Greece new KS.MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Skopje Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 400 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1600 1949 1920 709 2021 2021 1920

PTDF % 12.5 16.4 9.0 8.1 -25.2 -4.5 21.7 20.7 41.6 0.0 -3.7 -1.5 -4.1 -1.1 -31.7 -16.8 5.4 -0.5 -13.5 15.8 -0.6

Table A 4.35 Year 2020 PTDF Export to UCTE new KS-MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Skopje Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 400 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1600 1949 1920 709 2021 2021 1920

PTDF % 14.6 27.8 22.6 21.6 -12.1 15.4 -3.5 6.2 11.3 11.1 -1.2 -0.1 -5.0 6.3 -15.1 2.1 9.7 -0.4 -0.8 -0.9 -23.2

Table A 4.36 Year 2020 LODF Export to Albania new KS-MK LODF (%) 1 2 3 4 5 6

PA10054 AN10170 AF10002 PP16147 HP10053 NN10132

1 PA10054 -40.2 -38.8 28.9 -15.6 26.5

2 AN10170 -39.6

3 AF10002 -39.6 35.6

24.1 32.4 5.8 34.9

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

-17.1 -29.1 -15.6

4 PP16147 21.8 27.4 -13.1 -10.3 -69.7

5 6 7 8 9 10 HP10053 NN10132 HF10147 HP10001 HF10030 AP20065 -4.5 26.0 6.8 -5.4 2.7 53.4 0.5 38.8 -2.5 0.7 -0.4 -79.1 -6.0 -15.9 12.1 -7.3 4.2 172.3 -3.9 -90.7 3.9 -4.5 1.5 28.3 -10.4 14.9 59.1 10.7 -109.1 -3.3 3.7 -3.9 1.5 73.6

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment 7 HF10147 8 HP10001 9 HF10030 10 AP20065

22.0 -19.4 10.6 -16.7

-14.2 7.3 -6.7 8.8

52.9 -36.7 25.3 15.8

10.6 -12.7 5.4 -2.5

11.9 62.2 6.6 0.9

November, 2007 Page 49 (96) 11.8 -13.0 5.9 -11.4

14.0 18.9 45.0 -2.0

7.6 1.2

Table A 4.37 Year 2020 PTDF Export to Albania new SR-MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 1600 1600 1600 1920 1600 1920 1949 1640 1640 1000 1000 824 600 790 1200 1949 1920 709 2021 2021 1920

PTDF % 41.6 9.5 24.1 22.4 -15.9 -20.3 -27.4 5.7 12.5 -1.9 -1.1 -0.2 -11.8 -2.5 9.4 28.3 21.4 5.1 4.5 5.2 -1.7

Table A 4.38 Year 2020 PTDF Export to Greece new SR.MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 44 17 55 25 41 10 27 6 7 32 25 8 30 23 49 7 31 38 10 16 13

PTDF % 18.8 18.9 16.3 14.9 -41.8 0.9 21.1 19.4 39.6 -5.2 -5.1 -2.1 -5.5 0.9 4.5 -16.9 10.2 -0.8 -11.9 17.3 -10.0

49.3 13.4 -0.6

179.1 -133.1 106.4

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

November, 2007 Page 50 (96)

Table A 4.39 Year 2020 PTDF Export to UCTE new SR-MK Nr

Line Code

Nome End 1 Kosovo Kosovo Kosovo Peja Skopje Kashar Zemljak Dubrovo Bitola Stip Skopje Skopje Fierze VDeja Glogovc Elbasan Ribarevina Tirana Ag. Dimitrios Thessaloniki Trebinie

Vnom kV 400 400 400 400 400 400 400 400 400 400 220 220 220 220 220 400 400 220 400 400 400

Imax A 44 17 55 25 41 10 27 6 7 32 25 8 30 23 49 7 31 38 10 16 13

PTDF % 19.0 22.9 27.9 26.6 -22.9 20.6 -6.0 3.7 7.2 4.8 -1.8 -0.5 -6.0 8.3 5.3 3.7 13.8 -0.6 0.3 0.4 -31.8

Table A 4.40 Year 2020 LODF Export to Albania new SR-MK LODF (%) 1 PA10054 2 AN10170 3 AF10002 4 PP16147 5 HP10053 6 NN10132 7 HF10147 8 HP10001 9 HF10030 10 AP20065

1 PA10054 -41.6 -37.5 30.0 -28.2 26.9 19.9 17.3 9.5 -16.7

2 AN10170 -36.7

3 AF10002 -40.5 34.6

25.5 38.1 5.6 40.5 -11.4 3.7 -5.3 7.4

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

-19.7 -46.0 -18.3 49.2 16.7 23.2 16.9

4 PP16147 22.6 26.5 -11.9 -22.4 -70.1 8.6 18.3 4.3 -2.0

5 6 7 8 9 10 HP10053 NN10132 HF10147 HP10001 HF10030 AP20065 -14.3 28.1 12.1 12.7 8.5 -3.9 0.4 39.4 4.7 6.8 5.9 72.6 -16.7 -14.5 8.7 5.4 2.7 -12.6 -15.0 -90.3 12.4 17.7 10.2 44.2 -23.6 23.3 -44.9 15.6 32.9 -12.4 12.1 15.8 10.1 9.3 18.3 10.6 4.6 56.6 -18.1 -36.2 20.9 -2.5 -4.0 -31.1 9.9 5.3 49.1 2.6 -12.2 3.1 -12.1 -4.6 -3.4 -3.5

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Figure A 4.1 Year 2012 Boundary Diagrams of NTC of Kosovo transmission network Peak Load European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 51 (96)

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Figure A 4.2 Year 2012 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line KS-AL Peak Load

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

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Figure A 4.3 Year 2012 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line KS-AL Light Load

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

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Figure A 4.4 Year 2014 Boundary Diagrams of NTC of Kosovo transmission network Peak load European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 54 (96)

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

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Figure A 4.5 Year 2014 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Kosovo-Kashar Peak Load European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

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Figure A 4.6 Year 2014 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Kosovo-Kashar Light Load

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Figure A 4.7 Year 2016 Boundary Diagrams of NTC of Kosovo transmission network Peak Load

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 57 (96)

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Figure A 4.8 Year 2016 Boundary Diagrams of NTC of Kosovo transmission network Light Load

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 58 (96)

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

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Figure A 4.9 Year 2016 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Kosovo(KS)-Skopje (MK) European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

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Figure A 4.10 Year 2018 Boundary Diagrams of NTC of Kosovo transmission network Peak Load European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 60 (96)

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

Figure A 4.11 Year 2018 Boundary Diagrams of NTC of Kosovo transmission network Light Load European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 61 (96)

Study to support the development of new generation capacities and related transmission Annexes of Report on Task2, Transmission System Impact Assessment

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Figure A 4.12 Year 2018 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Kosovo(KS)-Skopje (MK)

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Figure A 4.13 Year 2018 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Nish(SR)-Skopje (MK) European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

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Figure A 4.14 Year 2020 Boundary Diagrams of NTC of Kosovo transmission network Peak Load European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 64 (96)

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Figure A 4.15 Year 2020 Boundary Diagrams of NTC of Kosovo transmission network Light Load

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 65 (96)

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Figure A 4.16 Year 2020 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Kosovo(KS)-Skopje (MK) European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

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Figure A 4.17 Year 2020 Boundary Diagrams of NTC of Kosovo transmission network with new 400 kV line Nish(SR)-Skopje (MK) European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment

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Table A 4.41 Year 2005 Congestion Management and Capacity Allocation in UCTE ASSESSMENT OF CONGESTION MANAGEMENT AT EUROPEAN BORDERS (FEB 05) Conventional TC NTC (MW) of the Allocation Allocation Capacity Use it or Country 1 Country 2 Congested Winter 2005 Interconnection method frequency tradability loose it (MVA Thermal) EA/RET CRO SLO >1000 4816 d No yes occasionally FF SLO CRO >1000 4816 d No yes never RET GR IT 350 500 y,d No Yes frequently EA/PR IT GR 500 500 y,d No Yes occasionally RET/EA FYROM GR 600 1420 y No Yes occasionally RET/EA BG GR 600 1300 y No yes occasionally JEA CZ DE 2300 5843 y,m,d Yes yes always JEA DE CZ 700 5843 y,m,d Yes yes seldom RET/CEA PL-CZ DE 2200 9730 y,m,d Yes yes frequently RET/CEA DE PL-CZ 200 9730 y,m,d Yes yes seldom JEA SK CZ 2330 5266 y,m,d Yes yes seldom JEA CZ SK 2330 5266 y,m,d Yes yes seldom EA/RET PL SK 750 2868 y,m,d Yes yes frequently EA SK PL 750 2868 y,m,d Yes yes frequently JEA CZ PL 800 2976 y,m,d Yes Yes Occasionally JEA PL CZ 1870 2976 y,m,d Yes Yes Occasionally JEA AT CZ 600 2249 y,m,d yes yes Seldom JEA CZ AT 600 2249 y,m,d yes Yes frequently JEA AT HU 500 2124 y,m yes yes occasionally JEA HU AT 1100 2124 y,m yes yes always EA SK HU 1100 2492 y,m yes yes always EA HU SK 200 2492 y,m yes yes seldom EA HU SCG 400 1332 y,m yes Yes frequently EA SCG HU 300 1332 y,m yes Yes EA HU RO 300 1246 y,m yes Yes EA RO HU 300 1246 Y,m yes Yes frequently EA/RET HU CRO 600 2688 y, m yes Yes frequently EA/RET CRO HU 300 2688 y,m yes yes FF/RET CRO BIH 700 NA y,m,d no never FF/RET BIH CRO 600 NA y,m,d no occasionally FF BIH CG 600 NA y,m,d no never FF CG BIH 600 NA y,m,d no never FF SR CG 1000 NA y,m,d no never FF CG SR 1000 NA y,m,d no never FF SR MA 700 NA y,m,d no never FF MA SR 700 NA y,m,d no never FF SR BO 600 NA y,m,d no never FF BO SR 600 NA y,m,d no never FF SR RO 400 NA y,m,d no never FF RO SR 400 NA y,m,d no never FF/RET CRO SR 700 NA y,m,d no never FF/RET SR CRO 500 NA y,m,d no seldom FF/EA MA GR 400 NA y,m,d no always FF GR MA 400 NA y,m,d no never FF AL KO 100 NA y,m,d no FF KO AL 100 NA y,m,d no FF CG AL 250 NA y,m,d no FF AL CG 100 NA y,m,d no FF RO BO 1000 NA y,m,d no FF BO RO 700 NA y,m,d no FF AL GR 1200 NA y,m,d no FF GR AL 1200 NA y,m,d no FF BO GR 1200 NA y,m,d no FF GR BO 1200 NA y,m,d no FF KO SR 800 NA y,m,d no FF SR KO 800 NA y,m,d no FF KO MA 1200 NA y,m,d no FF MA KO 1200 NA y,m,d no Source: EFET Allocation frequency: y yearly, s semi-annually, q quarterly, m monthly, w weekly, d daily

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5. Annex 5 Transient Stability Analysis 1.1

Generators Data Table A 5.1 Albania Generator parameter

CodGru ABAAG1 ABAAG2 ABAAG3 ABAAG4 ABIAG1 ABIAG2 ABIAG3 ABIAG4 ABRAG1 ABRAG2 AF1AG1 AF1AG2 AF1AG3 AF1AG4 AF1AG5 AF1AG6 AF1AG7 AFIAG1 AFIAG2 AFIAG3 AFIAG4 AKOAG1 AKOAG2 AKOAG3 AKOAG4 AS2AG1 AS3AG1 AULAG1 AULAG2 AULAG3 AULAG4 AV1AG1 AV1AG2 AV1AG3 AV1AG4 AV1AG5

Name ABABICG1 ABABICG2 ABABICG3 ABABICG4 ABISTRIG ABISTRIG ABISTRIG ABISTRIG ABRATI91 ABRATI92 AFIER 9 AFIERV9 AFIERV9 AFIERV9 AFIERV9 AFIERV9 AFIER2G AFIERZ91 AFIERZ92 AFIERZ93 AFIERZ94 AKOMAN91 AKOMAN92 AKOMAN93 AKOMAN94 ASHKP19 ASHKP29 AULEZ 9 AULEZ 9 AULEZ 9 AULEZ 9 AVDEJA91 AVDEJA92 AVDEJA93 AVDEJA94 AVDEJA95

XPD

XPQ

XSD

XSQ

1.759 1.759 1.759 1.759 1.000 1.000 1.000 1.330 0.871 0.871 2.040 1.000 1.000 1.000 1.000 2.270 2.270 0.871 0.871 0.871 0.871 1.000 1.000 1.000 1.000 1.052 1.052 1.000 1.000 1.000 1.068 0.996 0.996 0.996 0.996 0.996

1.720 1.720 1.720 1.720 0.700 0.700 0.700 0.600 0.576 0.576 2.000 0.700 0.700 0.700 0.700 2.200 2.200 0.576 0.576 0.576 0.576 0.630 0.630 0.630 0.630 0.720 0.720 0.700 0.700 0.700 0.654 0.632 0.632 0.632 0.632 0.632

0.254 0.254 0.254 0.254 0.300 0.300 0.300 0.347 0.261 0.261 0.200 0.300 0.300 0.300 0.300 0.159 0.159 0.261 0.261 0.261 0.261 0.320 0.320 0.320 0.320 0.323 0.323 0.300 0.300 0.300 0.350 0.239 0.239 0.239 0.239 0.239

0.440 0.440 0.440 0.440 0.000 0.000 0.000 0.000 0.000 0.000 0.500 0.000 0.000 0.000 0.000 0.600 0.600 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

0.171 0.171 0.171 0.171 0.200 0.200 0.200 0.235 0.161 0.161 0.135 0.200 0.200 0.200 0.200 0.090 0.090 0.161 0.161 0.161 0.161 0.240 0.240 0.240 0.240 0.204 0.204 0.200 0.200 0.200 0.215 0.163 0.163 0.163 0.163 0.163

0.135 0.135 0.135 0.135 0.100 0.100 0.100 0.100 0.068 0.068 0.102 0.100 0.100 0.100 0.100 0.050 0.050 0.068 0.068 0.068 0.068 0.185 0.185 0.185 0.185 0.073 0.073 0.100 0.100 0.100 0.118 0.100 0.100 0.100 0.100 0.100

K damping 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000

TPD0 TPQ0 TSD0 TSQ0 TAA 4.950 4.950 4.950 4.950 5.000 5.000 5.000 5.763 7.540 7.540 8.600 5.000 5.000 5.000 5.000 6.720 6.720 7.540 7.540 7.540 7.540 6.800 6.800 6.800 6.800 2.016 2.016 5.000 5.000 5.000 1.702 5.770 5.770 5.770 5.770 5.770

1.000 1.000 1.000 1.000 0.210 0.210 0.210 0.060 0.071 0.071 1.200 0.210 0.210 0.210 0.210 0.900 0.900 0.071 0.071 0.071 0.071 0.075 0.075 0.075 0.075 0.112 0.112 0.210 0.210 0.210 0.060 0.070 0.070 0.070 0.070 0.070

0.040 0.040 0.040 0.040 0.000 0.000 0.000 0.000 0.000 0.000 0.050 0.000 0.000 0.000 0.000 0.050 0.040 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

Table A 5.2 Kosovo Generator parameter CodGru KHGPG1 KHGPG2 KT1PG1 KT1PG2 KT1PG3 KT1PG4 KT2PG1 KT2PG2 KT2PG3 KT2PG4 KT2PG5 KTKPG1 KTKPG2

Name KHGAZIG1 KHGAZIG2 KTKOSCG1 KTKOSCG2 KTKOSCG3 KTKOSCG4 KTKOSAG1 KTKOSAG2 KTKOSAG3 KTKOSAG4 KTKOSAG5 KTKOSBG1 KTKOSBG2

XPD

XPQ

XSD

XSQ

1.150 1.150 2.560 2.560 2.560 2.560 1.930 1.930 1.930 1.930 1.930 2.214 2.214

0.790 0.790 2.510 2.510 2.510 2.510 1.620 1.585 1.620 1.620 1.620 2.093 2.093

0.343 0.343 0.380 0.380 0.380 0.380 0.310 0.310 0.310 0.310 0.310 0.356 0.356

0.000 0.000 0.570 0.570 0.570 0.570 0.470 0.470 0.470 0.470 0.470 0.540 0.540

0.168 0.168 0.240 0.240 0.240 0.240 0.185 0.260 0.248 0.248 0.248 0.209 0.209

0.120 0.120 0.144 0.144 0.144 0.144 0.150 0.150 0.150 0.150 0.150 0.130 0.130

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K damping 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000 1.000 0.000

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

TPD0 TPQ0 TSD0 TSQ0 TAA 5.000 5.000 7.300 7.300 7.300 7.300 6.800 6.800 6.800 6.800 6.800 6.500 6.500

0.060 0.060 0.310 0.310 0.310 0.310 0.270 0.270 0.270 0.270 0.270 0.270 0.270

0.020 0.020 0.010 0.010 0.010 0.010 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.000 0.000 0.042 0.042 0.042 0.042 0.032 0.032 0.032 0.032 0.032 0.032 0.032

0.020 0.020 0.010 0.010 0.010 0.010 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment

November, 2007 Page 70 (96)

Table A 5.3 Montenegro Generator parameter CodGru JH1NG1 JH1NG2 JH1NG3 JH1NG4 JH1NG5 JH1NG6 JH1NG7 JHPNG1 JHPNG2 JHPNG3 JPLNG1

Name JHPERUG1 JHPERUG2 JHPERUG3 JHPERUG4 JHPERUG5 JHPERUG6 JHPERUG7 JHPIVAG1 JHPIVAG2 JHPIVAG3 JTPLJEG1

XPD

XPQ

XSD

XSQ

1.455 1.455 1.455 1.455 1.455 1.380 1.380 1.000 1.000 1.000 2.060

0.770 0.770 0.770 0.770 0.770 0.770 0.770 0.600 0.600 0.600 2.000

0.347 0.347 0.347 0.347 0.347 0.325 0.325 0.360 0.360 0.360 0.450

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.580

0.310 0.310 0.310 0.310 0.310 0.195 0.195 0.207 0.207 0.207 0.250

0.120 0.120 0.120 0.120 0.120 0.130 0.130 0.140 0.140 0.140 0.166

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

TPD0 TPQ0 TSD0 TSQ0 TAA 1.440 1.440 1.440 1.440 1.440 1.990 1.990 6.500 6.500 6.500 6.480

0.070 0.070 0.070 0.070 0.070 0.073 0.073 0.060 0.060 0.060 0.330

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.036

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.4 Macedonia Generator parameter CodGru BITHG1 BITHG2 BITHG3 B-MHG1 GLOHG1 GLOHG2 KO1HG1 MATHG1 OSLHG1 SPIHG1 SPIHG2 SPIHG3 TIKHG1 TIKHG2 TIKHG3 TIKHG4 TPPHG1 VRUHG1 VRUHG2 VRUHG3 VRUHG4 ZLZHG1

Name BT 2 100 BT 2 400 BT 2 400 B.MOST GLOBOCIC GLOBOCIC KOZJAK MATKA 2 OSLOMEJ SPILJE SPILJE SPILJE TIKVES TIKVES TIKVES TIKVES TPP NEGO VRUTOK VRUTOK VRUTOK VRUTOK GASNA

XPD

XPQ

XSD

XSQ

2.450 2.450 2.450 2.080 1.220 1.220 1.100 2.080 1.840 1.080 1.080 1.080 1.100 1.100 1.100 1.100 2.000 1.390 1.390 1.047 1.047 2.450

2.400 2.400 2.400 1.390 0.650 0.650 0.673 1.390 1.750 0.685 0.685 0.685 0.673 0.673 0.673 0.673 1.920 0.950 0.950 0.950 0.950 2.400

0.278 0.278 0.278 0.450 0.303 0.303 0.246 0.450 0.210 0.350 0.350 0.350 0.246 0.246 0.246 0.246 0.312 0.320 0.320 0.322 0.322 0.300

0.451 0.451 0.451 0.000 0.000 0.000 0.000 0.000 0.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.500 0.000 0.000 0.000 0.000 0.715

0.192 0.192 0.192 0.201 0.175 0.175 0.190 0.201 0.150 0.200 0.200 0.200 0.190 0.190 0.190 0.190 0.198 0.317 0.317 0.217 0.217 0.190

0.166 0.166 0.166 0.200 0.148 0.148 0.120 0.200 0.100 0.136 0.136 0.136 0.120 0.120 0.120 0.120 0.100 0.130 0.130 0.132 0.132 0.104

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.100

TPD0 TPQ0 TSD0 TSQ0 TAA 7.000 7.000 7.000 6.000 2.530 2.530 5.060 6.000 4.300 2.530 2.530 2.530 5.060 5.060 5.060 5.060 7.750 4.600 4.600 4.600 4.600 4.750

0.251 0.251 0.251 0.100 0.050 0.050 0.050 0.100 0.540 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.500 0.070 0.070 0.070 0.070 1.500

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.034 0.034 0.034 0.000 0.000 0.000 0.000 0.000 0.076 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.141 0.000 0.000 0.000 0.000 0.090

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.5 Greece Generator parameter CodGru AG1FG1 AG9FG1 AG-FG1 AG-FG2 AG-FG3 AG-FG4 AGRFG1 AGRFG2 AH2FG1 AH2FG2 AH2FG3 AL9FG1 ALIFG1 ALIFG2 ALIFG3 ALIFG4 AMUFG1 AMUFG2 ASWFG1 ASWFG2 AWOFG1 AWOFG2

Name AG-DHM G MOTOR OI AG-DHM G AG-DHM G AG-DHM G AG-DHM G AGRAS G. AGRAS G. AHSAG2 AHSAG G AHSAG G ALOUMINI ALIB G1 ALIB G2 ALIB G3 ALIB G4 AMUNT G1 AMUNT G2 ASWMATA ASWMATA AWOS G1 AWOS G1

XPD

XPQ

XSD

XSQ

1.680 1.052 1.724 1.724 1.680 1.680 1.000 0.956 2.053 1.830 1.830 2.053 1.370 1.370 1.759 1.720 1.600 1.600 1.100 1.100 1.170 1.170

1.600 0.720 1.597 1.597 1.600 1.600 0.700 0.465 1.972 1.800 1.800 1.972 1.350 1.350 1.720 1.658 1.550 1.580 0.700 0.700 0.720 0.720

0.276 0.323 0.260 0.260 0.276 0.276 0.300 0.260 0.294 0.260 0.260 0.294 0.260 0.260 0.254 0.282 0.243 0.243 0.280 0.280 0.350 0.350

0.456 0.000 0.456 0.456 0.456 0.456 0.000 0.000 0.382 0.458 0.458 0.382 0.456 0.456 0.440 0.440 0.456 0.456 0.000 0.000 0.000 0.000

0.168 0.204 0.178 0.178 0.168 0.168 0.200 0.146 0.203 0.150 0.150 0.203 0.195 0.195 0.171 0.187 0.163 0.163 0.240 0.240 0.210 0.210

