Technical Assistance Consultant’s Report
Project Number: 43456 June 2010
Kyrgyz Republic: Transmission and Distribution Metering (Financed by the Technical Assistance Special Fund)
Prepared by AECOM New Zealand Ltd. Auckland, New Zealand
For the Ministry of Energy and JSC National Electrical Grid of Kyrgyztan
This consultant’s report does not necessarily reflect the views of ADB or the Government concerned, and ADB and the Government cannot be held liable for its contents.
Asian Development Bank
June 2010
Executing Agency Implementing Agency Ministry of Energy JSC "National Electrical Grid of Kyrgyzstan"
TA Nº 7368-KGZ Transmission Metering & Communications Project
Feasibility Study Report 60146737/109
TA Nº 7368-KGZ Transmission Metering & Communications Project
Feasibility Study Report
Client: : Asian Development Bank
Contract Nº S20828
Prepared by: AECOM New Zealand Limited 47 George Street, Newmarket, Auckland 1023, PO Box 4241, Shortland Street, Auckland 1140, New Zealand T +64 9 379 1200 F +64 9 379 1230 www.aecom.com
June 2010
60146737
June 2010 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Table of Contents
1.0 Introduction 1 1.1 Appointment 1 1.2 Terms of Reference 1 1.3 Feasibility Study Report 1 1.4 Objectives 2 1.5 Project Team 2 1.6 Project Office 3 1.7 Acknowledgements 3 2.0 Background and Overview 4 2.1 Kyrgyzstan 4 2.2 Power Sector 5 3.0 Wholesale Metering 10 3.1 Existing Situation 10 3.2 Wholesale Metering Concept Design 15 3.3 Wholesale Metering Scope and Cost Estimate 17 3.4 Safeguards 19 4.0 Substation Upgrades 20 4.1 Existing Situation 20 4.2 Substation Upgrades Scope and Cost Estimate 20 4.3 Safeguards 21 5.0 Communications 22 5.1 Existing Communications Systems 22 5.2 New Communications Systems 23 5.3 Fibre Network Performance 27 5.4 Communications System Upgrade Advantages 27 5.5 Communications System Scope of Work and Costs 28 5.6 Safeguards 28 6.0 SCADA 29 6.1 Existing SCADA System 29 6.2 SCADA Upgrade 30 6.3 Substations 32 6.4 SCADA Upgrade Advantages 33 6.5 SCADA System Scope of Work and Costs 34 7.0 Cost Summary 35 8.0 Project Implementation and Procurement 36 8.1 Project Implementation 36 8.2 Procurement 37 Appendix 1 Terms of Reference 39 Appendix 2 List of Key Officials Met 41 Appendix 3 NEGK Substations 43 Appendix 4 Interconnection of Generation with NEGK Substations 49 Appendix 5 Interconnection of DisCos with NEGK Substations 51 Appendix 6 International Transmission Lines 59 Appendix 7 Digital Wholesale Meters 61 Appendix 8 Details of Substation Upgrade Equipment 67 Appendix 9 Fibre Optic Network 69 Appendix 10 Schedule of Transmission Lines 71 Appendix 11 Simplified Transmission Single Line Diagram 79 Appendix 12 Implementation Schedule 81 Appendix 13 NEGK's PIU Experience 83
FIGURES
Figure 1 Map of Kyrgyzstan 4 Figure 2 Corporate Structure of NEGK 7 Figure 3 NEGK Central Dispatch Centre 7
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Figure 4 Power Flow between Entities 10 Figure 5 Typical NEGK Electromechanical Induction Watt-Hour Meters 11 Figure 6 Typical NEGK Digital Wholesale Meters 12 Figure 7 NEGK Digital Meter Testing 12 Figure 8 Old CT and VT Name Plates 14 Figure 9 Typical Modern Four-Quadrant Energy Meter 15 Figure 10 New Wholesale Metering between Entities 16 Figure 11 Substation Metering Configurations 17 Figure 12 Old 220 kV Circuit Breakers 20 Figure 13 Old PLCC Equipment 22 Figure 14 More Modern PLCC Equipment 22 Figure 15 Line Traps 22 Figure 16 New Multiplexer 23 Figure 17 Radio Relay and Cell Phone Antennae 23 Figure 18 Radio Relay Antenna (one broken) 23 Figure 19 Old PABX Equipment 23 Figure 20 Telephone Console 23 Figure 21 Workers Replacing Earth Wire with OPGW 25 Figure 22 ADSS on MV line 25 Figure 23 GPRS Network Arrangement 26 Figure 24 ChuPVES Regional Control Room 29 Figure 25 Telemetry Lady 29 Figure 26 SCADA Screens 29 Figure 27 Interface Device 30 Figure 28 SCADA Screen, Load Curve 30 Figure 29 SCADA Screen, Mimic Diagram 30 Figure 30 Equipment Architecture - Fibre Connected Substation 32 Figure 31 Equipment Architecture - GPRS Connected Substation 33
TABLES
Table 1 NEGK Transmission Lines 7 Table 2 NEGK Substations 8 Table 3 DisCo Features 8 Table 4 NEGK Cross-Border Wholesale Meters 11 Table 5 Large Customer Substations 11 Table 6 Existing NEGK Wholesale Meters 13 Table 7 NEGK CT & VT Testing Results 14 Table 8 Estimated Quantities of Wholesale Meters 18 Table 9 Estimated Quantities of Replacement CTs and VTs 18 Table 10 Estimated Cost of Wholesale Metering Component 19 Table 11 Estimated Quantities of Substation Replacement CBs, CTs and VTs 21 Table 12 Estimated Cost of Substation Upgrade Component 21 Table 13 Estimated Cost of Communications Component 28 Table 14 Estimated Cost of SCADA Component 34 Table 15 Estimated Total Project Cost 35
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Glossary ADB Technical Assistance Classification
Sector Energy Subsector Electricity transmission and distribution Targeting Classification General Intervention Themes Economic growth, Environmental sustainability Subtheme Promoting macroeconomic stability, Widening access to markets and economic opportunities, Natural resources conservation.
Abbreviations and Acronyms
ADB Asian Development Bank MoE Ministry of Energy ADF Asian Development Fund MPLS Multi Protocol Label Switching ADSS All Dielectric Self-Supporting MSP Ministry of State Property AECOM NZ AECOM New Zealand Ltd NCC National Control Centre CAPS Central Asian Power System NEGK National Electrical Grid of Kyrgyzstan CB Circuit Breaker NIST National Institute of Standards and CHP Combined Heat and Power (Plant) Technology CSCS Computerised Substation Control System NMS Network Management System CT Current Transformer OJSC Open Joint Stock Company CVT Capacitor Voltage Transformer OPGW Optical Ground Wire DisCo Distribution Company PABX Private Automatic Branch Exchange DNP Distributed Network Protocol PIC Project Implementation Consultant EIRR Economic Internal Rate of Return PLCC Power Line Carrier Communications EMS Energy Management System PPTA Project Preparatory Technical Assistance EPP Electric Power Plant PTSN Public Switched Telephone Network FIRR Financial Internal Rate of Return PVES (Predpriyatie Visokih Elektricheskih Setey) GoK Government of Kyrgyzstan NEGK Regional Centres GGSN Gateway GPRS Support Mode QCBS Quality-and-Cost-Based-Selection GPRS General Packet Radio Service RCC Regional Control Centre GPS Global Positioning System RTU Remote Terminal Unit GSM Global System for Mobile Communications SCADA Supervisory Control and Data Acquisition HEP Heat and Energy Plant SDH Synchronous Digital Hierarchy HPP Hydroelectric Power Plant SM Single Mode ICB International Competitive Bidding SOE Sequence of Events ICCP Inter Control Centre Protocol STM-1 Synchronous Transport Module level 1 IEC International Electrotechnical Commission T&D Transmission and Distribution IED Intelligent Electronic Device TA Technical Assistance IP Internet Protocol ToR Terms of Reference ITU-T International Telecommunication Union, UPS Uninterruptible Power Supply Telecommunication Standardisation Sector VT Voltage Transformer KPI Key Performance Indicator WAN Wide Area Network LAN Local Area Network LIC Large Industrial Customer
Currency Equivalents
The Kyrgyzstan currency is the Som (KGS). The exchange rate as of April 2010 was approximately USD 1.00 = KGS 45. In this report, "USD" refers to US dollars.
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Electrical Terminology
V (Volt) - Unit of voltage kV (kilovolt) - 1,000 volts W (Watt) - Unit of active power kW (kilowatt) - 1,000 watts MW (Megawatt) - 1,000 kW Wh (watt-hour) - Unit of Energy kWh (kilowatt-hour) - 1,000 Wh MWh (Megawatt-hour) - 1,000 kWh GWh (Gigawatt-hour) - 1,000 MWh TWh (Terawatt-hour) - 1,000 GWh VA (Volt-ampere) - Unit of apparent power kVA (kilovolt-ampere) - 1,000 VA MVA (Megavolt-ampere) - 1,000 kVA VAr (volt-ampere reactive) - Unit of reactive power Transmission System High Voltage (HV) - 500 kV, 230 kV, 115 kV lines supplying grid substations Medium Voltage Distribution (MV) - 35 kV, 10 kV or 6 kV lines supplying distribution substations Low Voltage Distribution (LV) - 400/230 V distribution and service lines Load Factor - Ratio of average power demand to maximum power demand Electrical Losses - Difference between energy delivered and energy sent out Grid Substation - Substation with primary voltage of 500 kV, 230 kV or 115 kV Distribution Substation - Substation with primary voltage of 35 kV or 10 kV and secondary voltage of 400/230 V
NEGK Regional Centres
ChuPVES Chuyskoe Predpriyatie Visokih Elektricheskih Setey. Chuy Organisation of High Voltage Transmission Lines IPVES Issyk-Kulskoe Predpriyatie Visokih Elektricheskih Setey. Issyk-Kul Organisation of High Voltage Transmission Lines NPVES Narynskoe Predpriyatie Visokih Elektricheskih Setey. Naryn Organisation of High Voltage Transmission Lines TPVES Talasskoe Predpriyatie Visokih Elektricheskih Setey Talas Organisation of High Voltage Transmission Lines JPVES Jalal-Abadskoe Predpriyatie Visokih Elektricheskih Setey Jalalabad Organisation of High Voltage Transmission Lines OshPVES Oshskoe Predpriyatie Visokih Elektricheskih Setey. Osh Organisation of High Voltage Transmission Lines.