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

XL 0.149 0.073 0.149 0.149 0.149 0.149 0.100 0.130 0.120 0.100 0.100 0.120 0.149 0.149 0.135 0.135 0.149 0.149 0.180 0.180 0.120 0.120

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

TPD0 TPQ0 TSD0 TSQ0 TAA 5.900 2.016 5.980 5.980 5.900 5.900 5.000 5.030 6.600 8.500 8.500 6.600 1.400 1.400 4.950 4.950 5.800 5.800 5.700 5.700 8.500 8.500

1.000 0.112 1.000 1.000 1.000 1.000 0.210 0.035 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 0.135 0.135 0.102 0.102

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.130 0.000 0.060 0.060 0.130 0.130 0.000 0.000 0.060 0.042 0.042 0.060 0.060 0.060 0.040 0.040 0.130 0.130 0.000 0.000 0.000 0.000

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru D14FG1 D14FG2 D16FG1 D1BFG1 D1BFG2 D1BFG3 D1BFG4 D1BFG5 D1TFG1 EDEFG1 EDFFG1 ELDFG1 ELPFG1 EN1FG1 ENEFG1 ENEFG2 GKIFG1 HROFG1 HROFG2 HROFG3 HROFG4 HROFG5 IRAFG1 IRAFG2 K13FG1 K14FG1 K14FG2 K14FG3 KARFG1 KARFG2 KARFG3 KARFG4 KREFG1 KREFG2 KREFG3 KREFG4 LAQFG1 LAQFG2 LAUFG1 LAUFG2 LOUFG1 LOUFG2 LOUFG3 MA1FG1 ME5FG1 ME5FG2 ME5FG3 ME5FG4 ME9FG1 MECFG1 MECFG2 MEDFG1 MEDFG2 MYTFG1 PL4FG1 PL4FG2 PL4FG3 PLAFG1 PO2FG1 PO3FG1 PO3FG2 PO4FG1 PO5FG1 PO7FG1 POUFG1 PT3FG1 PT3FG2 PT3FG3 PT3FG4

Name FLWR.G1 FLWR.G2 K_LARYMN LAURIOG1 SLAUCCG5 SLAUCCG4 SLAUCCG6 LAURIOG2 K-TRIKAL EDESSAIO EDF-G ELDA ELPE G ENELCO-G ENELCOG1 ENELCOG2 GIWNA G HRON ST HRON G34 HRON G34 HRON G12 HRON G12 IRARI G1 IRARI G2 KASTR G2 KASTR G1 KASTR G3 KASTR G4 KARDIA G KARDIA G KARDIA G KARDIA G KREMAS G KREMAS G KREMAS G KREMAS G LADWN G LADWN G BLAUCCG1 BLAVRG2 LOUROS G LOUROS G LOUROS G MAKR.G1 MEG.1TES MEGLOP G MEGLOP G MEGLOP G MEGLOP G MESOCWRA MESOCWRA METSOBG1 METSOBG2 MYTILHN PLASTHRA PLASTHRA PLASTHRA PLATANOB POLUF G1 POLUF G2 POLUF G3 POURNAR POURNAR POURNAR2 POURNAR PTOLEMAI PTOLEMAI PTOLEMAI PTOLEMAI

XPD

XPQ

XSD

XSQ

1.823 1.823 1.680 1.759 1.760 1.760 1.760 1.820 1.680 1.010 1.680 1.052 1.680 1.680 2.053 2.053 1.260 1.200 1.000 1.200 1.000 1.200 1.150 1.150 1.030 1.030 1.030 1.030 1.823 1.823 1.823 1.823 0.920 0.920 0.920 0.920 1.027 1.027 1.052 1.052 1.000 1.000 0.915 1.170 2.053 1.770 1.770 2.120 2.120 1.000 1.000 1.200 1.200 1.680 1.260 1.260 1.260 1.110 1.380 1.380 1.380 0.960 0.960 1.010 0.960 1.700 1.846 1.800 1.800

1.720 1.720 1.600 1.720 1.720 1.720 1.720 1.720 1.600 0.604 1.600 0.720 1.600 1.600 1.972 1.972 0.810 0.800 0.700 0.800 0.700 0.800 0.750 0.750 0.562 0.562 0.562 0.562 1.720 1.720 1.720 1.720 0.580 0.580 0.580 0.580 0.668 0.668 0.720 0.720 0.700 0.700 0.860 0.720 1.972 1.740 1.740 2.020 2.020 0.680 0.680 0.800 0.800 1.600 0.810 0.810 0.810 0.680 0.860 0.860 0.860 0.640 0.640 0.604 0.640 1.680 1.810 1.760 1.760

0.264 0.264 0.276 0.240 0.254 0.254 0.254 0.264 0.276 0.223 0.276 0.323 0.276 0.276 0.294 0.294 0.250 0.280 0.300 0.280 0.300 0.280 0.350 0.350 0.255 0.255 0.255 0.255 0.264 0.264 0.264 0.264 0.280 0.280 0.280 0.280 0.310 0.310 0.323 0.323 0.300 0.300 0.332 0.350 0.294 0.350 0.350 0.330 0.330 0.268 0.268 0.280 0.280 0.276 0.250 0.250 0.250 0.270 0.280 0.280 0.280 0.350 0.350 0.223 0.350 0.210 0.240 0.195 0.195

0.456 0.456 0.456 0.440 0.440 0.440 0.440 0.440 0.456 0.000 0.456 0.000 0.456 0.456 0.382 0.382 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.456 0.456 0.456 0.456 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.382 0.443 0.443 0.770 0.770 0.000 0.000 0.000 0.000 0.456 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.425 0.455 0.455 0.455

0.198 0.198 0.168 0.160 0.130 0.130 0.130 0.184 0.168 0.138 0.168 0.204 0.168 0.168 0.203 0.203 0.200 0.160 0.200 0.160 0.200 0.160 0.210 0.210 0.200 0.200 0.200 0.200 0.124 0.124 0.124 0.124 0.210 0.210 0.210 0.210 0.205 0.205 0.168 0.168 0.200 0.200 0.201 0.220 0.203 0.230 0.230 0.230 0.230 0.180 0.180 0.160 0.160 0.168 0.161 0.161 0.161 0.210 0.230 0.230 0.230 0.190 0.190 0.138 0.190 0.135 0.172 0.130 0.130

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

XL 0.100 0.100 0.149 0.135 0.100 0.100 0.100 0.135 0.149 0.130 0.149 0.073 0.149 0.149 0.120 0.120 0.136 0.135 0.100 0.135 0.100 0.135 0.130 0.130 0.130 0.130 0.130 0.130 0.100 0.100 0.100 0.100 0.130 0.130 0.130 0.130 0.136 0.136 0.073 0.073 0.100 0.100 0.136 0.136 0.120 0.120 0.120 0.150 0.150 0.100 0.100 0.135 0.135 0.149 0.130 0.130 0.130 0.153 0.138 0.138 0.138 0.130 0.130 0.130 0.130 0.100 0.140 0.100 0.100

November, 2007 Page 71 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

TPD0 TPQ0 TSD0 TSQ0 TAA 5.830 5.830 5.900 7.400 4.950 4.950 4.950 5.830 5.900 5.500 5.900 2.016 5.900 5.900 6.600 6.600 8.500 6.000 5.000 6.000 5.000 6.000 5.050 5.050 8.900 8.900 8.900 8.900 5.830 5.830 5.830 5.830 6.600 6.600 6.600 6.600 7.000 7.000 2.016 2.016 5.000 5.000 6.600 8.500 6.600 5.700 5.700 7.200 7.200 7.600 7.600 6.000 6.000 5.900 5.600 5.600 5.600 6.200 9.200 9.200 9.200 7.500 7.500 5.500 7.500 5.600 5.780 5.780 5.780

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 0.035 1.000 0.112 1.000 1.000 1.000 1.000 0.064 0.071 0.210 0.071 0.210 0.071 0.135 0.135 0.091 0.091 0.091 0.091 1.000 1.000 1.000 1.000 0.079 0.079 0.079 0.079 0.110 0.110 0.112 0.112 0.210 0.210 0.048 0.064 1.000 1.000 1.000 1.000 1.000 0.079 0.079 0.071 0.071 1.000 0.064 0.064 0.064 0.100 0.083 0.083 0.083 0.095 0.095 0.035 0.095 1.000 1.000 1.000 1.000

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.060 0.060 0.130 0.040 0.040 0.040 0.040 0.040 0.130 0.000 0.130 0.000 0.130 0.130 0.060 0.060 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.060 0.060 0.060 0.060 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.060 0.041 0.041 0.060 0.060 0.000 0.000 0.000 0.000 0.130 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.080 0.083 0.083 0.083

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru PT3FG5 PT3FG6 QH1FG1 QHSFG1 QHSFG2 QHSFG3 SF2FG1 SF2FG2 SF2FG3 STRFG1 STRFG2 STRFG3 STRFG4 TEMFG1

Name LIPTOL G LIPTOL G QHSAUROS KOMOT.G1 KOMOT.G2 KOMOT.G3 SFHKIA G SFHKIA G SFHKIA G STRATOS STRATOS STRATOS STRATOS TEMENOSG

XPD

XPQ

XSD

XSQ

1.000 1.670 1.060 2.053 2.053 2.053 1.150 1.150 1.150 0.950 0.950 1.000 0.915 1.670

0.700 1.650 0.630 1.972 1.972 1.972 0.750 0.750 0.750 0.560 0.560 0.700 0.860 1.650

0.300 0.180 0.270 0.294 0.294 0.294 0.350 0.350 0.350 0.300 0.300 0.300 0.332 0.280

0.000 0.455 0.000 0.382 0.382 0.382 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.455

0.200 0.120 0.180 0.203 0.203 0.203 0.210 0.210 0.210 0.200 0.200 0.200 0.201 0.205

November, 2007 Page 72 (96)

SATUR SIGMA

0.100 0.100 0.123 0.112 0.120 0.120 0.130 0.130 0.130 0.150 0.150 0.100 0.136 0.100

0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

TPD0 TPQ0 TSD0 TSQ0 TAA 5.000 4.500 8.400 6.600 6.600 6.600 5.050 5.050 5.050 3.900 3.900 5.000 6.600 4.500

0.210 1.000 0.180 1.000 1.000 1.000 0.135 0.135 0.135 0.040 0.040 0.210 0.048 1.000

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.000 0.083 0.000 0.060 0.060 0.060 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.083

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.6 Bulgaria Generator parameter CodGru PVCBG1 SAMBG1 SESBG1 SESBG2 SH2BG1 ST5BG1 STKBG1 STKBG2 STKBG3 STKBG4 TDEBG1 TDEBG2 TE0BG1 TE0BG2 TE1BG1 TE2BG1 TE3BG1 TE3BG2 TE3BG3 TE4BG1 TE4BG2 TE4BG3 TE4BG4 TE4BG5 TE4BG6 TE5BG1 TE5BG2 TE5BG3 TE6BG1 TE7BG1 TE7BG2 TE7BG3 TE7BG4 TE7BG5 TE8BG1 TE8BG2 TE8BG3 TE8BG4 TE9BG1 TE9BG2 TE9BG3 TEABG1 TEBBG1 TECBG1 TEDBG1 TEDBG2 TEDBG3 TEFBG1 TEFBG2 TESBG1

Name TDEV.G3 SAMARA HSES.G1 HSES.G2 SHUMEN-1 ST_GRAD HST.KG12 HST.KG12 HST.KG34 HST.KG34 TDEV_G14 TDEV_G14 TSV_G12 TSV_G12 TMI1_G6 TMI1_G7 TSF_G8 TSF_G5 TSF_G6 TVARN_G1 TVARN_G2 TVARN_G3 TVARN_G4 TVARN_G5 TVARN_G6 TVRACAG TVRACAG TVRACAG TSL.G1 TSF.I.G5 TSF.I.G4 TSF.I.G3 TSF.IG12 TSF.IG12 TKREM_G4 TKR_G235 TKR_G235 TKR_G235 TREP.G5 TREP.G34 TREP.G34 TRUSEG4 TRUSEG3 TMI1_G5 TPD.G1 TPD.G2 TPD.G3 TVIDING TVIDING HTESH.G

XPD

XPQ

XSD

XSQ

1.850 0.996 1.410 1.410 0.996 0.996 1.000 1.370 1.000 1.370 1.000 2.200 1.000 1.610 2.390 2.390 1.610 1.610 1.610 2.100 2.100 2.100 2.100 2.100 2.100 1.000 1.000 2.180 2.110 1.610 2.097 2.110 1.000 2.097 1.610 1.000 1.000 1.610 2.000 1.000 2.180 2.336 2.336 2.390 2.200 2.110 2.110 1.000 1.610 1.000

1.850 0.610 0.895 0.895 0.610 0.610 0.700 0.880 0.700 0.880 0.700 2.200 0.700 1.610 2.340 2.340 1.610 1.610 1.610 2.100 2.100 2.100 2.100 2.100 2.100 0.700 0.700 2.180 2.110 1.610 2.097 2.110 0.700 2.097 1.610 0.700 0.700 1.610 2.000 0.700 2.180 2.336 2.336 2.340 2.200 2.110 2.110 0.700 1.610 0.700

0.187 0.167 0.265 0.265 0.167 0.167 0.300 0.377 0.300 0.377 0.300 0.290 0.300 0.280 0.320 0.320 0.233 0.233 0.233 0.270 0.270 0.270 0.270 0.270 0.270 0.300 0.300 0.236 0.220 0.233 0.219 0.220 0.300 0.219 0.280 0.300 0.300 0.280 0.205 0.300 0.236 0.265 0.265 0.320 0.238 0.220 0.220 0.300 0.280 0.300

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.280 0.560 0.560 0.233 0.233 0.233 0.270 0.270 0.270 0.270 0.270 0.270 0.000 0.000 0.236 0.220 0.233 0.219 0.220 0.000 0.219 0.280 0.000 0.000 0.280 0.205 0.000 0.236 0.265 0.265 0.560 0.230 0.220 0.220 0.000 0.280 0.000

0.162 0.151 0.230 0.200 0.151 0.151 0.200 0.271 0.200 0.271 0.200 0.190 0.200 0.195 0.239 0.239 0.129 0.129 0.129 0.180 0.180 0.180 0.180 0.180 0.180 0.200 0.200 0.163 0.130 0.156 0.129 0.130 0.200 0.129 0.195 0.200 0.200 0.195 0.145 0.200 0.163 0.220 0.220 0.239 0.164 0.130 0.130 0.200 0.195 0.200

0.137 0.120 0.130 0.130 0.120 0.120 0.100 0.000 0.100 0.000 0.100 0.120 0.100 0.150 0.190 0.190 0.110 0.110 0.110 0.166 0.166 0.166 0.166 0.166 0.166 0.100 0.100 0.150 0.000 0.110 0.110 0.000 0.100 0.110 0.000 0.100 0.100 0.150 0.000 0.100 0.150 0.000 0.000 0.190 0.000 0.000 0.000 0.100 0.150 0.100

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

K TPD0 damping 0.000 6.420 0.000 7.150 0.000 11.300 0.000 11.300 0.000 7.150 0.000 7.150 0.000 5.000 0.000 7.650 0.000 5.000 0.000 7.650 0.000 5.000 0.000 6.400 0.000 5.000 0.000 4.900 0.000 7.290 0.000 7.290 0.000 9.900 0.000 9.900 0.000 9.900 0.000 7.000 0.000 7.000 0.000 7.000 0.000 7.000 0.000 7.000 0.000 7.000 0.000 5.000 0.000 5.000 0.000 9.500 0.000 9.500 0.000 8.000 0.000 9.500 0.000 9.500 0.000 5.000 0.000 9.500 0.000 6.700 0.000 5.000 0.000 5.000 0.000 4.900 0.000 6.400 0.000 5.000 0.000 9.500 0.000 6.000 0.000 6.000 0.000 7.290 0.000 9.500 0.000 9.500 0.000 9.500 0.000 5.000 0.000 4.900 0.000 5.000

TPQ0 TSD0 TSQ0 TAA 0.250 0.347 0.220 0.220 0.347 0.347 0.210 0.100 0.210 0.100 0.210 0.284 0.210 4.900 0.260 0.260 9.900 9.900 9.900 7.000 7.000 7.000 7.000 7.000 7.000 0.210 0.210 9.500 9.500 8.000 9.500 9.500 0.210 9.500 6.700 0.210 0.210 4.900 6.400 0.210 9.500 6.000 6.000 0.260 9.500 9.500 9.500 0.210 4.900 0.210

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.100 0.029 0.029 0.120 0.120 0.120 0.100 0.100 0.100 0.100 0.100 0.100 0.000 0.000 0.100 0.100 0.120 0.120 0.100 0.000 0.120 0.100 0.000 0.000 0.100 0.100 0.000 0.100 0.100 0.100 0.029 0.100 0.100 0.100 0.000 0.100 0.000

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru TESBG2 VA1BG1 VA1BG2 VARBG1 VBEBG1 VBEBG2 VE2BG1 VE2BG2 VE2BG3 VE2BG4 VE3BG1 VE3BG2 VE4BG1 VE4BG2 VE7BG1 VE7BG2 VE7BG3 VE7BG4 VECBG1 VECBG2 VECBG3 VKIBG1 VKIBG2

Name HTESH.G VARDINO VARDINO VARNA220 VBELI_IZ VBELI_IZ HBATG123 HBATG123 HBATG123 HBAT_G4 HKRI.G1 HKRI.G2 DEVIN.G1 DEVIN.G2 HKAR.G12 HKAR.G12 HKAR.G34 HKAR.G34 HALEKOG3 HALEKOG2 HALEKOG1 VKITNICA VKITNICA

XPD

XPQ

XSD

XSQ

1.204 1.000 2.080 1.870 1.000 2.080 1.000 1.000 1.270 1.270 1.204 1.204 1.204 1.204 1.000 1.100 1.000 1.100 1.205 1.205 1.205 1.000 2.080

0.701 0.700 1.390 1.870 0.700 1.390 0.700 0.700 0.800 0.800 0.701 0.701 0.701 0.701 0.700 0.625 0.700 0.625 0.800 0.800 0.800 0.700 1.390

0.319 0.300 0.450 0.290 0.300 0.450 0.300 0.300 0.320 0.320 0.319 0.319 0.319 0.319 0.300 0.320 0.300 0.320 0.350 0.350 0.350 0.300 0.450

0.000 0.000 0.000 0.290 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

0.220 0.200 0.201 0.200 0.200 0.201 0.200 0.200 0.220 0.220 0.211 0.211 0.211 0.211 0.200 0.200 0.200 0.200 0.158 0.158 0.158 0.200 0.201

0.211 0.100 0.200 0.155 0.100 0.200 0.100 0.100 0.200 0.200 0.200 0.200 0.200 0.200 0.100 0.000 0.100 0.000 0.000 0.000 0.000 0.100 0.200

November, 2007 Page 73 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

TPD0 TPQ0 TSD0 TSQ0 TAA 6.000 5.000 6.000 6.400 5.000 6.000 5.000 5.000 10.000 10.000 6.000 6.000 6.000 6.000 5.000 6.000 5.000 6.000 10.000 10.000 10.000 5.000 6.000

0.100 0.210 0.100 6.400 0.210 0.100 0.210 0.210 0.100 0.100 0.100 0.100 0.100 0.100 0.210 0.100 0.210 0.100 0.100 0.100 0.100 0.210 0.100

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.000 0.000 0.000 0.120 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.7 Romania Generator parameter CodGru AREJG1 AREJG2 AREJG3 AREJG4 BA1JG1 BA1JG2 BACJG1 BO3JG1 BU0JG1 BU0JG2 BU2JG1 BUAJG1 BUBJG1 BUCJG1 BUCJG2 BUCJG3 BUCJG4 BUCJG5 BUCJG6 BUJJG1 BUJJG2 BULJG1 CE0JG1 CE1JG1 CE1JG2 CE2JG1 CE2JG2 CE2JG3 CE2JG4 CE3JG1 CE3JG2 CE4JG1 CE4JG2 CE5JG1 CE5JG2 CE5JG3 CE5JG4 CE5JG5 CE5JG6 CECJG1 CERJG1

Name AREFU 1 AREFU 2 AREFU 3 AREFU 4 BARBOSI5 BARBOSI3 BACAU 1 BORZEST8 BUC.V 1 BUC.VTG2 FAI I 3 BUC.S 5 BUC.S 6 BUC.S 3 BUC.S 1 BUC.S 2 BUC.S 4 BUC.STG BUC.STG1 BUC.V 2 BUC.VTG1 FAI I 4 ARAD 1 SUCEAVA1 SUCEAVA2 BRAZI 5 BRAZI 10 BRAZI 7 BRAZI 6 PROGRS4 PROGRS3 BRASOV 1 BRASOV 2 STUPA I1 STUPA I2 STUPAII6 STUPAII5 STUPA I3 STUPA I4 GHIZDAR1 CERNAV.1

XPD

XPQ

XSD

XSQ

1.250 1.250 1.250 1.250 1.907 1.907 2.096 1.880 2.420 2.053 1.657 2.420 2.420 1.790 2.000 1.790 1.790 2.097 2.053 2.420 2.053 1.657 2.096 2.096 2.096 1.907 2.096 2.096 1.907 2.000 2.000 2.096 2.096 1.657 1.657 1.657 1.657 1.657 1.657 2.096 1.810

0.880 0.880 0.880 0.880 1.907 1.907 2.096 1.880 2.420 1.972 1.657 2.420 2.420 1.790 2.000 1.790 1.790 2.097 1.972 2.420 1.972 1.657 2.096 2.096 2.096 1.907 2.096 2.096 1.907 2.000 2.000 2.096 2.096 1.657 1.657 1.657 1.657 1.657 1.657 2.096 1.690

0.250 0.250 0.250 0.250 0.278 0.278 0.280 0.270 0.284 0.294 0.309 0.284 0.284 0.263 0.242 0.263 0.263 0.219 0.294 0.284 0.294 0.309 0.280 0.280 0.280 0.278 0.280 0.280 0.278 0.242 0.242 0.280 0.280 0.309 0.309 0.309 0.309 0.309 0.309 0.280 0.335

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.382 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.219 0.382 0.000 0.382 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.540

0.160 0.160 0.160 0.160 0.192 0.192 0.189 0.191 0.167 0.203 0.176 0.167 0.167 0.183 0.156 0.183 0.183 0.129 0.203 0.167 0.203 0.176 0.189 0.189 0.189 0.192 0.189 0.189 0.192 0.156 0.156 0.189 0.189 0.176 0.176 0.176 0.176 0.176 0.176 0.189 0.260

0.100 0.100 0.100 0.100 0.110 0.110 0.100 0.120 0.110 0.120 0.100 0.110 0.110 0.110 0.100 0.110 0.110 0.110 0.120 0.110 0.120 0.100 0.100 0.100 0.100 0.110 0.100 0.100 0.110 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.170