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1.0 Introduction
1.1 Appointment International consulting services to assist the Asian Development Bank (ADB) with TA Nº 7368-KGZ Transmission Metering & Communications Project (initially titled “Transmission and Distribution Metering Project”) are being provided by AECOM New Zealand Limited (AECOM NZ) of Auckland, New Zealand, under Contract Nºs S20828, S21610 and A31878. AECOM NZ is assisted by international consultant Mr Janybek Omorov, Economic and Financial Analysis Expert, and a team of national experts.
The Executing Agency (EA) is the Ministry of Energy (MoE) and the Implementing Agency (IA) is Open Joint Stock Company “National Electrical Grid of Kyrgyzstan” (NEGK).
Contract Nº S20828 for consulting services of AECOM NZ's Mr Michael Breckon, Transmission & Distribution Metering Expert/Team Leader, was signed on 19 January 2010 and the Notice to Proceed was received on 20 January. Contract Nº S21610 for consulting services of AECOM NZ's Mr Scott Thode, Communications and SCADA Expert, was signed on 09 March and the Notice to Proceed was received on 10 March. On 19 April, ADB extended the Contract Completion from 30 April to 31 May 2010, and again on 10 June to 30 June, both without increase in contract amount. A new Contract Nº A31878 for additional consulting services of Mr Scott Thode, was signed on 26 May and the Notice to Proceed was received on 31 May.
Services by AECOM NZ commenced on 25 January 2010. The Project was originally scheduled to be completed by 30 April 2010; however, as a result of the uprising and overthrow on 07 April of ex-President Kurmanbek Bakiyev in Kyrgyzstan, all ADB Missions were suspended on 08 April. The AECOM NZ team demobilised from Bishkek on 10 April. Under the abnormal circumstances, the draft Feasibility Study Report was completed as much as possible in the home office and issued on 14 May.
Representatives from the Interim Government (IG) attended ADB's Annual Meeting held in Tashkent at the beginning of May and requested continuous support from ADB, including this Project. Consequently, the Project processing schedule resumed its operations, with the IG as the counterpart. A Fact-Finding Mission to finalise the Project design was carried out 26 May to 14 June 2010; the AECOM NZ team assisted the Mission from 01 to 14 June.
1.2 Terms of Reference The Terms of Reference for the two AECOM NZ experts are reproduced in Appendix 1. The scope of work provides for the preparation of the ensuing loan of the Transmission Metering & Communications Project for expected ADB funding in 2010. The Project is expected to contribute to the power companies' efforts to establish a solid commercial base of operations, and enhance transparency and accountability of the power sector, which will subsequently reduce system losses.
The original ToR also provided for an assessment of distribution master metering and a distribution billing system. However, due to the privatisation of Severelektro1 and pending sale of the other three DisCos in February (refer Section 2.2.7), the ADB2 agreed with the Government at that time to exclude the distribution subprojects from the project.
1.3 Feasibility Study Report This Feasibility Study Report sets out the background and scope of work of the assignment and addresses the requirements of the Terms of Reference. Issued as a draft version in May 2010, this Feasibility Study Report incorporates feedback and final revisions to the scope of work as agreed between ADB, MoE and NEGK during ADB's Fact Finding Mission held in Bishkek 26 May to 14 June 2010. It sets out the technical details of the proposed USD 44.8 million Project to be financed by ADB.
1 The privatisation and sale of the Discos was repealed by the new Interim Government in April 2010. 2 Refer TA 7368-KGZ: Preparation of Transmission and Distribution Metering Project Review Mission Aide Memoire dated 8 February 2010. June 2010 Page 1 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
1.4 Objectives The overall objective of the Small-Scale Project Preparation Technical Assistance (S-PPTA) Transmission Metering & Communications Project, provided by ADB, is to formulate the proposed Power Sector Improvement Project in Kyrgyz Republic. The ADB is considering providing a loan of approximately USD 44.8 million to the Kyrgyz Republic with the objective to reduce electricity losses, improve operational efficiency and bring transparency, efficiency and accountability to the power sector.
The final Project content is focused on the modernisation of the Kyrgyzstan transmission grid and includes the following three major physical components:
(i) Installation of wholesale digital meters and automated data acquisition equipment at existing grid substations to measure input/output between NEGK, generation companies, distribution companies and import/export boundaries, as well as at large industrial consumers; (ii) Installation of a communications loop and basic components of a SCADA (Supervisory Control and Data Acquisition) system linking six major substations in the northern transmission system, with interconnection to the national dispatch centre, to facilitate automated metering and commercial data acquisition and provide basic SCADA (iii) Upgrading of selected NEGK substations with replacement circuit breakers (CBs), current transformers (CTs) and voltage transformers (VTs).
In addition, the Project includes the following three non-physical items:
(iv) Implementation Consultant to assist NEGK with the implementation of the above three major components (v) Consultant to assist with financial management capacity building of NEGK (vi) Consultant to assist MoE with a study on the establishment of an independent regulator and a wholesale electricity transaction settlement centre which is intended to bring transparency and accountability to the power sector.
1.5 Project Team The following key personnel (excludes officers under previous Government) and project team were involved during the project formulation:
Asian Development Bank (ADB) Takafumi Kadono Energy Specialist Roka Sanda Investment Specialist Jim Liston Energy Specialist Cheong-Ann Png Attorney Lan Wu KYRM Country Director Mirdin Eshenaliev KYRM Project Implementation Officer
Ministry of Energy (MoE) Artykbaev Osmonbek Minister Erkin Abdykalikov Deputy Minister Aftandil Kalmambetov Deputy Minister
Ministry of Finance (MoF) Temir Sariev Minister Arzibek Kojoshev Deputy Minister Abdualim Nishanov Deputy Minister Erik Usubaliev Deputy Minister (until 07 June 2010) Saidbee Zulpuev Deputy Minister
National Electrical Grid of Kyrgyzstan (NEGK) Raimbek Mamirov General Director Murat Djumanalievich Durusaliev First Deputy General Director Bapa Raevich Janibekov Deputy General Director Finance
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Kubanychbek Ismailov Deputy General Director Alexey Borodin Technical Director Operations Leonid Popov Head of (Planning) Department Melisbek Isakovich Head of PIU Kubanichsek Asanovich Smankulov Head of Communications Department Anarbek Baibachaev Head Engineer Radio Relay Sergey Ribalov Head Engineer Tele-Mechanics Erkin Kurmanov Head Engineer of HF Tunukbek Kurmanbekovich Djumabaev Head of Meterology Department Vladimir Alexseevich Hohlov Chief Engineer Meterology Department Alexsander Mihaylovich Burimov Chief Engineer Communications Department
AECOM New Zealand Ltd Michael Breckon Transmission & Metering Expert/Team Leader Scott Thode Communications and SCADA Expert
Project Team Janybek Omorov International Consultant Energy Samat Sukenaliev Assistant Engineer Professor Yuri Simakov Transmission Metering Expert Djamila Aitmatova Environmental & Social Safeguards Expert Dinara Choibekova Economic & Financial Expert
A complete list of key officials met and/or who contributed during the project is given in Appendix 2.
1.6 Project Office As part of the facilities to be supplied by the EA/IA, NEGK provided a project office within their Head office in Bishkek. A broadband connection to facilitate internet communications, together with a wireless modem and print router, plus a multi-function printer/copier/scanner was organised/purchased by the Project team from the TA funds allocated for this purpose. The equipment will be handed over to the IA at the conclusion of the assignment.
1.7 Acknowledgements The AECOM NZ team gratefully acknowledge the co-operation and assistance of MoE and NEGK management and officers in providing all necessary information and support resources and facilitating visits to the project areas and NEGK facilities.
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2.0 Background and Overview
2.1 Kyrgyzstan Kyrgyzstan is a landlocked country of 198,500 km2 located in Central Asia, bordering Kazakhstan, China, Tajikistan and Uzbekistan. Current population is estimated as 5.4 million.
Figure 1 Map of Kyrgyzstan
Geographically, the mountainous region of the Tian Shan covers over 80% of the country, with the remainder made up of valleys and basins. Less than 8% of the land is cultivated, and this is concentrated in the northern lowlands and the fringes of the Fergana Valley. Lake Issyk-Kul in the north-eastern Tian Shan is the largest lake in Kyrgyzstan and the second largest mountain lake in the world. The highest peaks are in the Kakshaal-Too range, forming the Chinese border. Peak Jengish Chokusu, at 7,439 m, is the highest point. Heavy snowfall in winter leads to spring floods which contribute to Kyrgyzstan's hydro-electric resource. Kyrgyzstan has significant deposits of metals including gold and rare earth metals.
Bishkek in the north is the capital and largest city, with approximately 1 million inhabitants. In February 1991, the name of the capital, Frunze, was changed back to its prerevolutionary name of Bishkek. The second largest city is the ancient town of Osh, located in the Fergana Valley near the border with Uzbekistan. Osh is claimed to be older than Rome and was a major hub on the Silk Road in ancient times.
Originally part of the Soviet Union, Kyrgyzstan gained full independence on 25 December 1991 (the Soviet Union ceased to exist the following day). In 1992, Kyrgyzstan joined the United Nations Organisation.
Elected in October 1990, Askar Akayev was the Country's first President until the "Tulip Revolution" in March 2005, when he was replaced by new President Kurmanbek Bakiyev and Prime Minister Feliks Kulov. Fuelled by the public's concerns about rising heating and electricity tariffs, privatization of state-owned enterprises
June 2010 Page 4 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report and claims of corruption3, civil unrest broke out in the town of Talas on 06 April 2010, spreading to the capital Bishkek by the following day, resulting in the bloody overthrow of the Government and deposing of President Bakiyev on Wednesday 07 April. A transition government, led by former foreign minister Roza Otunbayeva, took control the following day. The new-Government moved quickly and by Thursday afternoon had rescinded several items of significance to this study. The proposed electricity tariff increase due to take effect imminently was cancelled and the sale earlier in the year of the Country's four distribution utilities was annulled on the basis that the process was illegal (it was alleged that members of the ex-President's family were the new owners).
Since joining the ADB in 1994, the Kyrgyz Republic has received loans worth USD 603.5 million (5% in the Energy sector) and Asian Development Fund (ADF) grants worth USD 66.1 million; and technical assistance (TA) grants worth USD 39.7 million.
2.2 Power Sector The Kyrgyzstan power sector consists primarily of one generation company, one transmission company and four distribution companies. There are some smaller independent power producers as well as some small private distribution companies; however the key players comprise these six companies, coming under the jurisdiction of the Ministry of Energy.
2.2.1 Ministry of Energy The Ministry of Energy (MoE) is established4 as the state authority responsible for the electricity sector. MoE performs various functions, including: development and implementation of energy policy; coordination (vis-à- vis other sectors and State authorities) and control over the electricity sector; regulation per se of the electricity sector (including licensing and tariff regulation), and various support functions.