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

K TPD0 damping 0.000 6.000 0.000 6.000 0.000 6.000 0.000 6.000 0.000 7.750 0.000 7.750 0.000 4.800 0.000 6.400 0.000 4.500 0.000 6.600 0.000 5.400 0.000 4.500 0.000 4.500 0.000 7.750 0.000 6.400 0.000 7.750 0.000 7.750 0.000 9.500 0.000 6.600 0.000 4.500 0.000 6.600 0.000 5.400 0.000 4.800 0.000 4.800 0.000 4.800 0.000 7.750 0.000 4.800 0.000 4.800 0.000 7.750 0.000 6.400 0.000 6.400 0.000 4.800 0.000 4.800 0.000 5.400 0.000 5.400 0.000 5.400 0.000 5.400 0.000 5.400 0.000 5.400 0.000 4.800 0.000 8.700

TPQ0 TSD0 TSQ0 TAA 0.268 0.268 0.268 0.268 0.331 0.331 0.331 0.284 0.408 1.000 0.331 0.408 0.408 0.331 0.460 0.331 0.331 9.500 1.000 0.408 1.000 0.331 0.331 0.331 0.331 0.331 0.331 0.331 0.331 0.460 0.460 0.331 0.331 0.331 0.331 0.331 0.331 0.331 0.331 0.331 0.430

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.060 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.120 0.060 0.000 0.060 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.060

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru CERJG2 CERJG3 DO1JG1 DOIJG1 DR6JG1 DR8JG1 DR8JG2 DROJG1 GILJG1 GILJG2 GR2JG1 GRZJG1 GUTJG1 GUTJG2 GUTJG3 GUTJG4 HOLJG1 HOLJG2 IA1JG1 IA1JG2 IE2JG1 IERJG1 IERJG2 IERJG3 IERJG4 IERJG5 IS2JG1 IS2JG2 LOTJG1 LOTJG2 LOTJG3 L-SJG1 L-SJG2 L-SJG3 MARJG1 MARJG2 MARJG3 MIAJG1 MIBJG1 MINJG1 MINJG2 MINJG3 MINJG4 OR3JG1 OR3JG2 OR3JG3 ORAJG1 ORAJG2 ORAJG3 OS1JG1 OZMJG1 P-1JG1 P-1JG2 PA1JG1 PALJG1 PARJG1 PARJG2 PARJG3 PARJG4 P-DJG1 P-DJG2 P-DJG3 P-DJG4 P-DJG5 P-DJG6 PITJG1 PITJG2 PROJG1 PROJG2

Name CERNAV.2 CERNAV.3 DOICEST8 DOICEST7 DROBETA4 DROBETA3 DROBETA1 DROBETA2 GALCEAG1 GALCEAG2 GROZAV 2 GROZAV 1 BORZEST7 BORZE I6 BORZE I4 BORZE I5 FAI II 1 FAI II 2 RUIENI 1 RUIENI 2 IERNUT 3 IERNUT 1 IERNUT 5 IERNUT 6 IERNUT 4 IERNUT 2 ISALNIT7 ISALNIT8 LOTRU 1 LOTRU 2 LOTRU 3 BRAILA 1 BRAILA 2 BRAILA 3 MARISEL1 MARISEL2 MARISEL3 MINTIA 2 MINTIA 4 MINTIA 1 MINTIA 5 MINTIA 3 MINTIA 6 ORAD I 4 ORAD I 6 ORAD I 5 ORAD II1 ORAD II2 ORAD II3 GRUIA12 GRUIA34 GRUIA78 GRUIA56 PALAS 2 PALAS 1 PAROS 4 PAROSEN1 PAROSEN2 PAROSEN3 P.D.F 1 P.D.F 2 P.D.F 3 P.D.F 4 P.D.F 5 P.D.F.6 PITEST 4 PITEST 5 PROGRS 1 PROGRS 2

XPD

XPQ

XSD

XSQ

1.810 1.810 1.920 1.920 2.096 2.096 2.096 2.096 0.996 0.996 2.000 2.000 1.880 2.096 2.096 2.096 2.096 2.096 1.045 1.045 1.850 1.850 2.200 2.200 1.850 1.850 2.300 2.300 1.050 1.050 1.050 2.200 2.200 2.200 0.996 0.996 0.996 2.200 2.200 2.200 2.200 2.200 2.200 2.200 2.200 2.200 2.096 2.096 2.096 1.000 1.000 1.000 1.000 2.096 2.096 2.067 1.730 1.730 1.730 1.140 1.140 1.140 1.140 1.140 1.407 1.657 1.657 2.000 2.000

1.690 1.690 1.920 1.920 2.096 2.096 2.096 2.096 0.610 0.610 2.000 2.000 1.880 2.096 2.096 2.096 2.096 2.096 0.624 0.624 1.850 1.850 2.200 2.200 1.850 1.850 2.300 2.300 0.680 0.680 0.680 2.200 2.200 2.200 0.610 0.610 0.610 2.200 2.200 2.200 2.200 2.200 2.200 2.200 2.200 2.200 2.096 2.096 2.096 0.700 0.700 0.700 0.700 2.096 2.096 2.067 1.730 1.730 1.730 0.840 0.840 0.840 0.840 0.840 1.407 1.657 1.657 2.000 2.000

0.335 0.335 0.276 0.276 0.280 0.280 0.280 0.280 0.167 0.167 0.242 0.242 0.270 0.280 0.280 0.280 0.280 0.280 0.212 0.212 0.187 0.187 0.290 0.290 0.187 0.187 0.362 0.362 0.323 0.323 0.323 0.249 0.249 0.249 0.167 0.167 0.167 0.249 0.249 0.249 0.249 0.249 0.249 0.200 0.200 0.200 0.280 0.280 0.280 0.420 0.420 0.420 0.420 0.280 0.280 0.319 0.190 0.190 0.190 0.380 0.380 0.380 0.380 0.380 0.453 0.309 0.309 0.242 0.242

0.540 0.540 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

0.260 0.260 0.212 0.212 0.189 0.189 0.189 0.189 0.151 0.151 0.156 0.156 0.191 0.189 0.189 0.189 0.189 0.189 0.164 0.164 0.162 0.162 0.190 0.190 0.162 0.162 0.251 0.251 0.237 0.237 0.237 0.190 0.190 0.190 0.151 0.151 0.151 0.190 0.190 0.190 0.190 0.190 0.190 0.125 0.125 0.125 0.189 0.189 0.189 0.300 0.300 0.300 0.300 0.189 0.189 0.212 0.128 0.128 0.128 0.316 0.316 0.316 0.316 0.316 0.342 0.176 0.176 0.156 0.156

0.170 0.170 0.146 0.146 0.100 0.100 0.100 0.100 0.120 0.120 0.100 0.100 0.120 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.137 0.137 0.120 0.120 0.137 0.137 0.150 0.150 0.160 0.160 0.160 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.100 0.100 0.100 0.100 0.100 0.100 0.120 0.120 0.120 0.120 0.100 0.100 0.120 0.100 0.100 0.100 0.240 0.240 0.240 0.240 0.240 0.100 0.100 0.100 0.100 0.100

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007 Page 74 (96)

K TPD0 damping 0.000 8.700 0.000 8.700 0.000 7.750 0.000 7.750 0.000 4.800 0.000 4.800 0.000 4.800 0.000 4.800 0.000 7.150 0.000 7.150 0.000 6.400 0.000 6.400 0.000 6.400 0.000 4.800 0.000 4.800 0.000 4.800 0.000 4.800 0.000 4.800 0.000 6.530 0.000 6.530 0.000 6.420 0.000 6.420 0.000 6.400 0.000 6.400 0.000 6.420 0.000 6.420 0.000 6.600 0.000 6.600 0.000 9.600 0.000 9.600 0.000 9.600 0.000 6.400 0.000 6.400 0.000 6.400 0.000 7.150 0.000 7.150 0.000 7.150 0.000 6.400 0.000 6.400 0.000 6.400 0.000 6.400 0.000 6.400 0.000 6.400 0.000 6.000 0.000 6.000 0.000 6.000 0.000 4.800 0.000 4.800 0.000 4.800 0.000 1.650 0.000 1.650 0.000 1.650 0.000 1.650 0.000 4.800 0.000 4.800 0.000 4.800 0.000 6.000 0.000 6.000 0.000 6.000 0.000 6.600 0.000 6.600 0.000 6.600 0.000 6.600 0.000 6.600 0.000 4.660 0.000 5.400 0.000 5.400 0.000 6.400 0.000 6.400

TPQ0 TSD0 TSQ0 TAA 0.430 0.430 0.284 0.284 0.331 0.331 0.331 0.331 0.347 0.347 0.460 0.460 0.284 0.331 0.331 0.331 0.331 0.331 0.268 0.268 0.250 0.250 0.284 0.284 0.250 0.250 0.916 0.916 0.088 0.088 0.088 0.284 0.284 0.284 0.347 0.347 0.347 0.284 0.284 0.284 0.284 0.284 0.284 0.250 0.250 0.250 0.331 0.331 0.331 0.100 0.100 0.100 0.100 0.331 0.331 0.409 0.250 0.250 0.250 0.210 0.210 0.210 0.210 0.210 0.286 0.331 0.331 0.460 0.460

0.060 0.060 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru R-MJG1 R-MJG2 SI3JG1 SI4JG1 SMIJG1 SMIJG2 STEJG1 STEJG2 STEJG3 SUGJG1 SUGJG2 TANJG1 TANJG2 TANJG3 TANJG4 TANJG5 TANJG6 UREJG1 UREJG2 UREJG3 UREJG4 UREJG5

Name RETEZAT1 RETEZAT2 CRAI II1 CRAI II2 SMARDAN6 SMARDAN4 STEJARU5 STEJARU6 STEJARU SUGAG 1 SUGAG 2 TURCENI1 TURCENI3 TURCENI4 TURCENI5 TURCENI6 TURCENI7 ROVIN 5 ROVIN 6 ROVIN 3 ROVIN 4 ROVIN 7

XPD

XPQ

XSD

XSQ

1.050 1.050 2.067 2.067 1.907 2.096 1.200 1.200 1.200 0.949 0.949 2.070 2.070 2.070 2.070 2.070 2.070 2.120 2.120 2.120 2.120 2.120

0.680 0.680 2.067 2.067 1.907 2.096 0.885 0.885 0.885 0.621 0.621 2.070 2.070 2.070 2.070 2.070 2.070 2.120 2.120 2.120 2.120 2.120

0.323 0.323 0.319 0.319 0.278 0.280 0.328 0.328 0.328 0.256 0.256 0.340 0.340 0.340 0.340 0.340 0.340 0.330 0.330 0.330 0.330 0.330

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

0.237 0.237 0.212 0.212 0.192 0.189 0.206 0.206 0.206 0.195 0.195 0.234 0.234 0.234 0.234 0.234 0.234 0.240 0.240 0.240 0.240 0.240

0.160 0.160 0.120 0.120 0.110 0.100 0.100 0.100 0.100 0.120 0.120 0.210 0.210 0.210 0.210 0.210 0.210 0.210 0.210 0.210 0.210 0.210

November, 2007 Page 75 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K TPD0 damping 0.000 9.600 0.000 9.600 0.000 4.800 0.000 4.800 0.000 7.750 0.000 4.800 0.000 6.400 0.000 6.400 0.000 6.400 0.000 6.530 0.000 6.530 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130 0.000 6.130

TPQ0 TSD0 TSQ0 TAA 0.088 0.088 0.409 0.409 0.331 0.331 0.178 0.178 0.178 0.268 0.268 0.724 0.724 0.724 0.724 0.724 0.724 0.724 0.724 0.724 0.724 0.724

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.8 Serbia Generator parameter CodGru JH1MG1 JH1MG2 JH3MG0 JH3MG1 JH3MG2 JH3MG3 JH3MG4 JH3MG5 JH3MG6 JH3MG7 JH3MG8 JH3MG9 JH4MG1 JH4MG2 JH6MG1 JH6MG2 JH7MG1 JH7MG2 JHBMG1 JHBMG2 JHDMG1 JHDMG2 JHDMG3 JHDMG4 JHDMG5 JHDMG6 JHKMG1 JHKMG2 JHPMG1 JHPMG2 JHUMG1 JHVMG1 JHVMG2 JHVMG3 JHVMG4 JHZMG1 JHZMG2 JHZMG3 JHZMG4 JR1MG1 JRHMG1 JT1MG1

Name JHBBASG3 JHBBASG4 JHDJE2G9 JHDJE2G1 JHDJE2G1 JHDJE2G3 JHDJE2G3 JHDJE2G5 JHDJE2G5 JHDJE2G7 JHDJE2G7 JHDJE2G9 JHPOTPG2 JHPOTPG3 JHVRL2G1 JHVRL2G2 JHVRL3G1 JHVRL3G2 JHBBASG1 JHBBASG2 JHDJERG1 JHDJERG1 JHDJERG3 JHDJERG3 JHDJERG5 JHDJERG5 JHKBROG1 JHKBROG2 JHPIROG1 JHPIROG2 JHUVACG1 JHVRL1G1 JHVRL1G2 JHVRL1G3 JHVRL1G4 JHZVORG1 JHZVORG2 JHZVORG3 JHZVORG4 JRHBBAG2 JRHBBAG1 JTENTAG6

XPD

XPQ

XSD

XSQ

0.860 0.860 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.175 1.175 1.160 1.160 1.370 1.370 0.860 0.860 1.000 1.245 1.000 1.246 1.000 1.246 1.040 1.040 1.257 1.257 1.257 1.308 1.308 1.308 1.308 1.475 1.475 1.475 1.475 1.232 1.232 2.140

0.590 0.590 0.700 0.700 0.700 0.700 0.700 0.700 0.700 0.700 0.700 0.700 0.649 0.649 0.703 0.703 0.703 0.703 0.590 0.590 0.700 0.925 0.700 0.930 0.700 0.930 0.580 0.580 0.720 0.720 0.720 1.000 1.000 1.000 1.000 0.770 0.770 0.770 0.770 0.780 0.780 2.070

0.300 0.300 0.300 0.300 0.420 0.300 0.420 0.300 0.420 0.300 0.420 0.420 0.357 0.357 0.343 0.343 0.343 0.343 0.300 0.300 0.300 0.373 0.300 0.382 0.300 0.382 0.310 0.310 0.416 0.416 0.416 0.343 0.343 0.343 0.343 0.400 0.400 0.400 0.400 0.279 0.279 0.290

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.440

0.200 0.200 0.200 0.200 0.300 0.200 0.300 0.200 0.300 0.200 0.300 0.300 0.211 0.211 0.305 0.305 0.305 0.305 0.200 0.200 0.200 0.303 0.200 0.330 0.200 0.330 0.149 0.149 0.200 0.200 0.200 0.227 0.227 0.227 0.227 0.278 0.278 0.278 0.278 0.174 0.174 0.229

0.140 0.140 0.100 0.100 0.120 0.100 0.120 0.100 0.120 0.100 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.140 0.140 0.100 0.150 0.100 0.150 0.100 0.150 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.120 0.130 0.130 0.130

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

K TPD0 damping 0.000 6.400 0.000 6.400 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 4.600 0.000 4.600 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 6.400 0.000 6.400 0.000 5.000 0.000 6.500 0.000 5.000 0.000 7.400 0.000 5.000 0.000 7.400 0.000 4.600 0.000 4.600 0.000 2.000 0.000 2.000 0.000 2.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 11.040 0.000 11.040 0.000 7.450

TPQ0 TSD0 TSQ0 TAA 0.030 0.030 0.210 0.210 0.060 0.210 0.060 0.210 0.060 0.210 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.030 0.030 0.210 0.042 0.210 0.042 0.210 0.042 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.060 0.040 0.040 0.310

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru JT2MG1 JT3MG1 JT6MG1 JT7MG1 JT8MG1 JT9MG1 JTDMG1 JTDMG2 JTEMG1 JTGMG1 JTGMG2 JTGMG3 JTGMG4 JTGMG5 JTHMG1 JTHMG2 JTIMG1 JTIMG2 JTJMG1 JTKMG1 JTKMG2 JTMMG1 JTTMG1 JTTMG2 JH2MG1 JH2MG1 JH2MG1 JH2MG2 JH2MG2

Name JTENTBG1 JTENTBG2 JTENTAG1 JTENTAG2 JTENTAG3 JTENTAG4 JTDRMNG1 JTDRMNG2 JTENTAG5 JTKOLUG1 JTKOLUG2 JTKOLUG3 JTKOLUG4 JTKOLUG5 JTKSTAG1 JTKSTAG2 JTTNSAG1 JTTNSAG2 JTTZREG1 JTKOLBG1 JTKOLBG2 JTMORAG1 JTTBGDG1 JTTBGDG2 JHBISTG1 JHBISTG1 JHBISTG1 JHBISTG2 JHBISTG2

XPD

XPQ

XSD

XSQ

2.560 2.560 1.932 1.932 2.025 2.025 2.390 2.390 2.140 1.400 1.400 2.250 2.100 2.120 1.795 1.932 1.830 1.830 1.830 2.390 2.390 1.830 1.830 1.830 1.000 0.000 0.000 1.000 0.000

2.510 2.510 1.900 1.900 2.140 2.140 2.340 2.340 2.070 1.350 1.350 2.000 2.000 2.000 1.400 1.900 1.810 1.810 1.810 2.340 2.340 1.810 1.810 1.810 0.700 0.000 0.000 0.700 0.000

0.380 0.380 0.312 0.312 0.306 0.300 0.320 0.320 0.290 0.300 0.300 0.207 0.270 0.270 0.263 0.312 0.305 0.305 0.305 0.320 0.320 0.305 0.305 0.305 0.300 0.000 0.000 0.300 0.000

0.570 0.570 0.340 0.340 0.440 0.440 0.560 0.560 0.440 0.600 0.600 0.600 0.600 0.600 0.500 0.500 0.600 0.600 0.600 0.560 0.560 0.600 0.600 0.600 0.000 0.000 0.000 0.000 0.000

0.240 0.240 0.198 0.198 0.229 0.230 0.239 0.239 0.229 0.145 0.145 0.140 0.145 0.159 0.183 0.198 0.247 0.247 0.247 0.239 0.239 0.247 0.247 0.247 0.200 0.000 0.000 0.200 0.000

0.144 0.144 0.166 0.166 0.130 0.130 0.190 0.190 0.130 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.190 0.190 0.100 0.100 0.100 0.100 0.000 0.000 0.100 0.000

November, 2007 Page 76 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.000 0.000 0.150 0.000

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 0.000 0.000 1.000 0.000

K TPD0 damping 0.000 7.300 0.000 7.300 0.000 6.850 0.000 6.850 0.000 7.400 0.000 7.400 0.000 7.290 0.000 7.290 0.000 7.450 0.000 6.000 0.000 6.000 0.000 6.000 0.000 6.000 0.000 6.000 0.000 6.000 0.000 6.850 0.250 5.000 0.250 5.000 0.000 5.000 0.000 7.290 0.000 7.290 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.000 0.000 0.000 0.000 0.000 0.000 5.000 0.000 0.000

TPQ0 TSD0 TSQ0 TAA 0.310 0.310 0.340 0.340 0.310 0.310 0.260 0.260 0.310 1.000 1.000 1.000 1.000 1.000 1.000 0.340 1.000 1.000 1.000 0.260 0.260 1.000 1.000 1.000 0.210 0.000 0.000 0.210 0.000

0.010 0.010 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.010 0.020 0.020 0.020 0.000 0.000 0.020 0.000

0.042 0.042 0.041 0.041 0.035 0.035 0.029 0.029 0.035 0.050 0.050 0.050 0.050 0.050 0.050 0.041 0.025 0.025 0.025 0.029 0.029 0.019 0.025 0.025 0.000 0.000 0.000 0.000 0.000

0.010 0.010 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.010 0.020 0.020 0.020 0.000 0.000 0.020 0.000

Table A 5.9 Bosnia-Herzegovina Generator parameter CodGru BOCCG1 BOCCG2 GRACG1 GRACG2 HE1CG1 HE1CG2 HE2CG1 HE2CG2 HE3CG1 HE3CG2 HE3CG3 HECCG1 HECCG2 HEJCG1 HEJCG2 HEJCG3 HEJCG4 HEJCG5 HEJCG6 HEMCG1 HEMCG2 HEMCG3 HERCG1 HERCG2 HETCG1 HETCG2 HETCG3 HEVCG1 HEVCG2 HEVCG3 KAKCG1 SALCG1 SALCG2 SALCG3 TEGCG1

Name BOCACG1 BOCACG2 GRAB-G1 GRAB-G2 JAJ1-G1 JAJ1-G2 MLINI-G1 MLINI-G2 JAJ2-G1 JAJ2-G2 JAJ2-G3 CAPL-G1 CAPL-G2 JAB-G1 JAB-G2 JAB-G3 JAB-G4 JAB-G5 JAB-G6 MOST-G1 MOST-G2 MOST-G3 RAMA G1 RAMA G2 HE TREB HE TREB HE TREB HE VISE HE VISE HE VISE KAK-G7 SAL-G1 SAL-G2 SAL-G3 GACKO

XPD

XPQ

XSD

XSQ

0.920 0.920 1.100 1.100 1.100 1.100 1.000 1.000 1.460 1.460 1.460 1.400 1.400 1.260 1.260 1.260 1.500 1.500 1.500 1.030 1.030 1.030 0.905 0.905 1.000 1.000 0.890 1.000 1.000 0.981 2.000 1.173 1.173 1.173 1.700

0.550 0.550 0.650 0.650 0.660 0.400 0.700 0.700 0.700 0.700 0.700 0.950 0.950 0.650 0.650 0.650 0.757 0.757 0.757 0.620 0.620 0.620 0.540 0.540 0.700 0.700 0.500 0.700 0.700 0.562 1.920 0.673 0.673 0.673 1.630

0.340 0.340 0.320 0.320 0.270 0.300 0.300 0.300 0.350 0.350 0.350 0.400 0.400 0.417 0.417 0.417 0.373 0.373 0.373 0.371 0.371 0.371 0.320 0.320 0.300 0.300 0.297 0.300 0.300 0.352 0.237 0.343 0.343 0.343 0.260

0.210 0.210 0.209 0.209 0.230 0.230 0.200 0.200 0.220 0.220 0.220 0.250 0.250 0.277 0.277 0.277 0.296 0.296 0.296 0.215 0.215 0.215 0.170 0.170 0.200 0.200 0.227 0.200 0.200 0.234 0.177 0.192 0.192 0.192 0.173

0.100 0.100 0.110 0.110 0.110 0.110 0.100 0.100 0.140 0.140 0.140 0.130 0.130 0.126 0.126 0.126 0.157 0.157 0.157 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.120 0.120 0.120 0.100

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

K TPD0 damping 0.000 3.757 0.000 3.757 0.000 6.035 0.000 6.035 0.000 5.490 0.000 5.490 0.000 5.000 0.000 5.000 0.000 5.490 0.000 5.490 0.000 5.490 0.000 3.140 0.000 3.140 0.000 2.530 0.000 2.530 0.000 2.530 0.000 7.320 0.000 7.320 0.000 7.320 0.000 1.360 0.000 1.360 0.000 1.360 0.000 4.000 0.000 4.000 0.000 5.000 0.000 5.000 0.000 5.570 0.000 5.000 0.000 5.000 0.000 4.476 0.000 7.750 0.000 5.060 0.000 5.060 0.000 5.060 0.000 5.900

TPQ0 TSD0 TSQ0 TAA 0.050 0.050 0.050 0.050 0.050 0.050 0.210 0.210 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.050 0.210 0.210 0.050 0.210 0.210 0.050 0.500 0.050 0.050 0.050 1.500

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru TEKCG1 TEKCG2 TETCG1 TETCG2 TETCG3 TUZCG1 UGLCG1

Name KAK-G5 KAK-G6 TUZ-G4 TUZ-G5 TUZ-G3 TUZ-G6 TE UGLJE

XPD

XPQ

XSD

XSQ

2.000 2.150 1.740 1.725 1.635 1.772 1.700

1.920 2.060 1.670 1.660 1.570 1.700 1.630

0.210 0.232 0.273 0.273 0.263 0.295 0.260

0.500 0.540 0.430 0.430 0.300 0.430 0.400

0.152 0.167 0.190 0.190 0.183 0.205 0.173

0.100 0.078 0.090 0.090 0.078 0.090 0.100

November, 2007 Page 77 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000

K TPD0 damping 0.000 4.300 0.000 4.300 0.000 6.530 0.000 6.400 0.000 6.500 0.000 6.400 0.000 5.900

TPQ0 TSD0 TSQ0 TAA 0.540 0.540 1.500 1.500 0.500 1.500 1.500

0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.076 0.076 0.141 0.141 0.070 0.141 0.042

0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.10 Croatia Generator parameter CodGru EL-DG1 EL-DG2 HE1DG1 HE2DG1 HE2DG2 HE3DG1 HE3DG2 HECDG1 HECDG2 HEDDG1 HEDDG2 HEGDG1 HEGDG2 HEGDG3 HEODG1 HEODG2 HEODG3 HEPDG1 HEPDG2 HERDG1 HERDG2 HESDG1 HESDG2 HESDG3 HEVDG1 HEVDG2 HEVDG3 HEZDG1 HEZDG2 HEZDG3 HEZDG4 HLEDG1 HLEDG2 HPODG1 HPODG2 JERDG1 JERDG2 JERDG3 JERDG4 KRADG1 KRADG2 KRADG3 KRADG4 KRADG5 MELDG1 OBRDG1 OBRDG2 OS1DG1 OS1DG2 OS1DG3 PLADG1 PLADG2 TE-DG1 TE-DG2 TE-DG3 TE-DG4 TE-DG5

Name EL-TOG1 EL-TOG2 HESKLOG1 HEVARAG1 HEVARAG2 HEDJALG1 HEDJALG2 HECAKOG1 HECAKOG2 HEDUBRG1 HEDUBRG2 HEGOJAG1 HEGOJAG2 HEGOJAG3 HEORLOG1 HEORLOG2 HEORLOG3 HEPERUG1 HEPERUG2 HERIJEG1 HERIJEG2 HESENJG1 HESENJG2 HESENJG3 HEVINOG1 HEVINOG2 HEVINOG3 HEZAKUG1 HEZAKUG2 HEZAKUG3 HEZAKUG4 HLESCG1 HLESCG2 HPODSG1 HPODSG2 JERTOVG1 JERTOVG2 JERTOVG3 JERTOVG4 KRALJEVG KRALJEVG KRALJEVG KRALJEVG KRALJEV1 KTERIJG1 RHEOBRG1 RHEOBRG2 TE-TOOG1 KTEOSGT KTEOSST HEDUBRG1 HEDUBRG2 TE-TOG1 TE-TOG2 TE-TOG3 TE-TOG4 TE-TOG5

XPD

XPQ

XSD

XSQ

1.250 1.250 1.180 1.140 1.140 1.100 1.100 1.490 1.490 1.346 1.345 1.390 1.390 1.390 0.950 0.950 0.950 1.130 1.130 1.200 1.200 1.300 1.300 1.300 1.200 1.200 1.200 0.902 0.900 0.902 0.900 1.130 1.130 1.200 1.200 1.700 1.700 2.490 2.490 1.000 1.000 1.000 1.250 2.053 1.900 1.020 1.020 1.900 2.053 2.053 0.938 0.938 2.230 1.930 1.850 2.159 2.159

1.220 1.220 0.670 0.700 0.700 0.630 0.630 0.940 0.940 0.940 0.940 0.720 0.720 0.720 0.540 0.540 0.540 0.680 0.680 0.670 0.670 0.650 0.650 0.650 0.800 0.800 0.800 0.591 0.500 0.591 0.500 0.680 0.680 0.800 0.800 1.650 1.650 2.470 2.470 0.700 0.700 0.700 0.750 1.972 1.800 0.560 0.560 1.850 1.972 1.972 0.552 0.552 2.050 1.930 1.770 2.058 2.058

0.232 0.232 0.320 0.349 0.349 0.360 0.360 0.420 0.420 0.446 0.446 0.420 0.420 0.420 0.280 0.280 0.280 0.370 0.370 0.320 0.320 0.255 0.255 0.255 0.280 0.280 0.280 0.342 0.400 0.342 0.400 0.370 0.370 0.280 0.280 0.188 0.188 0.330 0.330 0.300 0.300 0.300 0.300 0.294 0.240 0.285 0.285 0.240 0.294 0.294 0.285 0.285 0.340 0.214 0.280 0.316 0.316

0.715 0.715 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.400 0.400 0.750 0.750 0.000 0.000 0.000 0.000 0.382 0.960 0.000 0.000 0.500 0.382 0.382 0.000 0.000 0.680 0.680 1.120 0.462 0.462

0.120 0.120 0.210 0.240 0.240 0.220 0.220 0.340 0.340 0.330 0.330 0.220 0.220 0.220 0.183 0.183 0.183 0.240 0.240 0.200 0.200 0.141 0.141 0.141 0.160 0.160 0.160 0.212 0.220 0.212 0.220 0.240 0.240 0.160 0.160 0.139 0.139 0.250 0.250 0.200 0.200 0.200 0.200 0.203 0.150 0.196 0.196 0.105 0.203 0.203 0.216 0.216 0.203 0.145 0.210 0.162 0.162

0.104 0.104 0.100 0.150 0.150 0.180 0.180 0.210 0.210 0.243 0.243 0.130 0.130 0.130 0.165 0.165 0.165 0.150 0.150 0.130 0.130 0.130 0.130 0.130 0.135 0.135 0.135 0.129 0.100 0.129 0.100 0.150 0.150 0.135 0.135 0.104 0.104 0.104 0.104 0.100 0.100 0.100 0.110 0.120 0.120 0.130 0.130 0.100 0.120 0.120 0.205 0.205 0.150 0.100 0.170 0.100 0.100

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

K TPD0 damping 0.000 4.750 0.000 4.750 0.000 4.310 0.000 3.100 0.000 3.100 0.000 5.010 0.000 5.010 0.000 3.000 0.000 3.000 0.000 1.660 0.000 1.660 0.000 5.500 0.000 5.500 0.000 5.500 0.000 6.790 0.000 6.786 0.000 6.786 0.000 5.010 0.000 5.010 0.000 4.310 0.000 4.310 0.000 7.340 0.000 7.340 0.000 7.341 0.000 6.000 0.000 6.000 0.000 6.000 0.000 8.880 0.000 2.700 0.000 8.880 0.000 2.700 0.000 5.010 0.000 5.010 0.000 6.000 0.000 6.000 0.000 4.750 0.000 4.750 0.000 5.130 0.000 5.130 0.000 5.000 0.000 5.000 0.000 5.000 0.000 5.400 0.000 6.600 0.000 6.000 0.000 9.800 0.000 9.800 0.000 4.990 0.000 6.600 0.000 6.600 0.000 4.440 0.000 4.440 0.000 7.220 0.000 7.150 0.000 4.720 0.000 6.652 0.000 6.652

TPQ0 TSD0 TSQ0 TAA 1.500 1.500 0.099 0.099 0.099 0.099 0.099 0.097 0.097 0.099 0.099 0.087 0.087 0.087 0.058 0.058 0.058 0.099 0.099 0.099 0.099 0.075 0.075 0.075 0.071 0.071 0.071 0.090 0.099 0.099 0.099 0.099 0.099 0.071 0.071 1.500 1.500 1.500 1.500 0.210 0.210 0.210 0.075 1.000 0.500 0.099 0.099 0.500 1.000 1.000 0.099 0.099 0.500 0.500 0.500 0.466 0.466

0.090 0.090 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.099 0.099 0.099 0.099 0.000 0.000 0.000 0.000 0.060 0.099 0.000 0.000 0.099 0.060 0.060 0.000 0.000 0.054 0.054 0.099 0.465 0.465

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru TE-DG6 TE-DG7 TEPDG1 TEPDG2 TERDG1 TESDG1 TESDG2 TESDG3

Name KTEZGGT KTEZGST TEPLOMG1 TEPLOMG2 TERIJEG1 TESISAG2 KTESISGT KTESISST

XPD

XPQ

XSD

XSQ

2.053 2.053 1.830 1.830 1.900 1.930 2.053 2.053

1.972 1.972 1.820 1.820 1.800 1.800 1.972 1.972

0.294 0.294 0.305 0.305 0.240 0.312 0.294 0.294

0.382 0.382 0.600 0.600 0.960 0.600 0.382 0.382

0.203 0.203 0.212 0.212 0.150 0.198 0.203 0.203

0.120 0.120 0.170 0.170 0.120 0.180 0.120 0.120

November, 2007 Page 78 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K TPD0 damping 0.000 6.600 0.000 6.600 0.000 5.000 0.000 5.000 0.000 6.000 0.000 6.870 0.000 6.600 0.000 6.600

TPQ0 TSD0 TSQ0 TAA 1.000 1.000 0.500 0.500 0.500 0.500 1.000 1.000

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.060 0.060 0.099 0.099 0.099 0.099 0.060 0.060

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

Table A 5.11 Slovenia Generator parameter CodGru LH1KG1 LH2KG1 LH2KG2 LH2KG3 LH2KG4 LH3KG1 LH3KG2 LH3KG3 LH4KG1 LH4KG2 LH4KG3 LH4KG4 LH5KG1 LH5KG2 LH5KG3 LH6KG1 LH6KG2 LH6KG3 LH7KG1 LH7KG2 LH8KG1 LHAKG1 LHDKG1 LHDKG2 LHDKG3 LHEKG1 LHFKG1 LHFKG2 LHMKG1 LHMKG2 LHOKG1 LHOKG2 LHOKG3 LHPKG1 LHPKG2 LHRKG1 LHRKG2 LHRKG3 LHSKG1 LHSKG2 LHSKG3 LHUKG1 LHUKG2 LHUKG3 LKRKG1 LT1KG1 LT2KG1 LT2KG2 LT2KG3 LT3KG1 LT3KG2 LT3KG3 LT4KG1 LT4KG2 LT4KG3

Name

XPD

XPQ

XSD

XSQ

LHEMEDG1 LHEMOSG3 LHEMOSG2 LHEMOSG1 LHEMOSG4 LHEVUZG1 LHEVUZG3 LHEVUZG2 LHEDOBG3 LHEDOBG2 LHEDOBG1 LHEDOBG4 LHEFALG1 LHEFALG2 LHEFALG3 LHEMARG3 LHEMARG2 LHEMARG1 LHEZLAG2 LHEZLAG1 LHEMEDG2 LHAVCH51 LHEDRAG2 LHEDRAG1 LHEDRAG3 LHEPLAG2 LHEFORG2 LHEFORG1 LHEMAVG2 LHEMAVG1 LHEOZBG3 LHEOZBG2 LHEOZBG1 LHEPLAG1 LHEPLAG3 LHESOLG LHESOLG LHESOLG LHEVRHG3 LHEVRHG3 LHEVRHG3 LHEVUHG3 LHEVUHG2 LHEVUHG1 LNEK G LTES4 G LTETOLG3 LTETOLG2 LTETOLG1 LTES G3 LTES G2 LTES G1 LTEBPA14 LTEBPA15 LTEBPAG3

1.175 1.042 1.052 1.037 1.037 1.050 1.050 1.050 1.355 1.355 1.455 1.355 1.010 1.070 1.070 0.940 0.940 0.940 0.920 0.920 1.253 1.204 1.050 1.050 1.050 1.190 0.920 0.920 1.265 1.265 1.301 1.301 1.301 1.190 1.190 1.000 1.000 1.100 1.000 1.000 1.190 1.050 1.050 1.301 1.225 2.200 1.790 1.960 1.900 1.780 1.780 1.665 2.220 2.220 2.220

0.620 0.542 0.557 0.589 0.589 0.800 0.800 0.800 0.934 0.803 0.838 0.934 0.651 0.663 0.663 0.631 0.631 0.631 0.631 0.631 0.620 0.701 0.800 0.800 0.800 0.690 0.640 0.640 0.616 0.616 0.766 0.766 0.766 0.690 0.690 0.700 0.700 0.660 0.700 0.700 0.730 0.800 0.800 0.766 1.220 2.170 1.210 1.830 1.830 1.710 1.710 1.650 2.220 2.220 2.220

0.460 0.302 0.277 0.317 0.317 0.450 0.450 0.450 0.526 0.412 0.382 0.526 0.360 0.410 0.410 0.342 0.342 0.342 0.381 0.373 0.463 0.319 0.450 0.450 0.450 0.410 0.373 0.373 0.415 0.415 0.468 0.468 0.468 0.410 0.410 0.300 0.300 0.410 0.300 0.300 0.380 0.450 0.450 0.468 0.261 0.396 0.200 0.229 0.229 0.235 0.235 0.258 0.184 0.184 0.184

0.211 0.142 0.137 0.137 0.137 0.290 0.290 0.290 0.308 0.387 0.380 0.308 0.280 0.280 0.280 0.258 0.258 0.258 0.237 0.237 0.272 0.211 0.250 0.250 0.250 0.250 0.237 0.237 0.324 0.324 0.303 0.303 0.303 0.250 0.250 0.200 0.200 0.252 0.200 0.200 0.324 0.290 0.290 0.303 0.208 0.306 0.136 0.160 0.160 0.180 0.180 0.204 0.134 0.134 0.134

0.150 0.120 0.120 0.120 0.120 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.200 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.100 0.100 0.120 0.100 0.100 0.120 0.150 0.150 0.150 0.150 0.150 0.100 0.119 0.150 0.150 0.150 0.150 0.150 0.150 0.150

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K damping 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.100 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100

TPD0 TPQ0 TSD0 TSQ0 TAA 7.310 7.300 7.300 7.300 7.300 4.700 4.700 4.700 3.000 3.000 3.000 3.000 5.000 3.840 3.840 4.700 4.700 4.700 5.000 5.100 7.310 6.000 7.310 7.310 7.310 3.400 5.100 5.100 4.960 7.337 3.730 3.730 3.730 3.400 3.400 5.000 5.000 3.179 5.000 5.000 3.125 4.700 4.700 3.730 6.421 5.857 8.393 8.651 8.500 6.120 6.120 5.623 9.600 9.600 9.600

0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.200 0.200 0.200 0.200 0.200 0.200 0.100 0.100 0.100 0.100 0.080 0.080 0.080 0.060 0.200 0.200 0.176 0.080 0.100 0.100 0.100 0.060 0.060 0.210 0.210 0.100 0.210 0.210 0.100 0.100 0.100 0.100 1.500 1.500 0.500 0.500 0.500 1.500 1.500 1.500 1.500 1.500 1.500

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment CodGru LT4KG4 LT4KG5 LT4KG6 LT4KG7 LT5KG1 LT5KG2 LT5KG3 LTEKG1

1.2

Name LTEBPAG2 LTEBPAG1 LTEBTAG2 LTEBTAG1 LTETTAG4 LTETPAG2 LTETPAG1 LTES5 G

XPD

XPQ

XSD

XSQ

2.220 2.220 1.700 1.700 1.900 0.410 0.410 1.990

2.220 2.220 1.700 1.700 1.830 0.400 0.400 1.900

0.184 0.184 0.170 0.170 0.210 0.338 0.338 0.365

1.000 1.000 0.725 0.725 1.000 0.339 0.339 0.725

0.134 0.134 0.129 0.129 0.140 0.268 0.268 0.306

0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

November, 2007 Page 79 (96)

SATUR SIGMA 0.150 0.150 0.150 0.150 0.150 0.150 0.150 0.150

1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

K damping 0.100 0.100 0.100 0.100 0.100 0.100 0.100 0.100

TPD0 TPQ0 TSD0 TSQ0 TAA 9.600 9.600 8.700 8.700 5.000 5.344 5.344 7.740

1.500 1.500 1.500 1.500 0.500 1.500 1.500 1.500

0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

0.033 0.033 0.033 0.033 0.029 0.044 0.044 0.044

Voltage regulators and excitation systems

The block diagrams of the two types of voltage regulators and excitation systems that have been used are shown in the fig. 1, 2. The excitation system illustrate are: The parameters of the voltage regulators utilized for the simulation are given in Table ..

Figure A 5.1 Block diagram of IEEE Type AC4A Excitation System

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0.020 0.020 0.020 0.020 0.020 0.020 0.020 0.020

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Figure A 5.2 Block diagram of IEEE Type ST1A Excitation System 1.3

Check of the Excitation’s system performance

UNIT 37530 KTKOSBG1, EQUIPPED WITH A ESAC4A MODEL: Exciter parameters: TR

VIMAX

VIMIN

0.000

0.200

-0.200

1.100

TB 10.000

VRMAX

VRMIN

200.0

0.080

6.000

-5.500

0.050

Initial condition: 1.0 pu (Terminal Voltage) Step: 0.050 pu

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Figure A 5.3 Exciter type ESAC4A – Step response UNIT 37730 KTKOSCG1, EQUIPPED WITH A ESST1A MODEL: Exciter parameters: UEL VOS 0 TA 0.100

VIMAX

VIMIN

0.040

0.200

-0.200

1.500

VAMAX 8.000

VAMIN -8.000

VRMAX 7.800

VRMIN -6.700

KC 0.080

Initial condition: 1.0 pu (Terminal Voltage) Step: 0.050 pu

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TB 10.000

TC1

TB1

0.000

190.0

KF 0.020

TF 0.800

KLR 0.000

ILR 0.000

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Figure A 5.4 Exciter type ESST1A – Step response REPORT FOR GENERATOR MODELS UNIT 37730 KTKOSCG1 24. kV MBASE: 742.0 MVA T'D0 T''D0 S(1.2)

T'Q0 T''Q0

7.30 0.020 0.4000

0.31 0.042

1.80

DAMP

X'D

X'Q

X''D

1.00 2.5600 2.5100 0.3800 0.5700 0.2400 0.1440

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S(1.0) 0.0300

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1.4

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Check of the Governor’s performance

Introduction The Governors control system, regarding some of the units implemented in the Data Base, have been checked to simulates the response of the governing loops to a step change in load. This activity is executed with the generator unit in isolated condition. The models implemented in the Data Base are: Governors implemented in the Data Base: • • • • • •

TGOV1: Steam Turbine-Governor IEEEG1: IEEE Type 1 Speed-Governing Model IEEEG3: IEEE Type 3 Speed-Governing Model GAST: Gas Turbine-Governor TGOV3: Modified IEEE Type 1 Speed-Governing Model With Fast Valving HYGOV: Hydro Turbine-Governor

Figure A 5.5 TGOV1 - Steam Turbine-Governor

Figure A 5.6 IEEEG1 - IEEE Type 1 Speed-Governing Model

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Figure A 5.7 IEEEG3 - IEEE Type 3 Speed-Governing Model

Figure A 5.8 GAST - Gas Turbine-Governor

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Figure A 5.9 TGOV3 - Modified IEEE Type 1 Speed-Governing Model With Fast Valving

Figure A 5.10 HYGOV - Hydro Turbine-Governor

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UNIT 13405 NKOZ_G10 (1111.0 MVA), equipped with a IEEEG1 model: Governor parameters: K 25.00 K2 0.000

T1 5.000 T5 2.000

T2 1.500 K3 0.250

INITIAL CONDITION: Step: 0.10 pu

T3 0.300 K4 0.000

UO 1.050 T6 0.100

UC PMAX PMIN -1.050 1.0500 0.0000 K5 0.250

K6 0.000

T7 0.100

T4 0.150 K7 0.250

K1 0.250 K8 0.000

0.8 PU

Figure A 5.11 Governor type IEEEG1 – Step response

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UNIT 35001 JHDJERG1 (190.0 MVA), equipped with a IEEEG3 model: Governor parameters: TG

PMAX

PMIN

SIGMA

DELTA

0.200

0.040 TR

0.150 TW

-0.150 A11

0.913 A13

0.421 A21

0.060 A23

0.300

2.800

0.700

0.500

1.000

1.500

1.000

INITIAL CONDITION: Step: 0.10 pu

0.8 PU

Figure A 5.12 Governor type IEEEG3 – Step response

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UNIT 24034 MDUME 2 (259.0 MVA), equipped with a GAST model: Governor parameters: R

LOAD LIM

VMAX

VMIN

0.080

0.200

0.100

3.000

1.000

2.000

0.786

0.000

1.000

INITIAL CONDITION: Step: 0.10 pu

0.8 PU

Figure A 5.13 Governor type GAST – Step response

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UNIT 22354 KARDIA G1 (353.0 MVA), equipped with a TGOV1 model: Governor parameters: R

VMAX

VMIN

0.040

0.300

1.000

0.000

2.000

8.000

0.300

Initial condition: 0.8 pu Step: 0.10 pu

Figure A 5.14 Governor type TGOV1 – Step response

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UNIT 20348 TERIJEG1 (376.5 MVA), equipped with a TGOV3 model: Governor parameters: T4 0.110

20.00 K1

0.020 T5

1.400 K2

0.100 T6

0.275

4.000

INITIAL CONDITION: Step: 0.10 pu

0.425

0.424

PMAX

PMIN

0.400 -0.500 0.6013 0.0000 K3 TA TB TC 0.300

0.280

0.950

3.630

PRMAX 1.1000

0.8 PU

Figure A 5.15 Governor type TGOV3 – Step response

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UNIT 22302 QHSAUROS G2 (467.0 MVA), EQUIPPED WITH A HYGOV MODEL: Governor parameters: R-PERM R-TEMP 0.30

0.300 25.00 0.099 0.900

VELM

GMAX

GMIN

0.200

0.80

0.38

2.20

AT DTURB

QNL

1.20 0.30 0.080

Initial condition: 0.8 pu Step: 0.10 pu

Figure A 5.16 Governor type HYGOV – Step response

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6. Annex 6 Results of Short Circuit Calculation Table A 6.1 Year 2012 Short circuit currents of 400kV and 220kV network of Kosovo Variant 1 Bus Name

Vnom kV

Three-phase

Variant 2

Single-phase

Variant 3

Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

22.71 22.80 9.34 24.09 30.13 28.60 16.16 19.19 18.04 16.16

15,737 15,795 6,472 9,180 11,482 10,897 6,159 7,313 6,876 6,159

22.49 22.88 9.32 28.21 30.77 29.00 18.07 19.41 18.24 18.07

15,579 15,848 6,456 10,750 11,724 11,052 6,884 7,396 6,948 6,884

23.42 24.06 6.52 27.97 32.57 31.20 15.24 15.90 14.63 15.24

13.90 10.92

4,161

13.74 10.94

4,168

13.77

Kosovo C 400 Kosovo B 400 Peja 400 Kosovo C 220 Kosovo B 220 Kosovo A 220 Prishtina 4 Gllogovc Ferronikel Prizren 220