2.2.2 Sector Reforms and Issues Major reform of the power sector started in 1997, when the Government developed and adopted a programme of denationalisation and privatisation of the joint stock company «Kyrgyzenergo» according to which the company was to be separated based on its functions of generation, transmission, and distribution of electricity to end-users. By 2001, the Government completed a three-phase restructuring programme resulting in the creation of the following eight companies:
«Electric Power Stations» - a generating company «Chakan HPP» - a generating company consisting of several small HPPs « National Electrical Grid of Kyrgyzstan» - transmitting company on high-voltage lines «Severelektro» - a DisCo covering the Chui, Talas oblasts and the city of Bishkek «Vostokelektro» - a DisCo covering the Issyk-Kul and Naryn oblasts «Oshelektro» - a DisCo in the Osh oblast «Jalalabadelektro» - a DisCo in the Jalalabad oblast «Bishkekteploset» - provider of heat energy to consumers in Bishkek.
These companies were corporatised as Open Joint Stock Companies (OJSC), based on the Kyrgyz law, in their form of ownership so as to enable private investment. The current state‟s ownership of the stocks in these companies is 93.5% (the State Property Management Ministry owns 80.5% and the State Pension Fund 13%, the remaining 6.5% of their common stock freely float on the Kyrgyz Stock Exchange as well as the Central Asian Stock Exchange).
However, the reforms of the Government have not resulted in the expected improvements in the electricity sector. Due to the weak governance in the sector, an energy interest group emerged and became a powerful lobby group which directly influenced all levels of the previous Government in their own interest. This group controlled major electricity and cash flows. Meantime, the energy policy continues to pay little attention to costs. At the heart of the challenge is poor management and lack of transparency in the sector.
3 Kyrgyzstan has the reputation of being one of the world‟s most highly corrupt countries under the previous Government. In the 2009 Transparency International‟s Corruption Index (http://www.transparency.org/policy_research/surveys_indices/cpi/2009/ cpi_2009_table ), Kyrgyzstan ranked 162 out of 180 countries. 4 Pursuant to the Law on the Government Structure Nº 12 of 6 February 2007 and Decree of President Nº 96 of 16 March 2007. June 2010 Page 5 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
As a result, the system losses have been very high. In 2007, 5.9 terawatt-hours (TWh) out of 12.2 TWh supplied domestically was unaccounted for; i.e. a loss rate of 41%. Most losses are reported to be non- technical or commercial; this includes metering inaccuracy, electricity theft, meter tampering and metering data manipulation. This is rampant at all voltage levels (including transmission HV system) and the archaic manual system does not have the capability to trace such fraudulent conduct. With no data acquisition facilities, tariff meters at substations are read visually by the operator and recorded in log books; the operators then phone the readings at set times of the day or night to NEGK Head Office in Bishkek, where they are again manually recorded. Whilst errors are mostly due to human error, the procedure can obviously be manipulated and does not offer any degree of reliability or security. This lack of proper metering is one of the major obstacles for loss reduction and adequate commercial operation.
The quality of supply has suffered as well: frequent interruptions, scheduled disconnections of supply, unstable voltage (in Bishkek the voltage at peak hours in winter time sometimes drops down to 160 V from the nominal 220 V, at which point voltage-sensitive devices such as TV or computer fail to function).
The existing basic infrastructures and the management fail to meet the needs of the population and enterprises. Improper cash management, poor maintenance, delayed rehabilitation, and inefficient management negatively disrupt the provision of basic services.
Attempts to introduce corporate governance and to improve financial discipline have been not successful to date.
If these challenges are not further addressed, the country is expected to continue suffering from electricity shortages. This situation represents a serious impediment to business development and economic growth, and seriously affects the living conditions in an already financially difficult environment. Essential hindering factor that have negatively affected the reform process is the lack of public trust in Government decisions.
2.2.3 Electricity Production The main generating company is OJSC «Electric Power Plants», a consolidation of eight power stations with a total installed power capacity of 3,650 MW, including the cascade of the Toktogul hydroelectric power plants (HPP), Heat and Energy Plant (HEP) of Bishkek and Osh cities, At-Bashy HPP, and enterprises of HPPs under construction (Kambar-Ata 1, Kambar-Ata 2 and others). HPPs produce 95% of Kyrgyzstan‟s electricity, most of which are located around the Naryn River.
2.2.4 National Electrical Grid of Kyrgyzstan OJSC «National Electrical Grid of Kyrgyzstan» (NEGK) is a power transmission company with their Head Office in Bishkek. The organisation chart is shown in Figure 2. The main functions of NEGK include transmission of electricity through the national power grid to DisCos and large consumers, as well as operational and supervisory control over the national power grid, plus control over cross-border electricity flows. Kyrgyzstan, having vast majority of its power in hydro-stations, has been able to export excess electricity during summer to neighbouring countries.
NEGK operates out of six regional centres (PVES) in Chuy (includes Bishkek), Jalala-Bad, Osh, Issyk-Kul, Naryn and Talas. The national transmission grid comprises 500 kV, 220 kV and 110 kV networks (refer Table 1) and a total of 190 associated substations (refer Table 2). Appendix 3 lists all of NEGK substations by region.