400 400 400 220 220 220 220 220 220 220

22.54 22.62 9.33 30.21 29.63 29.73 19.14 19.01 17.89 19.14

15,613 15,668 6,462 11,513 11,291 11,327 7,293 7,245 6,815 7,293

Ferizaj 220

220 10.98

4,185

23.66 23.88 6.54 32.54 30.28 32.21 16.52 15.42 14.22 16.52

24.00 24.15 6.55 23.19 31.71 30.77 13.61 15.73 14.48 13.61

Table A 6.2 Year 2012 Short circuit currents of 110kV network of Kosovo Bus Name

Vnom kV

KTKOSA5 KPRIS45 KPRIS15 KPRIS55 KPRIS65 KCRKVO5 KPRIS35 KMAZGI5 KPRIS25 KPEC3 5 KFKOSO5 KUROSE5 KPRIZ25 KISTOK5 KLIPLJ5 KSHTIM5 KPRIZ15 KVALAC5 KPRIZ35 KUROS15 KDJAK25 KDJAK15 KMITR25 KSREKA5 KVUCIT5 KSUPKO5 KKLINA5 KPEC 5 KGNJIL5 KPEC2 5 KGNJI45

110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110

Three-phase

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

26.41 22.73 21.91 18.61 17.95 17.16 16.00 15.88 15.35 14.13 14.42 12.34 11.84 11.35 11.09 10.65 10.43 10.20 10.14 10.13 9.63 8.82 8.62 8.45 8.19 7.96 7.84 7.80 7.58 6.95 6.74

5,031 4,331 4,175 3,545 3,420 3,270 3,048 3,025 2,924 2,692 2,747 2,351 2,256 2,162 2,114 2,029 1,987 1,943 1,932 1,931 1,835 1,679 1,642 1,610 1,560 1,517 1,493 1,486 1,443 1,325 1,284

26.29 22.75 21.84 18.55 17.96 17.11 15.96 15.83 15.33 14.17 14.38 12.32 11.84 11.37 11.08 10.63 10.43 10.20 10.14 10.12 9.63 8.82 8.62 8.45 8.18 7.96 7.85 7.81 7.64 6.96 6.80

5,008 4,334 4,162 3,534 3,422 3,260 3,040 3,017 2,920 2,700 2,740 2,347 2,256 2,166 2,112 2,026 1,987 1,943 1,932 1,928 1,835 1,680 1,641 1,609 1,559 1,516 1,495 1,487 1,456 1,326 1,295

26.34 22.80 21.87 18.58 18.00 17.13 15.97 15.85 15.34 14.12 14.40 12.33 11.84 11.34 11.10 10.65 10.43 10.20 10.14 10.13 9.63 8.82 8.62 8.45 8.19 7.96 7.84 7.80 7.58 6.95 6.74

5,018 4,344 4,167 3,539 3,429 3,264 3,043 3,020 2,923 2,691 2,743 2,349 2,256 2,161 2,115 2,029 1,987 1,943 1,932 1,930 1,835 1,679 1,642 1,611 1,560 1,517 1,493 1,485 1,444 1,324 1,285

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26.72 20.33 18.99 15.59 14.54 13.97 12.39 12.89 11.66 12.24 11.40 11.23 9.57 8.73 7.80 7.61 8.02 7.80 7.65 7.49 6.88 6.16 6.16 5.83 5.61 5.52 5.43 5.49 5.10 4.77 4.48

26.77 19.99 18.96 15.60 14.36 13.98 12.40 12.90 11.61 12.24 11.41 11.23 9.57 8.74 7.77 7.61 8.02 7.80 7.65 7.49 6.88 6.16 6.17 5.83 5.61 5.52 5.43 5.49 5.09 4.78 4.47

26.64 20.15 18.94 15.56 14.45 13.95 12.37 12.87 11.63 12.31 11.39 11.21 9.57 8.76 7.78 7.60 8.02 7.80 7.65 7.49 6.88 6.16 6.16 5.82 5.61 5.52 5.44 5.50 5.15 4.78 4.52

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Bus Name

Vnom kV

Three-phase

November, 2007 Page 93 (96)

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

Ik"

MVA

Ik"

MVA

KGNJI55 KDECAN5 KBERIV5 KDJJAN5 KMALIS5 KRAHAV5 KDRAGA5 KHGAZI5 KGLOGO5 KKVITI5

110 110 110 110 110 110 110 110 110 110

6.74 6.41 6.22 6.40 6.28 6.19 5.91 5.91 5.87 5.65

1,285 1,220 1,185 1,219 1,197 1,180 1,126 1,125 1,119 1,077

4.48 4.33 4.17 4.95 4.16 4.09 4.15 4.93 5.66 3.85

6.74 6.41 6.22 6.40 6.28 6.19 5.91 5.91 5.88 5.66

1,284 1,220 1,185 1,219 1,197 1,180 1,126 1,126 1,121 1,077

4.47 4.33 4.17 4.95 4.16 4.09 4.15 4.93 5.68 3.85

6.80 6.41 6.38 6.40 6.28 6.19 5.91 5.91 5.89 5.67

1,295 1,221 1,216 1,219 1,197 1,180 1,126 1,125 1,123 1,080

4.52 4.34 4.30 4.95 4.16 4.09 4.15 4.93 5.69 3.86

KDRENA5

110

4.88

930

4.26

4.89

932

4.27

4.90

933

4.28

Table A 6.3 Year 2014 Short circuit currents of 400kV and 220kV network of Kosovo Variant 1 Bus Name

Vnom kV

Three-phase

Variant 2

Single-phase

Variant 3

Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

25.56 25.60 9.60 29.63 30.89 29.00 17.72 19.46 18.28 17.72

17,705 17,738 6,654 11,289 11,772 11,050 6,753 7,416 6,966 6,753

25.08 25.31 9.56 28.09 30.53 28.69 17.92 19.33 18.17 17.92

17,375 17,533 6,626 10,703 11,634 10,934 6,827 7,366 6,922 6,827

27.08 27.19 6.66 28.10 32.44 30.70 15.09 15.88 14.61 15.09

13.84 10.93

4,165

8.10 10.89

4,150

13.67

Kosovo C 400 Kosovo B 400 Peja 400 Kosovo C 220 Kosovo B 220 Kosovo A 220 Prishtina 4 Gllogovc Ferronikel Prizren 220

400 400 400 220 220 220 220 220 220 220

25.30 25.20 9.59 30.02 29.55 29.51 18.99 18.99 17.86 18.99

17,525 17,458 6,642 11,438 11,259 11,243 7,238 7,235 6,807 7,238

Ferizaj 220

220 10.95

4,174

27.44 27.12 6.67 32.31 30.37 31.86 16.35 15.44 14.24 16.35

27.78 27.80 6.47 30.52 32.75 30.87 14.72 15.67 14.43 14.72

Table A 6.4 Year 2014 Short circuit currents of 110kV network of Kosovo Bus Name

Vnom kV

KTKOSA5 KPRIS45 KPRIS15 KPRIS55 KPRIS65 KCRKVO5 KPRIS35 KMAZGI5 KPRIS25 KPEC3 5 KFKOSO5 KUROSE5 KPRIZ25 KISTOK5 KLIPLJ5 KSHTIM5 KPRIZ15 KVALAC5 KPRIZ35 KUROS15

110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110

Three-phase

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

25.12 22.31 21.26 17.96 17.69 16.61 15.59 15.40 15.08 14.23 14.03 12.27 11.85 11.40 11.02 10.60 10.44 10.14 10.15 10.09

4,786 4,251 4,051 3,422 3,371 3,165 2,970 2,935 2,873 2,711 2,672 2,339 2,258 2,171 2,099 2,019 1,989 1,932 1,933 1,922

24.98 22.22 21.17 17.89 17.63 16.55 15.54 15.35 15.03 14.27 13.98 12.25 11.85 11.42 10.99 10.58 10.43 10.14 10.14 10.07

4,760 4,234 4,033 3,409 3,359 3,153 2,960 2,925 2,864 2,719 2,664 2,333 2,257 2,175 2,094 2,016 1,987 1,931 1,932 1,919

25.05 22.29 21.20 17.93 17.67 16.58 15.56 15.38 15.06 14.22 14.00 12.26 11.85 11.39 11.01 10.60 10.43 10.14 10.14 10.08

4,773 4,246 4,040 3,415 3,367 3,159 2,964 2,930 2,868 2,709 2,668 2,336 2,257 2,170 2,098 2,019 1,988 1,931 1,933 1,921

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

24.54 19.79 18.22 14.82 14.27 13.35 11.99 12.36 11.42 12.32 10.98 11.16 9.57 8.77 7.74 7.58 8.02 7.75 7.65 7.46

24.47 19.41 18.06 14.89 14.09 13.39 12.04 12.14 11.42 11.96 10.75 9.69 8.88 8.58 7.68 7.35 7.55 7.55 7.25 7.10

24.42 19.60 18.16 14.78 14.17 13.31 11.96 12.33 11.38 12.41 10.96 11.14 9.58 8.80 7.72 7.57 8.02 7.75 7.65 7.45

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment

Bus Name

Vnom kV

Three-phase

November, 2007 Page 94 (96)

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

Ik"

MVA

Ik"

MVA

KDJAK25 KDJAK15 KMITR25 KSREKA5 KVUCIT5 KSUPKO5 KKLINA5 KPEC 5 KGNJIL5 KPEC2 5 KGNJI45 KGNJI55 KDECAN5 KBERIV5 KDJJAN5 KMALIS5 KRAHAV5 KDRAGA5 KHGAZI5 KGLOGO5 KKVITI5

110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110

9.64 8.83 8.56 8.45 8.11 7.90 7.86 7.82 7.55 6.97 6.72 6.72 6.42 6.21 6.38 6.28 6.19 5.91 5.89 5.87 5.64

1,837 1,682 1,631 1,610 1,545 1,506 1,497 1,490 1,439 1,327 1,281 1,281 1,222 1,184 1,216 1,197 1,180 1,126 1,122 1,119 1,075

6.89 6.16 6.12 5.82 5.55 5.48 5.44 5.50 5.08 4.78 4.46 4.46 4.34 4.17 4.94 4.16 4.10 4.15 4.91 5.66 3.84

9.65 8.83 8.57 8.45 8.11 7.91 7.86 7.82 7.56 6.97 6.72 6.72 6.42 6.21 6.38 6.28 6.19 5.91 5.89 5.90 5.64

1,838 1,682 1,632 1,609 1,546 1,506 1,498 1,490 1,439 1,328 1,281 1,281 1,222 1,184 1,216 1,197 1,180 1,127 1,122 1,124 1,075

6.66 6.00 6.04 5.64 5.54 5.43 5.39 5.39 4.94 4.69 4.36 4.36 4.23 4.02 4.27 4.08 4.03 3.95 4.87 5.67 3.65

9.64 8.83 8.56 8.44 8.11 7.90 7.87 7.83 7.55 6.97 6.72 6.72 6.42 6.21 6.38 6.28 6.19 5.91 5.89 5.89 5.64

1,837 1,682 1,631 1,608 1,544 1,505 1,499 1,492 1,438 1,329 1,280 1,280 1,223 1,183 1,215 1,196 1,180 1,126 1,122 1,122 1,074

6.89 6.17 6.12 5.82 5.55 5.48 5.45 5.52 5.08 4.79 4.46 4.46 4.34 4.16 4.94 4.16 4.10 4.15 4.91 5.69 3.84

KDRENA5

110

4.88

930

4.26

4.90

933

4.27

4.89

932

4.27

Table A 6.5 Year 2016 Short circuit currents of 400kV and 220kV network of Kosovo Variant 1 Bus Name

Vnom kV

Three-phase

Variant 2

Single-phase

Variant 3

Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

27.83 27.84 9.79 32.10 33.54 31.14 18.55 20.40 19.11 18.55

19,284 19,291 6,785 12,233 12,779 11,867 7,068 7,773 7,280 7,068

27.36 27.41 9.76 30.33 33.09 30.77 18.74 20.25 18.97 18.74

18,956 18,991 6,761 11,556 12,607 11,726 7,141 7,715 7,229 7,141

30.31 29.84 6.75 30.34 35.16 32.75 15.63 16.45 15.09 15.63

14.24 11.21

4,270

8.26 11.16

4,254

14.05

Kosovo C 400 Kosovo B 400 Peja 400 Kosovo C 220 Kosovo B 220 Kosovo A 220 Prishtina 4 Gllogovc Ferronikel Prizren 220

400 400 400 220 220 220 220 220 220 220

27.59 27.25 9.78 32.42 31.97 31.78 19.91 19.89 18.66 19.91

19,111 18,879 6,775 12,354 12,183 12,108 7,586 7,578 7,109 7,586

Ferizaj 220

220 11.24

4,281

30.65 29.68 6.76 34.84 32.85 34.20 16.95 16.00 14.71 16.95

30.99 30.88 6.57 33.13 35.65 33.00 15.26 16.26 14.92 15.26

Table A 6.6 Year 2016 Short circuit currents of 110kV network of Kosovo Bus Name

Vnom kV

KTKOSA5 KPRIS45 KPRIS15 KPRIS55 KPRIS65 KCRKVO5 KPRIS35 KMAZGI5 KPRIS25

110 110 110 110 110 110 110 110 110

Three-phase

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

25.81 22.88 21.74 18.31 18.04 16.91 15.84 15.66 15.32

4,917 4,358 4,142 3,489 3,437 3,221 3,019 2,984 2,919

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

25.19 20.21 18.58 15.05 14.48 13.54 12.14 12.52 11.56

Ik"

MVA

25.88 22.91 21.81 18.35 18.06 16.94 15.88 15.69 15.35

4,931 4,365 4,155 3,496 3,442 3,228 3,025 2,989 2,925

25.13 19.84 18.42 15.13 14.31 13.59 12.20 12.29 11.56

Ik"

MVA

25.72 22.80 21.70 18.27 18.00 16.87 15.82 15.63 15.30

4,901 4,344 4,134 3,481 3,429 3,215 3,014 2,978 2,915

25.04 20.02 18.51 15.00 14.38 13.50 12.11 12.48 11.52

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment

Bus Name

Vnom kV

Three-phase

November, 2007 Page 95 (96)

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

Ik"

Ik" kA

Ik"

Ik" kA

MVA

KPEC3 5 KFKOSO5 KUROSE5 KPRIZ25 KISTOK5 KLIPLJ5 KSHTIM5 KPRIZ15 KVALAC5 KPRIZ35 KUROS15 KDJAK25 KDJAK15 KMITR25 KSREKA5 KVUCIT5 KSUPKO5 KKLINA5 KPEC 5 KGNJIL5 KPEC2 5 KGNJI45 KGNJI55 KDECAN5 KBERIV5 KDJJAN5 KMALIS5 KRAHAV5 KDRAGA5 KHGAZI5 KGLOGO5 KKVITI5

110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110

14.35 14.24 12.43 11.95 11.48 11.14 10.71 10.51 10.21 10.22 10.19 9.71 8.88 8.62 8.51 8.17 7.96 7.90 7.86 7.60 7.00 6.76 6.76 6.44 6.23 6.42 6.31 6.22 5.94 5.91 5.92 5.67

2,735 2,713 2,368 2,276 2,187 2,123 2,041 2,003 1,945 1,947 1,942 1,850 1,692 1,642 1,621 1,557 1,516 1,505 1,498 1,448 1,334 1,288 1,288 1,228 1,188 1,223 1,203 1,186 1,131 1,126 1,128 1,080

12.42 11.11 11.29 9.63 8.81 7.80 7.63 8.06 7.78 7.69 7.52 6.92 6.19 6.15 5.85 5.58 5.50 5.46 5.52 5.10 4.80 4.48 4.48 4.35 4.17 4.96 4.17 4.11 4.16 4.93 5.70 3.86

14.37 14.26 12.44 11.95 11.49 11.15 10.72 10.52 10.22 10.22 10.20 9.71 8.88 8.62 8.51 8.18 7.96 7.91 7.86 7.60 7.00 6.76 6.76 6.45 6.24 6.42 6.31 6.22 5.94 5.91 5.94 5.67

2,738 2,717 2,371 2,277 2,189 2,124 2,041 2,003 1,946 1,948 1,943 1,850 1,693 1,643 1,620 1,558 1,516 1,506 1,498 1,448 1,334 1,288 1,288 1,228 1,188 1,224 1,203 1,186 1,131 1,127 1,132 1,080

12.07 10.88 9.79 8.93 8.63 7.74 7.40 7.59 7.59 7.28 7.16 6.69 6.02 6.06 5.67 5.56 5.45 5.41 5.41 4.96 4.71 4.38 4.38 4.25 4.03 4.29 4.10 4.04 3.96 4.88 5.71 3.66

14.42 14.21 12.41 11.95 11.51 11.13 10.70 10.51 10.21 10.22 10.18 9.71 8.88 8.62 8.50 8.17 7.95 7.91 7.87 7.60 7.01 6.76 6.76 6.45 6.23 6.42 6.31 6.22 5.94 5.91 5.94 5.67

2,747 2,708 2,365 2,276 2,193 2,120 2,038 2,002 1,945 1,946 1,939 1,850 1,693 1,642 1,619 1,556 1,515 1,508 1,500 1,447 1,335 1,287 1,287 1,229 1,188 1,223 1,202 1,185 1,131 1,126 1,131 1,080

12.52 11.09 11.26 9.63 8.86 7.78 7.62 8.06 7.78 7.69 7.51 6.92 6.19 6.15 5.85 5.57 5.50 5.47 5.54 5.10 4.81 4.48 4.48 4.35 4.17 4.96 4.17 4.11 4.16 4.93 5.73 3.85

KDRENA5

110

4.91

936

4.28

4.93

939

4.30

4.93

938

4.30

Table A 6.7 Year 2018 Short circuit currents of 400kV and 220kV network of Kosovo Variant 1 Bus Name

Vnom kV

Three-phase

Variant 2

Single-phase

Ik"

MVA

Kosovo C 400 Kosovo B 400 Peja 400 Kosovo C 220 Kosovo B 220 Kosovo A 220 Prishtina 4 Gllogovc Ferronikel Prizren 220

400 400 400 220 220 220 220 220 220 220

30.29 20,983 29.48 20,426 9.98 6,912 22.48 8,565 20.74 7,901 22.15 8,441 15.90 6,060 15.42 5,875 14.67 5,590 15.90 6,060

Ferizaj 220

220 10.18

3,879

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Three-phase Single-phase Three-phase Single-phase Ik"

Ik" kA

MVA

30.85 30.81 10.01 32.27 33.71 31.30 18.61 20.47 19.17 18.61

21,371 21,346 6,934 12,295 12,847 11,928 7,090 7,801 7,306 7,090

12.70 11.24

4,282

34.11 31.93 6.85 24.36 20.59 24.52 14.29 12.84 12.00 14.29

Variant 3 Ik"

Ik" kA

MVA

30.35 30.19 9.98 30.47 33.25 30.92 18.80 20.32 19.03 18.80

21,026 20,916 6,914 11,609 12,669 11,782 7,162 7,741 7,253 7,162

34.22 33.10 6.85 30.60 35.44 32.95 15.68 16.51 15.14 15.68

8.27 11.19

4,265

14.10

34.92 34.66 6.66 33.45 35.99 33.23 15.33 16.33 14.98 15.33

Studies to support the development of new generation capacities and related transmission Annexes of Report of Task2, Transmission System Impact Assessment

November, 2007 Page 96 (96)

Table A 6.8 Year 2018 Short circuit currents of 110kV network of Kosovo Bus Name

Vnom kV

Three-phase

Single-phase Three-phase Single-phase Three-phase Single-phase

Ik"

MVA

Ik"

Ik" kA

Ik"

Ik" kA

MVA

110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110 110

22.76 20.68 19.65 16.72 16.65 15.54 14.67 14.48 14.28 14.45 13.26 11.92 11.92 11.53 10.75 10.48 10.50 10.08 10.22 9.94 9.72 8.90 8.50 8.52 7.98 7.82 7.92 7.88 7.47 7.02 6.66 6.66 6.46 6.19 6.30 6.32 6.23 5.93 5.87 5.65 5.59

4,335 3,939 3,743 3,185 3,171 2,961 2,796 2,759 2,720 2,752 2,526 2,272 2,271 2,198 2,048 1,997 2,000 1,921 1,946 1,893 1,852 1,695 1,619 1,623 1,521 1,491 1,510 1,502 1,423 1,337 1,268 1,268 1,230 1,180 1,200 1,205 1,187 1,130 1,119 1,077 1,064

22.62 18.69 17.24 14.10 13.68 12.76 11.54 11.85 11.04 12.48 10.59 10.90 9.60 8.84 7.63 7.53 8.04 7.73 7.68 7.39 6.92 6.19 6.10 5.85 5.50 5.45 5.47 5.53 5.05 4.80 4.44 4.44 4.35 4.16 4.90 4.17 4.11 4.15 4.91 5.44 3.82

25.96 22.97 21.86 18.39 18.10 16.97 15.91 15.71 15.38 14.47 14.28 12.46 11.99 11.54 11.17 10.73 10.54 10.23 10.25 10.21 9.74 8.91 8.64 8.52 8.18 7.97 7.93 7.89 7.61 7.02 6.77 6.77 6.46 6.24 6.43 6.32 6.23 5.95 5.92 5.95 5.68

4,945 4,376 4,165 3,503 3,449 3,234 3,031 2,994 2,930 2,756 2,721 2,374 2,283 2,199 2,127 2,045 2,008 1,950 1,952 1,946 1,855 1,697 1,645 1,623 1,559 1,518 1,511 1,503 1,450 1,338 1,289 1,289 1,231 1,189 1,225 1,205 1,188 1,133 1,128 1,133 1,081

25.21 19.90 18.47 15.16 14.34 13.61 12.22 12.31 11.58 12.14 10.89 9.81 8.95 8.66 7.75 7.41 7.60 7.59 7.29 7.16 6.70 6.03 6.07 5.68 5.56 5.45 5.43 5.42 4.97 4.72 4.38 4.38 4.25 4.04 4.29 4.10 4.05 3.96 4.89 5.72 3.66

25.80 22.86 21.75 18.30 18.03 16.90 15.85 15.65 15.32 14.52 14.23 12.43 11.98 11.57 11.14 10.71 10.53 10.23 10.24 10.19 9.74 8.91 8.63 8.51 8.18 7.96 7.94 7.90 7.60 7.03 6.76 6.76 6.46 6.24 6.42 6.32 6.23 5.94 5.92 5.94 5.67

4,915 4,355 4,143 3,487 3,436 3,220 3,019 2,982 2,920 2,766 2,712 2,368 2,282 2,204 2,123 2,041 2,007 1,949 1,951 1,942 1,855 1,697 1,644 1,622 1,558 1,517 1,513 1,505 1,448 1,339 1,288 1,288 1,231 1,188 1,224 1,204 1,187 1,132 1,127 1,131 1,080

25.12 20.07 18.55 15.03 14.41 13.52 12.13 12.50 11.54 12.61 11.10 11.28 9.65 8.89 7.79 7.63 8.08 7.79 7.70 7.51 6.93 6.20 6.15 5.85 5.58 5.51 5.49 5.55 5.10 4.82 4.48 4.48 4.36 4.18 4.96 4.17 4.11 4.16 4.93 5.73 3.85

KDRENA5

110

4.73

901

4.13

4.93

940

4.30

4.93

939

4.30

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

November, 2007

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 2 (40) November, 2007

Disclaimer While the consortium of Pรถyry, CESI, TERNA and DECON considers that the information and opinions given in this work are sound, all parties must rely upon their own skill and judgement when making use of it. The consortium members do not make any representation or warranty, expressed or implied, as to the accuracy or completeness of the information contained in this report and assumes no responsibility for the accuracy or completeness of such information. The consortium members will not assume any liability to anyone for any loss or damage arising out of the provision of this report. The report contains projections that are based on assumptions that are subject to uncertainties and contingencies. Because of the subjective judgements and inherent uncertainties of projections, and because events frequently do not occur as expected, there can be no assurance that the projections contained herein will be realised and actual results may be different from projected results. Hence the projections supplied are not to be regarded as firm predictions of the future, but rather as illustrations of what might happen. Parties are advised to base their actions on an awareness of the range of such projections, and to note that the range necessarily broadens in the latter years of the projections.

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 3 (40) November, 2007

CONTENTS INTRODUCTION PHILOSOPHY OF PROJECT 1

INSTALLATION AT THE INSIDE OF THE THERMAL POWER PLANT KOSOVO “A”...........................................................................................................................................7

1.1 Connections with external unity (only for the changes, see doc. nr. ES002-A1) ..................10 1.2 Routing (see doc. nr. ES003-A1) ...........................................................................................10 1.3 Modifications (Kosovo “A” and Kosovo “B”) ......................................................................11 1.3.1 Modifications in Kosovo “B” ............................................................................................11 1.3.2 Modifications in Kosovo “A” ............................................................................................12 2

INSTALLATION NEAR THERMAL POWER PLANT KOSOVO “B” ......................13

2.1 Connections with external unity (only for the changes, see doc. nr. ES002-A2) ..................16 2.2 Routing (see doc. nr. ES003-A2) ...........................................................................................17 2.3 Modifications (Kosovo “A” and Kosovo “B”) ......................................................................18 2.3.1 Modifications in Kosovo “B” ............................................................................................18 2.3.2 Modifications in Kosovo “A” ............................................................................................19 3

INSTALLATION IN THE AREA OF BIVOLJAK .........................................................20

3.1 Connections with external unity (only for the changes, see doc. nr. ES002-A3) ..................23 3.2 Routing (see doc. nr. ES003-A3) ...........................................................................................24 3.3 Modifications (Kosovo “A” and Kosovo “B”) ......................................................................24 3.3.1 Modifications in Kosovo “B” ............................................................................................25 3.3.2 Modifications in Kosovo “A” ............................................................................................26

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 4 (40) November, 2007

INTRODUCTION The possible solutions for the new site of the Plant of Kosovo "C" (and therefore the position of the substation 400/220kV) are: -

Inside the Thermal Power Plant of Kosovo “A”; (see “ATT.01 Kosovo A site layout”)

Near to the Thermal Power Plant of Kosovo “B”;(see “ATT.02 Kosovo B site layout”)

In the area of Bivoljak.(see “ATT.03 Bivoljak site layout”)

PHILOSOPHY OF PROJECT With the purpose to decide the solution optimal the following hypotheses are proposed: -

the new plant will be constituted by n° 4 units (around 650MWe each);

the new plant directly connects him with Albania to 400kV;

the new plant also produces the 220kV;

the new plant directly connects him with Kosovo "B", but being only us an available gantry (n° 9) the following hypotheses are had:

A. connection in double line (freeing a gantry) 1. You also uses the gantry n° 4, in the case of the site Kosovo "Á." in how much the line for Shupie will be fed (and eventually strengthened) from Kosovo "C"; 2. You also uses the gantry n° 8, in the other cases in how much the line for Podgorica will be fed (and eventually strengthened) from Kosovo "C";

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 5 (40) November, 2007

Reference documents: ES001-A1: 400/220kV Switchyard Kosovo “C” SLD, area Kosovo A ES001-A2: 400/220kV Switchyard Kosovo “C” SLD, area Kosovo B ES001-A3: 400/220kV Switchyard Kosovo “C” SLD, area Bivoljak ES002-A1: 400/220kV Switchyard Kosovo “C” Interconnections – Block Diagram, area Kosovo A ES002-A2: 400/220kV Switchyard Kosovo “C” Interconnections – Block Diagram, area Kosovo B ES002-A3: 400/220kV Switchyard Kosovo “C” Interconnections – Block Diagram, area Bivoljak ES003-A0: 400/220kV Switchyard Kosovo “C” Transmission Connection Layout, existing ES003-A1: 400/220kV Switchyard Kosovo “C” Transmission Connection Layout, area Kosovo A ES003-A2: 400/220kV Switchyard Kosovo “C” Transmission Connection Layout, area Kosovo B ES003-A3: 400/220kV Switchyard Kosovo “C” Transmission Connection Layout, area Bivoljak Ambient conditions:

Average temperature of the air

15 °C

Minimum temperature of the air

-20 °C

Maximum temperature of the air

40 °C

Relative humidity

maximum

Annual precipitation Maximum speed of the wind

1000 mm Km/h

Atmospheric contamination Elevation

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

60%

120 High

s.l.m.

500 m ÷ 550 m

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 6 (40) November, 2007

400/220kV Switchyard and Lines: insulation levels The insulation levels of the equipments, of the machinery and in general of the plant in his whole they will be in accord to the values of voltage pointed out in the following table: Nominal Voltage

kV 400 220

Maximum Voltage System

Voltage Capacity Industrial Frequency

B.I.L.

kV kV 420 245 460 Nominal Frequency

S.I.L.

kV kV 1050 1425 1050 50 Hz

400/220kV Switchyard and Lines: short circuit current The 400/220kV switchyard will have to be projected for the following values of short circuit current:

Duration

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

220 kV Short Circuit Current 31,5 kA 1s

400 kV 40 kA

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 1

Page 7 (40) November, 2007

INSTALLATION INSIDE THE THERMAL POWER PLANT KOSOVO “A” It foresees the following connections in high voltage: -

double connection with Kosovo "B" to 400kV line;

single connection with Skopje to 400kV line (eliminating the connection from Kosovo “B” to Skopje);

single connection with Albania to 400kV line;

connection with the existing bus bars to 220kV of Kosovo "A" existing 400kV line Skopje existing 220kV line

KOSOVO “B” KOSOVO “A”

Figure 1-1 Current situation (only for the connections to be modified)

Albania

new 400 kV line existing 400 kV line

Skopje

new 400 kV line new 400 kV line

KOSOVO “B”

new 220 kV bus bar

KOSOVO “C” KOSOVO “A”

Figure 1-2 Future situation (only for the connections to be modified)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 8 (40) November, 2007

Figure 1-3 Proposed position for the 400/220 kV switchyard

The dimension of the 400/220kV Kosovo "C" switchyard is estimated to be 250x200m as it follows, side 400 kV (see doc. nr. ES001-A1): -

double 400kV bus bar;

maintenance 400kV bus bar;

400kV tie-breaker (between bus bar A and B);

gantry 400kV line (1) Kosovo “B”;

gantry 400kV line (2) Kosovo “B”;

gantry 400kV line Albania;

gantry 400kV line spare;

gantry 400kV line Skopje;

400kV tie-breaker (bus bar A/B with maintenance bus bar);

gantry step-up transformer 400/15kV, 500MVA, AT1;

gantry step-up transformer 400/15kV, 500MVA, AT2;

gantry step-up transformer 400/15kV, 500MVA, AT3;

gantry step-up transformer 400/15kV, 500MVA, AT4;

gantry auto transformer 400/220kV, 400MVA, AT5;

gantry auto transformer 400/220kV, 400MVA, AT6;

gantry auto transformer 400/220kV, 400MVA, spare;

double 220kV bus bar (connection to the existing bus bar of Kosovo “A”)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

European Agency for Reconstruction Pöyry-CESI-Terna-Decon Figure 1-4 Block diagram: 400/220 kV switchyard Kosovo “C”

(side 400 kV).

Side 220kV:

double 220kV bus bar;

gantry auto transformer 400/220kV, 400MVA, AT5;

gantry auto transformer 400/220kV, 400MVA, AT6;

gantry 220kV line spare; gantry auto transformer 400/220kV, 400MVA, spare

tie-breaker 400kV (bus bar A/B with maintenance bus bar) gantry step-up transformer 400/15kV, 500MVA, AT1 gantry step-up transformer 400/15kV, 500MVA, AT2 gantry step-up transformer 400/15kV, 500MVA, AT3 gantry step-up transformer 400/15kV, 500MVA, AT4 gantry auto transformer 400/220kV, 400MVA, AT5 gantry auto transformer 400/220kV, 400MVA, AT6

gantry 400kV line Skopje

gantry 400kV line spare

gantry 400kV line Albania

gantry 400kV line (2) Kosovo “B”

tie-breaker 400kV (between bus bar A and B) gantry 400kV line (1) Kosovo “B”

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design Page 9 (40) November, 2007

Page 10 (40) November, 2007

gantry auto transformer 400/220kV, 400MVA, AT5 gantry auto transformer 400/220kV, 400MVA, AT6

gantry 220kV line spare

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Figure 1-5 Block diagram: 400/220 kV switchyard Kosovo C (side 220kV).

1.1

Connections with external unity Only for the changes, see doc. nr. ES002-A1. -

gantry 400kV line (1) Kosovo “C” to gantry “4” Kosovo “B”,

because delete interconnection with Skopje (Shkupi);

gantry 400kV line (2) Kosovo “C” to gantry “9” Kosovo “B”,

because spare;

gantry 400kV line Kosovo “C” to (hold) Albania;

gantry 400kV line 400kV Kosovo “C” to existing 400kV line Shkupi; (start of the tie-line with Kosovo “B”);

double 220kV bus bar;

(connection to the existing bus bar of Kosovo “A”)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 1.2

Page 11 (40) November, 2007

Routing (see doc. nr. ES003-A1) - gantry 400kV line (1) Kosovo “B”; LP: ……………/1 cable: 3x2xACSR 490/65 routing: in parallel with existing 220kV line - gantry 400kV line (2) Kosovo “B”; LP: …………………./2 cable: 3x2xACSR 490/65 routing: in parallel with existing 220kV line NOTE: an only pylon with double lines - gantry 400kV line (1) Albania; LP: ………………../1 cable: 3x2xACSR 490/65 routing: new “right of way” (behind the 400/220kV switchyard) - gantry 400kV line Skopje; LP: (420)………………….. cable: 3x2xACSR 490/65 routing: in parallel with existing 220kV line - double 220kV bus bar; bus bar …………. (connection to the existing bus bar of Kosovo “A”)

1.3

Modifications (Kosovo “A” and Kosovo “B”)

1.3.1

Modifications in Kosovo “B” 400kV gantry n°4 (Skopje): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 400:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 400kV terminals of existing Skopje line; to connect: 400kV terminals from the new Kosovo “C” line.

modifications:

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 12 (40) November, 2007

400kV gantry n°9 (Spare): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 400:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to connect: 400kV terminals from the new Kosovo “C” line.

modifications:

1.3.2

Modifications in Kosovo “A” 220kV Bus Bar: existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x600 1A; 2x800 1 1 1 A

to connect: with new 220kV bus bar

modifications:

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 2

Page 13 (40) November, 2007

INSTALLATION NEAR THERMAL POWER PLANT KOSOVO “B” It foresees the following connections in high voltage: -

double connection with Kosovo "B" to 400kV line;

single connection with Podgorica to 400kV line (eliminating the connection from Kosovo “B” to Podgorica);

single connection with Albania to 400kV line;

double connection with Kosovo "B" to 220kV line;

double connection with Pristhina 4 to 220kV line; existing 400kV line Podgorica existing 220kV line

KOSOVO “B” KOSOVO “A”

Figure 2-1 Current situation (only for the connections to be modified)

new 400 kV line Albania

new 400 kV line

ex. 400 kV line

new 400 kV line

KOSOVO “C”

Podgorica

KOSOVO “B”

KOSOVO “A”

new 220 kV line new 220 kV line new 220 kV line new 220 kV line

Prishtina 4

Figure 2-2 Future situation (only for the connectins to be modified)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 14 (40) November, 2007

Figure 2-3 Proposed position for the 400/220 kV switchyard

The dimension of the 400/220kV Kosovo "C" switchyard is estimated to be 250x200m, as it follows, 400 kV side (see doc. nr. ES001-A2): -

double 400kV bus bar;

maintenance 400kV bus bar;

400kV tie-breaker (between bus bar A and B);

gantry 400kV line (1) Kosovo “B”;

gantry 400kV line (2) Kosovo “B”;

gantry 400kV line Albania;

gantry 400kV line spare;

gantry 400kV line Podgorica;

400kV tie-breaker (bus bar A/B with maintenance bus bar);

gantry step-up transformer 400/15kV, 500MVA, AT1;

gantry step-up transformer 400/15kV, 500MVA, AT2;

gantry step-up transformer 400/15kV, 500MVA, AT3;

gantry step-up transformer 400/15kV, 500MVA, AT4;

gantry auto transformer 400/220kV, 400MVA, AT5;

gantry auto transformer 400/220kV, 400MVA, AT6;

gantry auto transformer 400/220kV, 400MVA, spare;

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Page 15 (40) November, 2007

gantry 400kV line Podgorica

gantry 400kV line spare

gantry 400kV line Albania

gantry 400kV line (2) Kosovo “B”

tie-breaker 400kV (between bus bar A and B) gantry 400kV line (1) Kosovo “B”

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Figure 2-4 Block diagram: 400/220 kV switchyard Kosovo “C” (side 400 kV)

Side 220kV -

double 220kV bus bar;

220kV tie-breaker (between bus bar A and B);

gantry auto transformer 400/220kV, 400MVA, AT5;

gantry auto transformer 400/220kV, 400MVA, AT6;

gantry 220kV line (1) Kosovo “B”;

gantry 220kV line (2) Kosovo “B”;

gantry 220kV line (1) Kosovo “A”;

gantry 220kV line (2) Kosovo “A”;

gantry 220kV line spare.

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

gantry auto transformer 400/220kV, 400MVA, AT5 gantry auto transformer 400/220kV, 400MVA, AT6 gantry auto transformer 400/220kV, 400MVA, spare

gantry 220kV line spare

Page 16 (40) November, 2007

gantry 220kV line (2) Kosovo “B”

gantry 220kV line (1) Kosovo “B”

gantry 220kV line (2) Kosovo “A”

220kV tie-breaker (between bus bar A and B) gantry 220kV line (1) Kosovo “A”

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Figure 2-5 Block diagram: 400/220 kV switchyard Kosovo C (side 220 kV).

2.1

Connections with external unity Only for the changes see doc. nr. ES002-A2. -

gantry 400kV line (1) Kosovo “C” to gantry “8” Kosovo “B”, because delete interconnection with Podgorica;

gantry 400kV line (2) Kosovo “C” to gantry “9” Kosovo “B”, because spare;

gantry 400kV line Kosovo “C” to (hold) Albania;

gantry 400kV line 400kV Kosovo “C” to existing 400kV line Podgorica; (start of the tie-line with Kosovo “B”);

gantry 220kV line (1) Kosovo “C” to gantry “1” Kosovo “B”, because delete interconnection with Kosovo “A”;

gantry 220kV line (2) Kosovo “C” to gantry “2” Kosovo “B”, because delete interconnection with Kosovo “A”;

gantry 220kV line (1) Kosovo “C” to gantry “…” Kosovo “A”, because delete interconnection with Kosovo “B”;

gantry 220kV line (2) Kosovo “C” to gantry “…” Kosovo “A”, because delete interconnection with Kosovo “B”;

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 2.2

Routing (see doc. nr. ES003-A2) - gantry 400kV line (1) Kosovo “B”; LP: ……………/1 cable: 3x2xACSR 490/65 routing: new “right of way” - gantry 400kV line (2) Kosovo “B”; LP: …………………./2 cable: 3x2xACSR 490/65 routing: new “right of way” NOTE: an only pylon with double lines - gantry 400kV line Albania; LP: ………………../1 cable: 3x2xACSR 490/65 routing: new “right of way” - gantry 400kV line Podgorica; LP: (437)………………….. cable: 3x2xACSR 490/65 routing: to tie-line with existing 400kV line - gantry 220kV line (1) Kosovo “B”; LP: ……………/1 cable: 3xACSR 490/65 routing: new “right of way” - gantry 220kV line (2) Kosovo “B”; LP: …………………./2 cable: 3xACSR 490/65 routing: new “right of way” NOTE: an only pylon with double lines - gantry 220kV line (1) Pristhina 4; LP: (2305)/1 cable: 3xACSR 490/65 routing: new “right of way” to existing “right of way” Pristhina 4 - gantry 220kV line (2) Pristhina 4; LP: (2306)/2 cable: 3xACSR 490/65 routing: new “right of way” to existing “right of way” Pristhina 4 NOTE: an only pylon with double lines.

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Page 17 (40) November, 2007

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

2.3

Modifications (Kosovo “A” and Kosovo “B”)

2.3.1

Modifications in Kosovo “B”

Page 18 (40) November, 2007

400kV gantry n°8 (Podgorica): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 400:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 400kV terminals of existing Podgorica line; to connect: 400kV terminals from the new Kosovo “C” line.

modifications:

400kV gantry n°9 (Spare): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 400:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to connect: 400kV terminals from the new Kosovo “C” line.

modifications:

220kV gantry n°1 (Kosovo “A”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “A” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 19 (40) November, 2007

220kV gantry n°2 (Kosovo “A”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “A” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

2.3.2

Modifications in Kosovo “A” 220kV gantry n°… (Kosovo “B”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “B” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

220kV gantry n°… (Kosovo “B”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “B” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 20 (40) November, 2007

INSTALLATION IN THE AREA OF BIVOLJAK It foresees the following connections in high voltage: -

double connection with Kosovo "B" to 400kV line;

single connection with Podgorica to 400kV line (eliminating the connection from Kosovo “B” to Podgorica);

single connection with Albania to 400kV line;

double connection with Kosovo "B" to 220kV line;

single connection with Krushevci (TS Besina) to 220kV line; existing 400kV line Podgorica existing 220kV line

KOSOVO “B” KOSOVO “A”

Figure 3-1 Current situation (only for the connections to be modified)

new 400 kV line Albania

new 400 kV line

ex. 400 kV line

new 400 kV line

KOSOVO “C”

Podgorica

KOSOVO “B”

KOSOVO “A”

new 220 kV line new 220 kV line new 220 kV line

Krushevci (TS Besiana)

Figure 3-2 Future situation (only for the connections to be modified)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 21 (40) November, 2007

Figure 3-3 Proposed position for the 400/220 kV switchyard.

The dimension of the 400/220kV Kosovo "C" switchyard is estimated to be 250x200m, as it follows, side 220 kV (see doc. nr. ES001-A3): -

double 400kV bus bar;

maintenance 400kV bus bar;

400kV tie-breaker (between bus bar A and B);

gantry 400kV line (1) Kosovo “B”;

gantry 400kV line (2) Kosovo “B”;

gantry 400kV line Albania;

gantry 400kV line spare;

gantry 400kV line Podgorica;

400kV tie-breaker (bus bar A/B with maintenance bus bar);

gantry step-up transformer 400/15kV, 500MVA, AT1;

gantry step-up transformer 400/15kV, 500MVA, AT2;

gantry step-up transformer 400/15kV, 500MVA, AT3;

gantry step-up transformer 400/15kV, 500MVA, AT4;

gantry auto transformer 400/220kV, 400MVA, AT5;

gantry auto transformer 400/220kV, 400MVA, AT6;

gantry auto transformer 400/220kV, 400MVA, spare;

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Page 22 (40) November, 2007

gantry 400kV line Podgorica

gantry 400kV line spare

gantry 400kV line Albania

gantry 400kV line (2) Kosovo “B”

tie-breaker 400kV (between bus bar A and B) gantry 400kV line (1) Kosovo “B”

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Figure 3-4 Block diagram: 400/220 kV switchyard Kosovo “C” (side 400 kV).

Side 220kV -

double 220kV bus bar;

220kV tie-breaker (between bus bar A and B);

gantry auto transformer 400/220kV, 400MVA, AT5;

gantry auto transformer 400/220kV, 400MVA, AT6;

gantry 220kV line (1) Kosovo “B”;

gantry 220kV line (2) Kosovo “B”;

gantry 220kV line (1) Krushevci (TS Besina);

gantry 220kV line spare.

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

gantry auto transformer 400/220kV, 400MVA, AT5 gantry auto transformer 400/220kV, 400MVA, AT6 gantry auto transformer 400/220kV, 400MVA, spare

Page 23 (40) November, 2007

gantry 220kV line spare

gantry 220kV line (2) Kosovo “B”

gantry 220kV line (1) Kosovo “B”

gantry 220kV line (2) Kosovo “A”

220kV tie-breaker (between bus bar A and B) gantry 220kV line (1) Kosovo “A”

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Figure 3-5 Block diagram: 400/220 kV switchyard Kosovo C (side 220 kV).