NEGK‟s System Control and Central Dispatch Centre (refer Figure 3), located in Bishkek (ChuPVES), is responsible for 24/7 dispatch operation of all substations and transmission lines in Kyrgyzstan, plus it co- ordinates the six regional Control Centres.
2.2.5 Central Asian Power System The Kyrgyzstan 500 kV transmission network forms part of the Central Asian Power System (CAPS), along with Kazakhstan, Tajikistan, Turkmenistan and Uzbekistan. The five member countries of the Central Asian Power Council have power exchange agreements with each other for cross-border power trade. The CAPS grid is managed by Energia, the state-owned United Dispatch Centre organisation based in Tashkent, Uzbekistan. Energia regulates and monitors the inter-connected system, plus co-ordinates with the respective subsidiary national load dispatch centres in each of the member countries.
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Figure 2 Corporate Structure of NEGK
Table 1 NEGK Transmission Lines Region (PVES) 500 kV 220 kV 110 kV Total Chuy ChuPVES 176 854 637 1,667 Issyk-Kul IPVES - 154 849 1,003 Naryn NPVES - 149 932 1,081 Talas TPVES 134 81 290 505 Jalalabad JPVES 231 268 921 1,420 Osh OshPVES - 242 724 966 Total km 541 1,748 4,353 6,642
Figure 3 NEGK Central Dispatch Centre
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Table 2 NEGK Substations 500 kV 220 kV 110 kV Total Region (PVES) Nº MW Nº MW Nº MW Nº MW Chuy ChuPVES 1 1,529 5 1,105 45 1,587 51 4,221 Issyk-Kul IPVES 0 0 2 525 29 510 31 1,035 Naryn NPVES 0 0 1 250 16 257 17 507 Talas TPVES 1 300 1 125 12 185 14 610 Jalalabad JPVES 0 0 2 438 34 813 36 1,251 Osh OshPVES 0 0 3 500 38 806 41 1,306 Total 2 1,829 14 2,943 174 4,158 190 8,930
As noted in Section 5.0 - Communications, there are additional substations belonging to the Generators that connect directly into the national grid as well.
2.2.6 Electricity Distribution Companies In Kyrgyzstan there are four regionally based distribution companies (DisCos); their main features are shown in Table 3. The main development areas for the DisCos that the Government is currently facing are:
Reduction of electricity losses Improvement of quality and regularity of power supply Modernisation/reconstruction of the existing power lines and substations Improvement of metering and accounting of electric power in the grid.
Table 3 DisCo Features Nº of Nº of LV Lines 35 kV Lines Nº of DisCo Customers Employees km km Substations Severelektro 468,000 3,242 21,211 1,369 8,099 Oshelektro 326,000 2,101 1,345 1,275 4,543 Jalalabadelektro 187,000 1,514 9,756 975 1,343 Vostokelektro 173,000 1,708 12,991 1,045 4,613 Total 1,154,000 8,565 45,303 4,664 18,598
Severelektro is the largest DisCo and covers Bishkek and surrounding area (Chui and Talas regions) and distributes nearly half of the Country‟s electricity to its 468,000 consumers. Severelektro, like other DisCos, is a natural monopoly. Its subscribed capital is 454.5 million Som ($10.3 million). The company‟s major problems are: (i) weak and non-independent management; (ii) low paid staff with limited professional and innovative skills; and (iii) outdated infrastructure (electric distribution lines and substations).
There are also a number of scattered small distribution licensees throughout the country; each of these serve small groups of customers through simple networks. There is very little quantitative information available on these licensees; however it is understood that they only operate small networks at low voltage, 6 kV or sometimes 10 kV, and purchase electricity from the respective DisCos in which areas they operate.
A synergy of the problems described above has resulted in 47% loss in transmission and 20% of the receivables being written off in 2008. Moreover, in 2009 100% of their „unrecoverable‟ debt was written off based on a law adopted through the Parliament. The Ministry of Finance explained that this 2009 write-off was done in order to make the company attractive for investor at the time when Severelektro was in the process of privatisation. In reality, only the state subsidies and write-offs of the company‟s debt to the State has kept Severelektro afloat financially.
2.2.7 Privatisation of DisCos Following a bidding process last year for the privatisation of Severelektro, three bids were received by the Kyrgyz Government on 29 December 2009 from firms registered in Kyrgyzstan, Kazakhstan and Russia. The Ministry of State Property (MSP) officially announced on 05 February 2010 that the state shares of Severelektro were sold to Chakan GES, a Kyrgyz firm. According to MSP, Chakan GES were required to:
Invest not less than USD 64 million in the Company over the next ten years
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To repay its debt of 3.63 billion Som (USD 82 million) To improve financial and economic conditions of the company To provide a reliable supply of electricity Avoid unjustified shedding Use tariffs set by the Government.
According to MSP, Chakan GES has proposed an investment plan totalling USD 73.9 million. Payment by Chakan GES for the state owned shares of Severelektro (80.5% owned by the State Property Management Ministry) was reported as being USD 3 million.
The other three DisCos - Oshelektro (OE), Jalalabadelektro (JE), and Vostokelektro (VE) - were also put out to tender by MSP, however no definite outcome was concluded before the overthrow of the previous Government on 07 April 2010.
It was reported on 08 April that the new-Government had quickly annulled the sale of the Country's four distribution utilities on the basis that the process was illegal and non-transparent.
Nevertheless, the decision to exclude the distribution components from this TA, due to the privatisation of Severelektro and pending sale of the other three DisCo, was made by ADB and agreed with the Government in February 2010.