3.1

Connections with external unity Only for the changes (see doc. nr. ES002-A3) -

gantry 400kV line (1) Kosovo “C” to gantry “8” Kosovo “B”, because delete interconnection with Podgorica;

gantry 400kV line (2) Kosovo “C” to gantry “9” Kosovo “B”, because spare;

gantry 400kV line Kosovo “C” to (hold) Albania;

gantry 400kV line 400kV Kosovo “C” to existing 400kV line Podgorica; (start of the tie-line with Kosovo “B”);

gantry 220kV line (1) Kosovo “C” to gantry “1” Kosovo “B”, because delete interconnection with Kosovo “A”;

gantry 220kV line (2) Kosovo “C” to gantry “2” Kosovo “B”, because delete interconnection with Kosovo “A”;

gantry 220kV line (1) Kosovo “C” to gantry “…” Kosovo “A”, because delete interconnection with Kosovo “B”;

gantry 220kV line (2) Kosovo “C” to gantry “…” Kosovo “A”, because delete interconnection with Kosovo “B”;

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 3.2

Routing (see doc. nr. ES003-A3) - gantry 400kV line (1) Kosovo “B”; LP: ……………/1 cable: 3x2xACSR 490/65 routing: new “right of way” - gantry 400kV line (2) Kosovo “B”; LP: …………………./2 cable: 3x2xACSR 490/65 routing: new “right of way” NOTE: an only pylon with double lines - gantry 400kV line Albania; LP: ………………../1 cable: 3x2xACSR 490/65 routing: new “right of way” - gantry 400kV line Podgorica; LP: (437)………………….. cable: 3x2xACSR 490/65 routing: to tie-line with existing 400kV line - gantry 220kV line (1) Kosovo “B”; LP: ……………/1 cable: 3xACSR 490/65 routing: new “right of way” - gantry 220kV line (2) Kosovo “B”; LP: …………………./2 cable: 3xACSR 490/65 routing: new “right of way” NOTE: an only pylon with double lines - gantry 220kV line (1) Krushevci; LP: (205) cable: 3xACSR 360/57 routing: new “right of way”

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Page 24 (40) November, 2007

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 3.3 3.3.1

Page 25 (40) November, 2007

Modifications (Kosovo “A” and Kosovo “B”) Modifications in Kosovo “B” 400kV gantry n°8 (Podgorica): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 400:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 400kV terminals of existing Podgorica line; to connect: 400kV terminals from the new Kosovo “C” line.

modifications:

400kV gantry n°9 (Spare): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 400:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to connect: 400kV terminals from the new Kosovo “C” line.

modifications:

220kV gantry n°1 (Kosovo “A”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “A” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Page 26 (40) November, 2007

220kV gantry n°2 (Kosovo “A”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “A” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

3.3.2

Modifications in Kosovo “A” 220kV gantry n°… (Kosovo “B”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “B” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

220kV gantry n°… (Kosovo “B”): existing equipment: -

disconnecting switch: 2000A; circuit breaker: 2500A; earth switch: 2000A; VT: 220:√3; 0,1:√3; 0,1:√3 kV CT: 2x500 1A; 2x800 1 1 1 A

to disconnect: 220kV terminals of existing Kosovo “B” line; to connect: 220kV terminals from the new Kosovo “C” line.

modifications:

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4

TABLES

4.1

220 kV Lines Conductor

Page 27 (40) November, 2007

Conductor name

ACSR

Type

490/65

Composition

Aluminium size

nr x mm mm2 2

54x3.40 + 7x3.40 490.3

Steel size

63.6

Total size

mm2

553.9

External diameter

30.6

Linear weight

Kg/km

1861

Upload the shatter (U.T.S.)

daN

15310

10.

Form of elasticity daN/mm2 daN/mm2

7000

– Initial – Final 11.

Dilatation coefficient

1/°C

19.3

12.

Electrical resistance in d.c. at 20 °C

Ω/km

0.0590

13.

Coil length

2000

14.

Reference Normative

IEC

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.2

Page 28 (40) November, 2007

400 kV Lines Conductor 1.

Conductor name

ACSR

Type

490/65

Composition

Aluminium size

mm2

490.3

Steel size

mm2

63.6

Total size

mm2

553.9

External diameter

30.6

Linear weight

Kg/km

1861

Upload the shatter (U.T.S.)

daN

15310

10.

Form of elasticity

nr x mm 54x3.40+7x3.40

– Initial – Final

daN/mm2 daN/mm2 7000

11.

Dilatation coefficient

1/°C

19.3

12.

Electrical resistance in d.c. at 20 °C

Ω/km

0.0590

13.

Coil length

2000

14.

Reference Normative

IEC

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.3

Page 29 (40) November, 2007

Guard Wire GSW 1.

Type

Galvanisation steel High resistance

Composition

Size

mm2

78.94

External diameter

11.5

Linear weight

Kg/km

621

Upload the shatter (U.T.S.)

Form of elasticity Initial

nr x mm

daN –

19 x 2.3

12231

daN/mm2 daN/mm2 17500

– Final 1/°C x 10- 11.5

Dilatation coefficient

Electrical resistance in d.c. at 20 °C

10.

Coil length

11.

Reference Normative

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Ω/km

IEC ASTM A 363 class A zinc coating

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.4

Page 30 (40) November, 2007

220 kV Line Isolators Standard isolators for Suspension string and tent set 1.

Type

Bolt and socket

Material

Temperate glass

Upload the shatter

kN 120

Diameter

mm 255

Step

mm 146

Joining

mm 16 A

Creepdistance (min)

mm 295

Voltage Cap. Ind. at 50 Hz

8.1

- Dry one minute

kV 70

8.2

- Wet one minute

kV 40

B.I.L. (Dry)

kV 100

IEC 60383-1

10.

Voltage capacity perforation

to kV 130

IEC 60383-1

11.

Cutter pin

12.

Approximate weight

kg 4

13.

Isolators

Nr 6

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

IEC 60120 IEC 60383-1

Stainless steel

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.5

Page 31 (40) November, 2007

400 kV Line Isolators Standard isolators for Suspension string

Tent set

Bolt and Socket

Tempered glass

Type

Material

Upload the shatter

160

210

Diameter

280

Step

146

170

Joining

20 A

Creepdistance (min.)

315

370

Voltage Cap. Ind. at 50 Hz

8.1

- Dry one minute

8.2

- Wet one minute

B.I.L. (Dry)

110

IEC 60383-1

10.

Voltage capacity perforation

to kV

130

IEC 60383-1

11.

Cutter pin

Stainless steel

12.

Approximate weight

7.5

13.

Isolators

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

IEC 60120 IEC 60383-1

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.6

Page 32 (40) November, 2007

220 kV Line Isolators 1.

Type

Suspension string

Tent set

Number of isolators

Nr kV

1 x 14 220

1 x 15 220

Nominal Voltage Maximum Voltage

245

Upload the shatter

3.1

- Isolators

120

3.2

- Accessories

120

Maximum load

Length

2044

2190

Creepdistance

4130

4425

Voltage Cap. Ind. at 50 Hz

7.1

- Dry

675

715

7.2

- Wet

510

540

B.I.L.

1095

1160

Normative

IEC 60383

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Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.7

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400 kV Line Isolators 1.

Type

Suspension string at V

Tent set

Number of isolators

2 x 21

2 x 18

Nominal Voltage

400

Maximum Voltage

420

Upload the shatter

3.1

- Isolators

160

210

3.2

- Accessories

210

210/360

Maximum load

Length

3066

3060

Creepdistance

6615

6660

Voltage Cap. Ind. at 50 Hz

7.1

- Dry

950

895

7.2

- Wet

730

650

B.I.L.

1575

1550

Normative

IEC 60383

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.8

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Temperatures and Loads 220 kV

400 kV

Minimum Temperature

°C

-10

Medium Temperature EDS

°C

Maximum Temperature

°C

daN/m2 daN/m2

12.9 51.5

15.6 62.3

Maximum wind pressure (2 times the surface of daN/m2 projection of the structures of the towers)

86.0

104.0

Loads (finals) to EDS temperature

Maximum wind pressure 4.1 - min. temp. (-10 °C) with ice 4.2 - min. temp. (-10 °C) without ice

6.1

- Conductors ( 18% UTS)

daN

2756

6.2

- GSW

daN

1056

Maximum cable and GSW load (4.2 conditions) 7.1

- Conductors

daN

4100

4400

7.2

- GSW

daN

1700

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Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 4.9

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Safety Indexes

ACSR conductors to EDS temperature (standard span)

ACSR conductors (minimum span or maximum span) - min. temp. + ice + wind pressure - min. temp. + wind pressure

220 kV

400 kV

18%

25% 25%

25% 27%

GSW to EDS temperature (standard span)

GSW (minimum span or maximum span) - min. temp. + ice + wind pressure - min. temp. + wind pressure

9% 10%

Isolators – reported to the upload the shatter E&M

Accessories for isolators – load reported

Tent set joint – load UTS reported

0.95

Towers in the maximum load conditions

8.1

- with entire cables

8.2

- with broken cables

1.5

2.2 1.65

Foundation (turnover and lifting) at the maximum load conditions.

9.1

- with entire cables

9.2

- with broken cables

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ESTIMATED COSTS

5.1

Estimated cost: “Installation at the Inside of Thermal Power Plant Kosovo A “ Description Cable 3x2xACSR 490/65 Line 1: 400kV from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line 2: 400kV from Kosovo “C” to Kosovo “B” Pylons + GSW for 400kV double line from Kosovo “C” to Kosovo “B” Isolators for 400kV double line from Kosovo “C” to Kosovo “B” Foundations for 400kV double line from Kosovo “C” to Kosovo “B” Accessories for 400kV double line from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line LP420: 400kV from Kosovo “C” to Skopje Pylons + GSW for 400kV single line from Kosovo “C” to Skopje Isolators for 400kV single line from Kosovo “C” to Skopje Foundations for 400kV single line from Kosovo “C” to Skopje Accessories for 400kV single line from Kosovo “C” to Skopje Total cost (euro)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Q.ty 3.500m

3.500m nr 4 nr 36 36x4m3 1 set

2.500m nr 4 nr 18 36x4m3 1 set 2.250.000,00

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 5.2

Page 37 (40) November, 2007

Estimated cost: “Installation near Thermal Power Plant Kosovo B” Description Cable 3x2xACSR 490/65 Line 1: 400Kv from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line 2: 400kV from Kosovo “C” to Kosovo “B” Pylons + GSW for 400kV double line from Kosovo “C” to Kosovo “B” Isolators for 400kV double line from Kosovo “C” to Kosovo “B” Foundations for 400kV double line from Kosovo “C” to Kosovo “B” Accessories for 400kV double line from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line LP437: 400kV from Kosovo “C” to Podgorica Pylons + GSW for 400kV single line from Kosovo “C” to Podgorica Isolators for 400kV single line from Kosovo “C” to Podgorica Foundations for 400kV single line from Kosovo “C” to Podgorica Accessories for 400kV single line from Kosovo “C” to Podgorica

Q.ty 2.000m

2.000m nr 3 nr 30 36x3m3 1 set

1.500m nr 3 nr 15 36x3m3 1 set next

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Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Description Cable 3x2xACSR 490/65 Line 1: 220Kv from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line 2: 220kV from Kosovo “C” to Kosovo “B” Pylons + GSW for 220kV double line from Kosovo “C” to Kosovo “B” Isolators for 220kV double line from Kosovo “C” to Kosovo “B” Foundations for 220kV double line from Kosovo “C” to Kosovo “B” Accessories for 220kV double line from Kosovo “C” to Kosovo “B” Cable 3xACSR 490/65 Line LP2306: 220kV from Kosovo “C” to Pristhina 4 Cable 3xACSR 490/65 Line LP2305: 220kV from Kosovo “C” to Pristhina 4 Pylons + GSW for 220kV single line from Kosovo “C” to Pristhina 4 Isolators for 220kV single line from Kosovo “C” to Pristhina 4 Foundations for 220kV single line from Kosovo “C” to Pristhina 4 Accessories for 220kV single line from Kosovo “C” to Pristhina 4 Total cost (euro)

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Q.ty 2.000m

2.000m nr 3 nr 30 36x3m3 1 set

3.500m

3.500m nr 4 nr 36 36x4m3 1 set 4.125.000,00

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design 5.3

Page 39 (40) November, 2007

Estimated cost: Installation in the area of Bivoljak Description Cable 3x2xACSR 490/65 Line 1: 400Kv from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line 2: 400kV from Kosovo “C” to Kosovo “B” Pylons + GSW for 400kV double line from Kosovo “C” to Kosovo “B” Isolators for 400kV double line from Kosovo “C” to Kosovo “B” Foundations for 400kV double line from Kosovo “C” to Kosovo “B” Accessories for 400kV double line from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line LP437: 400kV from Kosovo “C” to Podgorica Pylons + GSW for 400kV single line from Kosovo “C” to Podgorica Isolators for 400kV single line from Kosovo “C” to Podgorica Foundations for 400kV single line from Kosovo “C” to Podgorica Accessories for 400kV single line from Kosovo “C” to Podgorica

Q.ty 7.000m

7.000m nr 7 nr 54 36x7m3 1 set

1.500m nr 3 nr 15 36x3m3 1 set next

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Conceptual design

Description Cable 3x2xACSR 490/65 Line 1: 220Kv from Kosovo “C” to Kosovo “B” Cable 3x2xACSR 490/65 Line 2: 220kV from Kosovo “C” to Kosovo “B” Pylons + GSW for 220kV double line from Kosovo “C” to Kosovo “B” Isolators for 220kV double line from Kosovo “C” to Kosovo “B” Foundations for 220kV double line from Kosovo “C” to Kosovo “B” Accessories for 220kV double line from Kosovo “C” to Kosovo “B” Cable 3xACSR 360/57 Line LP205: 220kV from Kosovo “C” to Krushevci Pylons + GSW for 220kV single line from Kosovo “C” to Krushevci Isolators for 220kV single line from Kosovo “C” to Krushevci Foundations for 220kV single line from Kosovo “C” to Krushevci Accessories for 220kV single line from Kosovo “C” to Krushevci Total cost (euro)

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Page 40 (40) November, 2007

Q.ty 7.000m

7.000m nr 7 nr 54 36x7m3 1 set

6.000m nr 7 nr 27 36x7m3 1 set 8.875.000,00

November, 2007

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Interconnection procedures

Page 2 (31) November, 2007

European Agency for Reconstruction Pรถyry-CESI-Terna-Decon

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Interconnection procedures

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CONTENTS 1

INTRODUCTION.............................................................................................................4

DEFINITION OF THE RULE OF OPERATION ........................................................4

PLANT CHARACTERISTICS, CONNECTION AND PROTECTION SYSTEM...5

3.1 3.2 3.3 3.4 3.5 3.6 3.6.1 3.6.2 3.6.3

Characteristics of the Plant .................................................................................................5 Characteristics of the Connection .......................................................................................5 Point of delivery of the Plant ..............................................................................................6 Blocks .................................................................................................................................9 Characteristics of the Protections........................................................................................9 Disconnection and Reconnection......................................................................................13 Voluntary Disconnection ..............................................................................................13 Involuntary Disconnection............................................................................................13 Obligation to Reconnect ...............................................................................................14

PLANT OPERATION....................................................................................................15

4.1 4.2 4.3

Dedicated Personnel..........................................................................................................15 Normal Operation .............................................................................................................15 Emergency Operation ......................................................................................................15

PRODUCTION PROGRAMMING AND UNAVAILABILITIES ............................17

5.1 5.2

Production Programming ..................................................................................................17 Annual and occasional planning: maintenance.................................................................17

PLANT CONTROL........................................................................................................18

6.1 6.2 6.3 6.4

Remote Information ..........................................................................................................18 Measurements ...................................................................................................................18 Monitoring Equipments ....................................................................................................18 Maintenance......................................................................................................................19

ADDITIONAL REQUIREMENTS FOR GENERATORS ........................................20

7.1 7.2 7.3 7.4 7.5

General..............................................................................................................................20 Active Power Control .......................................................................................................21 Blackstart and Island Operation........................................................................................23 Excitation Systems............................................................................................................23 Plants Subject to Central Dispatch....................................................................................24

MISCELLANEOUS .......................................................................................................25

8.1 8.2

Communication.................................................................................................................25 Variation and Addition .....................................................................................................25

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INTRODUCTION The terms and conditions on which connection to the transmission system is granted will be set out in the commercial agreement, on reasonable terms, entered into by the User and the transmission system and market operator (TSMO). This is called the connection agreement (CA) and is a specific contractual agreement between the TSMO and the User for each individual connection point of the transmission system. Where a single User has multiple connections on a single site then only a single CA is required. The TSMO, by entering into a CA with a particular User, must ensure that the quantity and quality of service that it agrees to provide to the relevant User are not less than could be provided if the transmission system was planned, designed and operated in accordance with the criteria set out within this connections code, except if specifically varied by the relevant CA. Users by entering into CA with the TSMO must ensure that they abide by the rules, procedures, technical specification and equipment requirements as outlined in this grid code, except if specifically varied by the relevant CA. To the TSMO, the assignments are submitted to practice the activities of transmission and dispatching of electric energy. Therefore the TSMO, with the purpose to guarantee the safety and the operational connection among the nets, discipline such connection with specific technical rules as specified to the following chapter 2. The destined Power introduced by the User on the Net in MW has to be defined. In the following, an example of interconnection procedure is proposed, based on the Consultant experience and on the Connection Rules included in the Grid Code issued by the Kosovo TSO KOSTT (in the following TSMO).

DEFINITION OF THE RULE OF OPERATION The purpose of the present Rule is to establish the formalities of management of the connection between the plant of the User and the “TSMO”. The contracting parts of the present Rule are: ● for the TSMO: ..............................; address................................ ● for the User: ............................. address..................................

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PLANT CHARACTERISTICS, CONNECTION AND PROTECTION SYSTEM

3.1

Characteristics of the Plant The User Thermal Power Plant (to specify the typology) has a nominal Power equal to ……..... MW and is constituted by the following parts: •

nr... gas turbine of .... MW, nr.... alternator of ... MVA, Voltage of.…,. kV;

•

nr... steam turbine of ... MW, nr... alternator of... MVA, Voltage of ...,. kV;

•

nr... step-up transformer ..,. /..,. /.. kV of... MVA, supplied with OLTC (... ±. x...,.%), operated manages with neutral in general HV connected to earth directly or through a disconnecting switch.

The User declares, under its own responsibility, that the plant complies to what is defined in the current IEC standards, from the Connection and Dispatching Rules in the Grid Code and from any other existing complementary agreement. The User, declares, moreover besides, that the plant responds to the actual technical Norms. The plant electric simplified single line diagram of the of the User is included in annex 1.1, together with the list of the protection and measuring equipment. 3.2

Characteristics of the Connection The User power plant is connected to the substations........, referred to as "point of delivery", through the line ......, ... kV, with a length of …... km. The Connection Agreement (CA) must contain the specific conditions that have been agreed for the connection and the access to the transmission network. Data and information exchanged must be part of the CA and, if applicable, must include but not be limited to the following list: -

details of the connection point (ownership, configuration, list of associated assets, associated plant identification and nomenclature, fault levels, short circuit infeeds, impedance, switchgear ratings, nominal voltages, protection equipment type/fault clearance time/settings of relays, intertripping schemes, special automatic features etc.);

busbar protection schemes and settings;

system splitting or islanding schemes that impact on a generator’s plant;

frequency and voltage sensitive generating unit protection settings;

registered capacity and the power transfer capability of associated generating units;

the agreed authorised demand that may be supplied to the User;

details of the metering installation and metering arrangements and adjustments for losses where the actual metering equipment differs from the connection point;

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details on requirements for CTs, VTs, contacts for protection, metering, interlocking, etc;

testing intervals for associated protection systems;

agreed protocols for maintenance co-ordination;

operational diagrams;

site drawings;

any site specific special conditions, derogation, etc.;

any specific priority, operational conditions and/or switching arrangements required for security reasons;

any other data in text or diagram form that will be deemed necessary by both parties.

The outline timescales for the procedures are as follows: -

Submit formal application: (User);

Deliver completed offer including the draft CA: (30days TSMO);

Accept offer: (30days User);

Sign agreement: (30days User/TSMO);

Provide detailed planning data: (30days User).

It is important to note that the timescales given above are maximum times and for relatively straightforward connections the expectation is that the stages of the process would be completed in a much shorter timescale. For complex connections where these timescales cannot be met, the TSMO will inform the User and will provided the User with an alternative timescale within 30 days after formal application. 3.3

Point of delivery of the Plant For a new connection or a modification to an existing connection point, the User must submit a formal application to the TSMO, advising it of all the relevant information. This information is required to enable the TSMO to assess the application, including the power transfer capability that the system interconnection facilities should provide. It applies to both applicants for connection that need to be supplied with electric energy (demand Users) or to applicants who wish to export the generated electric energy for sale (generation User). During the initial phase the User will submit the standard planning data and the preliminary project planning data as specified in the planning code. Although this data will be treated by the TSMO as confidential data it may be shared with other system operators if this is necessary to progress the application. The TSMO must in response to a submitted application to connect, proceed to prepare an offer to connect and must provide the applicant with a completed offer, no later than 30 days after receiving the initial application.

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In order to maintain levels of service and quality of the power system, the TSMO may consult other network operators in order to determine the following: -

the performance requirements for the equipment to be connected;

the extend and cost of reinforcements that may be required to other parts of the transmission network;

the possible material effect of this new connection on the transmission network power transfer capacity.

If the User wishes to accept an offer to connect, then the User must take the following steps: -

inform the TSMO, in writing, that he accepts the offer within the time period stated in the offer which in any case must be no less than 30 days, after which it automatically passes;

within 30 days enter into a CA with the TSMO;

within 30 days after signing the CA, the User must provide detailed planning data as specified in the planning code. The TSMO can now treat all data as non-confidential and it can be used without restriction in the (transmission system development plan) and by the DSOs in the development of their detailed plans.

The following two tables summarise the information to be supplied by the user. Table 3-1 – Generating Unit Data GENERAL POWER STATION DATA

UNITS

ENTER DATA BELOW

Connection Point to Transmission Network Text

Voltage at Connection Point

Number of Generating Units to which this data applies

Type of Generating Unit

Text

Electrical Machine Type

Text

Registered Capacity

Rated Terminal Voltage

Rated Power Factor

cosϖ

Generator Performance Chart

Chart

Black Start Capability

Text

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Table 3-2 – Generating Unit Data

RATED PARAMETERS DATA

UNITS

Generating Unit Rated Output

MVA

Rated Active Power Output

Generation data for short circuit studies Short Circuit Ratio Xd’-Generator Direct Axis Transient Reactance Xd’’- Generator Sub- Transient Reactance X2- Generator Negative Phase Sequence Synchronous Reactance X0- Generator Zero Phase Sequence Synchronous Reactance

pu machine MVA base pu machine MVA base pu machine MVA base pu machine MVA base

Dynamic Simulation Xq’-Generator Quadrature Axis Transient Reactance

pu machine MVA base

Xd’’-Generator Sub-transient Reactance

pu machine MVA base

Xl- Armature Leakage Reactance

pu machine MVA base

Tdo’- Generator Direct Axis Transient open circuit: Time Constant

Sec(s)

Tdo’’-Generator Direct Axis Sub transient open circuit: Time Constant

Sec(s)

Tqo’- Generator Quadrature Axis Transient Open circuit: time Constant

Sec(s)

Inertia Constant

MWsec/MVA

Exciter

Type

Power System Stabiliser

Type

Step-up Transformer Transformer Rated

MVA

Transformer voltage ratio LV/HV

kV/kV

Transformer positive sequence resistance R1

Transformer positive sequence reactance X1 (uk)

Transformer Vector group

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ENTER DATA BELOW

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Interconnection procedures

3.4

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Blocks It is necessary to describe with a block diagram the connection of the power plant in the point of delivery of the User.

3.5

Characteristics of the Protections Each connection between the User and the transmission network must be controlled by a circuit breaker capable of interrupting the maximum short circuit current at the connection point. The transmission network development plan gives values of short circuit current and the rating of the transmission circuit breakers at existing and committed connection points for future years. The scope and arrangements of the relay protections of generating units, step-up transformers, busbar and power lines owned by the generator shall at least be in compliance with the requirements of the relevant Kosovan Standards as referenced in the standard documents. The setting of the relay protections against faults in the transmission network, owned by the generator but external to the generating units and step-up transformers with respect to impedance, current and time shall be co-ordinated with the TSMO. The technical requirements for low frequency relays, covering frequency settings, measurement period settings, operating time, facility stages, output contacts and voltage supply requirements will be as specified by TSMO. The principle applied is that all power lines shall be protected by at least one protection designed for all types of faults. The normal arrangements at the different voltage levels are as follows: -

for power lines of 400kV two high speed main protections and one backup protection are provided;

for power lines of 110kV and 220kV main and backup protection are provided.

Backup protection may be provided remotely. The fault clearance times for faults on a Userâ&#x20AC;&#x2122;s equipment directly connected to the transmission network, from fault inception to the circuit arc extinction shall not be greater than the following: -

90ms at 400kV;

100ms at 220kV;

140ms at 110kV.

In the event that the above fault clearance times are not met as result of failure of the main protection systems to operate, the Users shall provide back-up protection. The TSMO will also provide back-up protection and these back-up protections will be co-ordinated so as to provide discrimination. Back-up protection shall operate to give a fault clearance time of no greater than 500ms at voltages of 110kV and above. European Agency for Reconstruction PĂśyry-CESI-Terna-Decon

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No bus bar protection, circuit-breaker fail protection relays, AC or DC wiring (other than power supplies or dc tripping associated with the User’s plant and apparatus) shall be worked upon or altered, by or on behalf of, a User in the absence of a representative of, or written authority from, the TSMO. Breaker Fail Protection In order to mitigate failures in the event of a circuit breaker fault involved in the connection between a User’s system and the transmission network, breaker fail protection shall be used for the automatic trip of all circuit breakers adjacent to the faulty circuit breaker. Automatic Reclosing Where automatic reclosing of TSMO circuit breakers is required following faults on the User’s system, automatic switching equipment shall be provided in accordance with the requirements specified in the corresponding CA. Protection Settings Protection and relay settings will be co-ordinated for existing, new and/or modified connections and subsequently update across the connection point, as outlined in each CA, to ensure effective disconnection of faulty equipment. All data that is reasonably required must be exchanged at the time of signature of the CA and regularly updated by both parties in the event of any data changes. This information must include as a minimum: -

fault levels and fault infeeds from the system;

protection equipment type, fault clearance time, relay settings;

differential protection setting for the generating unit/step up transformer unit/short distance lines;

generating unit protection setting;

busbar protection;

frequency and voltage sensitive generating unit protection settings;

operation and safety diagrams;

site drawings.

Protection Communications Communications for acceleration of relay protection signals and remote tripping of circuit breakers shall be the subject of design and agreement between the User and the TSMO. For power lines connecting a power plant to the transmission system two independent channels, independent from each other and at least one independent from the line to be protected, must be provided for relay protections installed at both ends of the connecting power line and the time for transmission of signals shall not be longer than 20ms. These channels can be used, if required, for the European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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remote switching out of adjacent switching under the action of the breaker fail protection. Synchronising Device All electrical connections to the transmission switchgear rated at 110kV and higher must be equipped with check synchronising systems. All synchronous generating units must be equipped with precision automatic synchronising systems. Frequency Protection Generating units of thermal power plants of above 20MW capacity must be equipped with a system to separate the unit including the supply of house-load system from the system in case of frequency excursions due to emergency conditions. The system for separation of units from the system must provide for adjustment of frequency within the range of 46 to 50 Hz, and in terms of time within the range of zero to three seconds. Protection Dependability The target performance for the system fault dependability index shall be not less than 99%. This is the measure of the ability of the protection to operate to initiate successful tripping of circuit breakers that are associated with the faulty item of apparatus. Fault Recording Facilities Where fault recording facilities are required by the TSMO their technical requirements should conform to the fault analysis standards that are produced and revised by TSMO. Earthing For the transmission system direct earthing is normally used but in all cases the earthing of all users plant and apparatus and provision of an earthing system shall as a minimum requirement be in accordance with the recommendations contained in the “Guide for Safety in Alternating Current Substations”. ANSI/IEEE No. 80, 1986”. Fault Level Considerations The short circuit rating of the user’s equipment at the connection point shall be not less than the design fault level of the transmission system to which it is connected. System Monitoring The user should provide such voltage, current, frequency, active power and reactive power, transformer tap position outputs and status points from his system European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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as are considered reasonable by the TSMO to ensure adequate system monitoring. The telemetry RTU (or equivalent) in such a situation will be provided, installed and maintained by the TSMO. Under the requirements of this connections code all new generating units and power plants, including generating units with an output of 5MW and greater connected to the distribution system, will need to provide real time information including MW to the TSMO for monitoring purposes. Communications Where required by the TSMO in order to ensure the monitoring and control of the transmission system communication between users and the TSMO shall be established in accordance with the relevant CA. These communications shall include some or all of the provisions detailed in the following: -

primary speech facility;

backup or emergency speech facility using communication channels and power supplies completely independent from the primary facility;

facsimile machine;

telemetry for system monitoring;

electronic data link;

e-mail;

main and backup metering links as required by the metering code

Site Related Conditions The TSMO and the User for each connection point shall agree connection site responsibility schedules that will include the following: -

ownership, control, operation and maintenance details at the connection point;

operational diagram;

site common drawings;

schedule of HV plant and apparatus;

schedule of telecommunication and telemetry equipment;

metering installation details;

site access arrangements;

protection information;

interlocking schemes;

information for carrying out work on protection;

maintenance arrangements;

safety management responsibility.

Plant and Apparatus Identification

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The TSMO and the relevant user will follow the requirements of the plant and apparatus identification code (within the operations code). 3.6

Disconnection and Reconnection

3.6.1

Voluntary Disconnection Users are entitled to required voluntary permanent disconnection of their equipment from the transmission system. If a generator decides to permanently disconnect its equipment then unless agreed otherwise and specified in the relevant CA, he must give the TSMO notice in writing of its intention at least 6 months before the commencement day for the disconnection. Users taking only demand can disconnect their plant from the transmission system at any time under the following circumstances: -

permanently using the an agreed disconnection procedure;

temporarily by agreement with the TSMO for demand control;

under the terms of an ancillary services agreement.

The user must bear all the costs directly attributable to the voluntary disconnection and decommissioning. The TSMO will undertake the commissioning procedures and will notify other users in the event that it believes the terms and conditions of the relevant CAs could be affected by procedures for disconnection 3.6.2

Involuntary Disconnection The TSMO may decide to disconnect a generatorâ&#x20AC;&#x2122;s facilities from the transmission system due to any of the following circumstances: -

pursuant to orders issued with the necessary level of authority;

during an emergency;

in accordance with Kosovan Laws;

in accordance with the provisions of the relevant CA;

in the event of a system incident causing the tripping of the generating unit.

Demand users shall be subject to the requirements of the grid code in particular to the demand control code (within the operations code) and the contingency planing code (within the operations code) with respect to the following: -

mandatory demand reduction;

underfrequency load shedding.

In all cases of disconnection the TSMO must undertake review and then provide report to the relevant generator advising of the circumstances requiring such action. Generally there will be no compensation to generators for lost revenue due to involuntary disconnection without advance notice in most circumstances. Examples of such circumstances are as follows: European Agency for Reconstruction PĂśyry-CESI-Terna-Decon

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prevention of imminent danger to the health and security of people or facilities;

accident in the power plant or the connection facilities;

non-fulfillment by the plant operating staff of an order given by the TSMO;

Other circumstances beyond the control of the TSMO not resulting from any international action or violation of the contract on their part and not subject to planning.

The TSMO will compile report that will be submitted to the regulator who will decide if further action is required 3.6.3

Obligation to Reconnect The TSMO must ensure that a generatorâ&#x20AC;&#x2122;s facilities are reconnected to the transmission system at a reasonable cost to the generator as soon as practicable if: -

the TSMO reasonably satisfied that the emergency that caused the generator to be disconnected no longer exists;

the TSMO is reasonably satisfied that there no longer exists a reason for the disconnection under the grid code or Kosovan Laws or the relevant CA;

a breach of the CA, giving rise to disconnection, has been remedied and the generator has taken all necessary steps to prevent the reoccurrence of the breach and has delivered binding undertakings to the TSMO that the breach will not re-occur.

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PLANT OPERATION

4.1

Dedicated Personnel

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All the activities inherent the management of the connection must be carried out from detached personnel. List of functions, of the dedicated personnel, of telephone/fax number and e-mail, respectively of the “TSMO” and of the User, must be reported in annex and must be always updated. 4.2

Normal Operation Under normal conditions of operation the generating groups will be managed in parallel with the “TSMO”; therefore the relevant circuit breakers will be, as a rule, closed. The parallel of the groups, or any variation to the normal scheme of operation, must be always agreed between the User and the Control Room of the “TSMO”; at the same way, the User must inform at the right time the “TSMO” of every useful news for the operation of the plant and the generation groups. Plant stops on fault breakdown must be signalled to the “TSMO” at the right moment; in this communication (by fax) the fault type and the envisaged period to re-enter into operation will also be specified in parallel. The User groups do not have to cause poor service or troubles to the operation of the “TSMO”; at the same time, the User it has to avoid recovery voltages from other grids.

4.3

Emergency Operation The generating groups of the User must be able to remain in parallel to the “TSMO” with the electric parameters, voltage and frequency, within the following limits: ● Voltage ± 10% Vn ● Frequency from 48,5 to 51,5 Hz. These limits must be respected in two possible cases of operation of the “TSMO”: fully connected or partially separate, with the generating groups of the User in operation. In case of islanding, the “TSMO”, as soon as the conditions of the grid will allow, will give the dispositions to restore the normal operation. In case of restricted service, with total lack of voltage supply, the “TSMO” will caary out the necessary actions for the restoration of service If the test has positive results, the User can re-enter in parallel, according to agreement with the “TSMO”. In case of fault near the User, it will immediately disconnect the plant through opening of the relevant circuit breaker; in every case, the User expressly exonerates

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Page 16 (31) November, 2007

the “TSMO” for any damage or consequent responsibility for overvoltages on the connections. In case of permanent fault, the “TSMO” and the User will perform on their own responsibility the procedure described at chapter 6.

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PRODUCTION PROGRAMMING AND UNAVAILABILITIES

5.1

Production Programming

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During the testing period, the User will communicate the production program to the “TSMO” before 10:00 of every Friday. Such program can be modified by the User in case of necessities, communicating it to the “TSMO” before 10:00 of the day ahead. Subsequently, with the beginning of the business, the User will proceed as follows. The User will communicate by fax or by e-mail to the “TSMO” within the hours 10:00 of every Friday, the production program of the active and reactive energy for the period from the hours 00:00 of the following Saturday, up to the hours 24:00 of following Friday. The program can be modified by the “TSMO”, with communications by fax or by e-mail, within the hours 10:00 of the preceding day to that party from the variation of program. The User must communicate by fax to the “TSMO” the possible unavailability of the programmed power and the relevant causes. The “TSMO” will check the compliance with the program. In any case, the “TSMO”, for particular events, has faculty to ask to the User, in real time, variations to the programmed production. 5.2

Annual and occasional planning: maintenance The User and the “TSMO” will take preliminary agreements with the purpose to formulate a proposed unavailability of the plant. In particular, the User will formulate within June 1st a proposal for an unavailability plan due to the maintenance for the following year. The final plan of the programmed unavailability to be performed in the following year "A" will be arranged between the “TSMO” and the User within 15 September of the year "A-1." Unavailability due to occasional works must be submitted to the “TSMO” in the respect of the aforesaid procedures.

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PLANT CONTROL

6.1

Remote Information

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In order to control the power plant by the “TSMO”, the necessary equipments for collecting and transmission the following information must be installed: -

measurement of the active power, of the reactive power and of the voltage at the plant MV busbars

measurement of the active power, of the reactive power and of the voltage at the plant HV busbars

measure of the active Power, of the reactive Power and of the Voltage at the connection point

state of the circuit breakers at the MV side of the groups;

state of the circuit breakers of the group transformers;

In cases of unavailability of the system for collecting and transmitting data, on application of the “TSMO” the User will send the data daily by fax or e-mail. 6.2

Measurements For the measure of the active and reactive energy injected in the grid and for the verification of active and reactive power, a systems for data elaboration and transmission has to be installed, constituted by: -

nr 1 complex of measure on the HV side of the connection toward the User (two-way both for the active one and for the reactive one);

nr 1 complex of measure on the MV side of the connection toward the User (two-way both for the active one and for the reactive one);

nr 1 complex of measure on the group unit (unidirectional for the active power and two-way for the reactive one);

the measurement apparatus that records the energy measurements to be transmitted to the “TSMO” (on request by the TSMO).

The “TSMO” has the right to ask the User periodic verification of the measuring complexes. 6.3

Monitoring Equipments The list of equipments for recording of the perturbations and the electric variables is to be reported in annex. A system for acquisition, recording and remote transmission of all the information and data gathered has to be installed by the User; the User will have to take care of the availability of such system with the purpose to allow the “TSMO” the connection and the acquisition of the data for the analysis of the service provided. In case of unavailability of those systems, the registered information must be sent in due times to the “TSMO”.

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Page 19 (31) November, 2007

Maintenance All the maintenance on the apparatuses described in the paragraphs 6.1, 6.2 and 6.3 will be care of the owners, for the relevant competence.

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ADDITIONAL REQUIREMENTS FOR GENERATORS

7.1

General Generators shall operate and maintain their generating unit’s voltage control facilities, their generating unit’s frequency control facilities and the reactive power control of the network interconnection facilities, in strict adherence to the grid code and instructions received from the TSMO for the operation and security of the transmission network. Each generating unit must be capable of continuously supplying its registered output within the system frequency range 50 ± [0.5] Hz. Any decrease of output power occurring in the frequency range [48.5 to 51.5] Hz, should not be more than pro rata with frequency. Un its connected on 110 kV

Voltage (% of nominal Voltage) 110%

Frequency (Hz) 48.5

49.5

50.5

51.5

decrease of output power should not be more than pro rata with frequency.

90 % gW hen a ge nerating unit becomes isolated from the rest of the total system but is still supplying Custom ers, the speed governor must also be abl eto respond to a system freq uency between 47.5 and 52 Hz unless this causes it to operate below its designed Minim um Ope ratin g Le vel, when it is possible that it may trip after a time.

Figure 7-1 Units connected on 110 kV.

European Agency for Reconstruction Pöyry-CESI-Terna-Decon

Continuously supplying its registered output

decrease of output power should not be more than pro rata with frequency.

Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Interconnection procedures Units connected on 220 and 380 kV

Page 21 (31) November, 2007 Voltage (% of nominal Voltage)

105%

Frequency (Hz) 48.5

49.5

50.5

51.5

95% decrease of output power should not be m ore than pro rata with frequency.

Continuously supplying its registered output

decrease of output power should not be m ore than pro rata with frequency.

gW hen a generating unit becomes isolated from the rest of the total system but is still supplying Customers, the speed governor must also be ableto respond to a system frequency between 47.5 and 52 Hz unless this causes it to operate below its designed Minimum Operating Level, when it is possible that it may trip after a time.

Figure 7-2 Units connected on 220 and 380 kV.

Each generating unit directly connected to the transmission system should not have its active power output affected by voltage changes in the normal operating range specified in the voltage control code not greater than 2%. Each generating unit and the power plant in which is located, must be capable of continuous uninterrupted operation during the occurrence of the following:

7.2

Overspeed up to 110%;

Unbalanced load 5 – 10%;

Exciter response ratio more than 0.5%;

Negative phase sequence current up to 5%:

Active Power Control All synchronous gas turbines and hydro generating units of capacity over 1 MW and turbo generating units of over 5 MW must be equipped with turbine speed and active power automatic control systems. The speed governor of each generating unit must be capable of operating within the generating unit’s technical limits and in a frequency range defined in paragraph 0. The speed governor in co-ordination with other control devices must control the generating unit active power output with stability over the entire operating range of the generating unit and must be able to maintain the set active power of the generating unit with accuracy as follows: -

For units of up to 20 MW - not less than ± 2% of rated power;

For units above 20 MW - not less than ± 1% of rated power:

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Turbine speed governors must be capable of equalising the speed (frequency) of the synchronous set with the frequency of the transmission system prior to connection of the generating unit in parallel with an accuracy of at least ± 0.1%. Automatic speed and power control systems for turbines rated over 10 MW shall be transformed from ‘power control’ mode to ‘speed control’ mode by rejection of the nominal load of the turbine by the action of the overspeed protection. Turbine automatic speed control systems must provide for limitation and protection against overspeed of the synchronous set and adjustment within a range as follows: -

For steam turbines - 104 to 112% of their nominal value;

For hydro and gas turbines - 104 to 130% of their nominal value:

Each generating unit with a registered capacity of at least [10MW] must be fitted with suitable equipment to receive LFC signals from the associated TSMO control feature. The TSMO will determine the selection and use of this function to ensure the overall Kosovan Power System meets the requirements of the UCTE rules and standards as set out under the frequency control code (within the balancing code). The LFC system signalling criteria are as follows: -

Accuracy 0.5 to 1.5% for active power measurement;

Accuracy 1.5 mHz for frequency measurement;

Regulation update time no more than 2 seconds;

Associated with the above the TSMO SCADA/EMS system will continuously display the active power output, higher and lower operating limits and run up / run down rates: Where a generating unit becomes isolated from the rest of the total system but is still supplying Customers, the speed governor must also be able to respond to a system frequency between 47.5 and 52 Hz unless this causes it to operate below its designed minimum operating level, when it is possible that it may trip after a time. All gensets with a registered capacity of 10MW or more must have the capability to provide primary control (with the response timing and duration set out in the frequency control code subject to the following minimum requirements: -

The control band of the speed governor must be at least [+/-2%] of the generating unit’s registered capacity, and must be adjustable on instruction by the TSMO;

The speed governor must be capable of being adjusted, on instruction by the TSMO, so that it operates with an overall speed droop of between 3% and 4%, in case of hydro generating units, and between 4% and 6% in the case of thermal generating units;

The speed governor insensitivity shall be no greater than +10 mHz;

All generating units with a registered capacity of at least [10MW] must have the capability to provide secondary control, with the response timing and duration set out in the frequency control code (within the balancing code).

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Blackstart and Island Operation Hydro power plants with a generating unit of registered capacity of at least [10MW] shall, if stipulated by the TSMO, provide a black start capability. All generating units with an approved black start capability will be made available under the terms of an ancillary services agreement, and meet the operational requirements set out in the contingency planning code. Turbine speed governors of generating units involved in system restoration after major system failures (hydro and gas turbines) shall be able to operate with an isolated load (island mode) in which case regulation will take place after altering the droop characteristic to insensitive mode. Transition of regulation modes shall take place as required by the prevailing operational circumstances: -

by criteria built into the governor - upper and lower limit of frequency, rate of change in frequency or loading;

by the power plant operator using a control switch;

remotely - by means of a telesignal from the dispatch centre dependent on the condition of the switchgear:

Turbine speed governors of units involved in the power system restoration after major system failures shall be able to start rotating initially and reach synchronous speed and be loaded in the absence of an external ac supply. 7.4

Excitation Systems Each generating unit must be capable of contributing to voltage control by continuous modulation of reactive power supplied to the transmission network. Each generating unit must be fitted with a continuously acting automatic excitation control system that may include stabilisers, to provide constant terminal voltage of the generating unit, without instability over the entire operating range of the generating unit. The output voltage limits of generating units must not cause excessive voltage excursions in excess of Âą10% of nominal. The voltage regulating equipment shall be able to maintain the output voltage level of the associated generating unit. The excitation system must provide for increase (forcing) in the excitation current and voltage of a synchronous generating unit as a factor at nominal load as follows: -

hydro generating units up to 25 MVA - min factor (ratio) 1.5 - min time 10s;

hydro generating units above 25 MVA - min factor 1.8 - min time 20s;

turbo generating units of up to 25 MVA - min factor 1.8 - min time 10s;

turbo generating units above 25 MVA - min factor 2.0 - min time 30s:

The forcing parameters must be achieved at a generating unit terminal voltage within the range of 80% to 120% of the nominal voltage and at a frequency range of 47.5Hz to 52Hz. The speed of change in the exciting voltage of the synchronous generating unit shall not be lower than 2 relative units/sec using as reference the exciting voltage under nominal load of the synchronous generating unit. European Agency for Reconstruction PĂśyry-CESI-Terna-Decon

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All synchronous generating units of capacity over 1 MVA must be equipped with an automatic voltage regulator (AVR). AVRs shall be capable of maintaining the voltage at the generating unit terminals with an accuracy as follows: -

for generating units of up to 25 MVA - not less than ± 1% of rated voltage;

for generating units above 25 MVA - not less than ± 0.5% of rated voltage:

AVRs must compensate for any drops in the voltage of the Unit Transformer as well as provide a stable distribution of reactive power between the synchronous generating units connected to common busbars. AVRs must provide for limitation of the following: -

Minimum excitation;

Rotor maximum current;

Synchronous generating unit stator maximum reactive current:

The excitation systems of generating units involved in the restoration of the transmission network after severe system incidents, shall be able to regulate the excitation of the generating unit in the absence of an external ac supply. Loss of Synchronism Protection Synchronous units, which are registered by the manufacturer to be capable of asynchronous operation (with or without excitation), shall be tested for stability at the point of their connection to the transmission network. In the cases when asynchronous operation is not permitted in terms of stability, the generating units must be equipped with protection against asynchronous operation if they become disconnected from the network. 7.5

Plants Subject to Central Dispatch All eligible generating units must be fitted with LFC and a power system stabiliser. The requirements for these will be as determined by the TSMO.

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Studies to support the development of new generation capacities and related transmission - Kosovo Task 2.3. Interconnection procedures 8

MISCELLANEOUS

8.1

Communication

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All the communications among the “TSMO” and the User will be exchanged according to the procedures reported in the preceding paragraphs. The communications by fax will have to bring the following information:

8.2

date and time of application;

name and position of the applicant;

name and position of the receiving person;

type of application.

Variation and Addition What is written in the present Rules that could be impacted by technical and/or organisational innovations of each of the contracting parts, will be rearranged among the parts and at communicated in due time.

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Page 26 (31) November, 2007 Attachment nr. 1.1

SINGLE LINE DIAGRAM (PLANT) ………………………………..

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Page 27 (31) November, 2007 Attachment nr. 1.2

HV SWITCHYARD SINGLE LINE DIAGRAM

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PROTECTIONS LIST

CONNECTIONS “TSMO” – USER

USER’S CONNECTIONS

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Page 29 (31) November, 2007 Attachment nr. 2.2

PERTURBATIONS EQUIPMENT RECORDING AND ELECTRICITY MEASUREMENTS MONITORING

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NAMES AND FUNCTIONS OF THE PERSONNEL AUTHORIZED BY THE “TSMO”

“TSMO” Last name & name

Nr. Office

Qualification

Nr. Fax

E-Mail

Phone

……………

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…

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…

……………. ……………. ……………. . ……………. .

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Page 31 (31) November, 2007 Attachment nr. 3.2

NAMES AND FUNCTIONS OF THE PERSONNEL AUTHORIZED BY THE “USER”

USER Last name & name

Nr. Office

Qualification

Nr. Fax

E-Mail

Phone

……………

………………

……………. …………… …………………….

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…

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…

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European Agency for Reconstruction Pöyry-CESI-Terna-Decon

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