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3.0 Wholesale Metering
3.1 Existing Situation 3.1.1 Existing Metering Interfaces Under the original system in the Soviet era, there was only one State Power Company “Kyrgyzenergo” which was responsible for all generation, transmission and distribution. However, once Kyrgyzenergo was unbundled into separate generation, transmission and distribution companies as outlined in Section 2.0, the commercial arrangements necessitated metering between every interface between the respective companies. Figure 4 shows the power flow (direction and respective voltages) between the various entities, together with the existing wholesale metering points.
Figure 4 Power Flow between Entities
6 kV, EPPs Small Hydro 10 kV, Existing 35 kV Wholesale Metering Points 110 kV, in KGZ 6 kV, 10 kV, 220 kV, 10 kV 6 kV, 500 kV 35 kV 10 kV, 35 kV 6 kV, 10 kV, 35 kV, 220 kV, 500 kV CAPS LICs NEGK Export - Import 110 kV, 220 kV 6 kV, 10 kV, 35 kV
6 kV, 10 kV, 35 kV
DisCos
LV 6 kV, 10 kV, 35 kV
Customers
LIC = Large Industrial Customers; EPP = Electric Power Plant; CAPS = Central Asian Power System; DisCos = Distribution Companies
In summary, wholesale meters have been installed at the following interfaces:
At every point where generation is connected to the NEGK transmission network (installed at the NEGK substation, plus duplicate metering on the outgoing feeder at the respective generating company‟s substation - usually 220 kV or 110 kV; sometimes at a lower voltage at the smaller generating stations) Appendix 4 lists the interconnection of generation with NEGK substations At every point where the respective DisCo takes supply from the NEGK transmission network (installed at the NEGK substation, usually one on each outgoing 10 kV or 6 kV feeder) Appendix 5 lists the interconnection of DisCos with NEGK substations At every cross-border supply point where power is exported/imported from/to Kyrgyzstan (installed at the nearest NEGK substation). Appendix 6 lists all the international transmission lines; Table 4 gives the quantity of existing meters at each voltage level At every point (refer Table 5) where large industrial customers (LICs) take high voltage supply from the NEGK transmission network (installed at the NEGK substation). LICs are specific industries that take supply at special tariff from either NEGK or EPPs (but not from DisCos).
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Table 4 NEGK Cross-Border Wholesale Meters Voltage Level Nº of Meters 500-220 kV 24 110 kV 18 35 k V 7 6/10 kV 17 Total 66
Table 5 Large Industrial Customer Substations Region (PVES) Nº Substation Chuy ChuPVES 3 Asanbay, Dordoy, Bistrovskaya Hydro Power Station Issyk-Kul IPVES 2 Kumtor, Enilchek Naryn NPVES 1 Makmal Talas TPVES 0 Jalala-Bad JPVES 4 Kambar-Ata, PDH, Sargata, Stroitelnaya Osh OshPVES 0 Total 10
NEGK‟s metering interfaces were accomplished as best as possible under the limited financial resources available, but do not meet the needs of the current operations, especially as the system relies on manual reading and data recording.
3.1.2 Existing Meter Technology The existing wholesale meters are a mixture of old and new technology, mostly sourced from Soviet manufacturers.
The older meters are of the conventional electromechanical induction watt-hour design (refer Figure 5) with a rotating disc, the speed of which is determined by the current flowing through coils inside the meter. The rotating disc drives a series of dials which count the disc revolutions to measure the energy usage. It consumes a small amount of power, typically around 2 watts. Although generally “sealed” with lead discs, these old meters are very easy to tamper with using external magnets or other clever but illegal devices; or they can be easily by-passed. Their accuracy is low, generally in the range 1 % to 5%. Their accuracy also declines with age. These meters are relatively cheap and easy to mass produce and are more commonly used to meter household consumption.
Figure 5 Typical NEGK Electromechanical Induction Watt-Hour Meters
In recent years, NEGK has installed digital wholesale meters (refer Figure 6). These include a variety of solid state meters (i.e. there are no moving parts) with programmable facility for recording an extensive range of data over specific periods of time. These meters record four-quadrant reactive and active power for both export and import (i.e. bi-directional), maximum power values, power-quality parameters, with either current transformer and voltage transformer connection (essential for metering of transmission circuits) or direct voltage connection. Internal memory will record all parameters over selectable integration times, as well as
June 2010 Page 11 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report maintain event and status logs, power-quality logs, and logs if power thresholds are exceeded. Appendix 7 lists manufacturer‟s details for some of the digital meters used by NEGK. The accuracy of digital meters is in the range 0.1% to 0.5%, and unlike induction meters this is does not deteriorate over time. Meter losses are also infinitesimal compared with induction type.
Figure 6 Typical NEGK Digital Wholesale Meters
Optical Connection
The digital electricity meters provide the possibility to programme, reprogramme, control and read parameters and data through an optical port or through standard communication interfaces. The latter will provide the necessary connection for automatic data acquisition as part of a SCADA system. The optical interface can be used to manually download the stored data to a laptop.
So far, NEGK have not been able to utilise the data acquisition facilities of these digital meters, primarily due to the existing communications network not having the capability to transfer the data. A trial pilot project was tried at Glavnaya 220 kV substation, where the data from the wholesale meters was collated through a local desktop computer and then sent via telemetry transducers to the Head Office for processing; however this was not successful and is no longer functional. The NEGK meter testing laboratory in Osh demonstrated the optical interface feature to the TA investigation team (refer Figure 7). It is noted that NEGK also has meter testing laboratories in Jalal-Abad as well as their main meter testing laboratory at NEGK Head Office. Optical interface devices were unavailable at any of the substations visited.
Figure 7 NEGK Digital Meter Testing
Data Screen Shot Meter Testing
Optical Connection to Laptop
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3.1.3 Existing Meter Quantities A summary of all NEGK‟s installed meter types and quantities at the different voltage levels is shown in Table 6. The specific features of each of these meters and the differences between types of meters was not immediately clear to the TA investigation team as the manuals are all in Russian language, as are the manufacturers‟ web sites. NEGK confirm that only the type СЭТ4ТМ and ЕА meters highlighted in Table 6 (total quantity = 214 meters) are of sufficient technical capability for the new wholesale metering requirements discussed in Section 3.2.
Table 6 Existing NEGK Wholesale Meters Types of Utility Own 500 kV 220 kV 110 kV 35 kV 10 kV 6 kV Total Meter needs Needs СЭТ4ТМ 6 56 108 20 190 ЕА 1 3 20 24 АМС 6 50 72 5 7 140 STQ220 5 3 8 ЦЭ6823 9 33 1 1 44 Э704 46 264 1,156 553 70 197 2,286 Э701 37 37 Э703 33 33 Promt 11 11 ELA7 9 15 24 A1800 6 2 2 10 A12E 4 4 Individual 25 22 47 Total 6 67 243 398 1,199 561 165 219 2,858 Source: NEGK Metrological Department.
3.1.4 Existing CTs and VTs Wholesale meters used to measure energy on the transmission system measure the voltage and current using voltage transformers (VTs) and current transformers (CTs), since it is impractical to put large currents and high voltages directly through the meter. The CTs and VTs are located in the high voltage switchyards and transform the voltages into nominal 110 V and currents into maximum of 1 A or 5 A, using standard ratios. These CTs and VTs usually have multi-windings, each with different characteristics, used for circuit protection and indication as well as for metering. The meter is calibrated using the known input CT and VT ratios, so that the recorded values at the meter reflect the actual primary circuit values. The CTs and VTs also have an accuracy rating, usually in the range of 0.1 % to 0.2 %. The total accuracy in the metering system is effectively the sum of the CT, VT and meter accuracies.
The majority of NEGK CTs and VTs are quite old and the accuracies are unknown. Figure 8 illustrates examples of old name plates on CTs and VTs at NEGK substations with minimal technical data shown. Nowadays, international standards such as IEC require that all technical information is recorded on the CT and VT nameplates; however the nameplates on the old soviet manufactured equipment lack such detail. In 2004. NEGK carried out a series of calibration tests on their 35 kV, 10 kV and 6 kV CTs and VTs. The results are shown in Table 7 and indicate that a significant number needed to be replaced. NEGK do not have the specialised injection equipment needed to test in situ the accuracy of their 110 kV, 220 kV and 500 kV CTs and VTs. This is further discussed in Section 3.3.4.
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Figure 8 Old CT and VT Name Plates
Table 7 NEGK CT & VT Testing Results Voltage Nº Tested Nº Defective % Defective 35 kV CTs 873 15 1.72 % 10 kV & 6 kV CTs 962 106 11.02 % 35 kV VTs 529 27 5.10 % 10 kV VTs 206 34 16.50 % 6 kV VTs 78 25 32.05 % Source: NEGK Metrological Department.
3.1.5 Existing Metering Practice All wholesale meters are read 12-hourly at every NEGK substation; each operator records the kWh readings manually in the substation logbook and then at pre-arranged times telephones all the readings to either their local NEGK Regional Control Centre or in some cases direct to the NEGK Central Dispatch Centre in Bishkek. At the receiving end in the Regional Control Centre, the readings are again transcribed manually into a wholesale metering register, for onward relaying to the Central Dispatch Centre. There each reading is manually keyed into a spreadsheet on a desktop computer and processed for billing as well as for calculation of losses. The overall process is cumbersome and inherently unreliable, particularly through natural human error. The process does not provide for dual entry of data or other similar quality checks. To some extent, it is a credit to all of the substation operators and Head Office staff that they can continue to operate and manage such an archaic system under such trying conditions. However, due to the inherent nature of the process, it would not be difficult to manipulate some of the reading for fraudulent purposes if so inclined.
3.1.6 Need for Change In summary of the above, the existing wholesale metering system and processes have the following disadvantages:
Manual system and inherently unreliable Lack of accuracy Lack of overall transparency Older metering equipment is outdated with unknown accuracy Recently installed metering equipment has data acquisition capability, but for technical reasons this feature cannot be implemented Associated communications system is also outdated and lacks data transfer capability.
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Clearly, there is a need to upgrade and automate the existing wholesale metering system to overcome these shortcomings and introduce a modern and reliable system fully transparent to all stakeholders.
3.2 Wholesale Metering Concept Design 3.2.1 Wholesale Metering Objectives The objective of the Wholesale Metering component of the Project is to provide a modern and accurate wholesale metering system capable of automatically recording all technical aspects of the transmission energy flow at all interfaces between NEGK and the generating stations, the respective DisCos, large customers, as well as at all cross-border connection points. Such Wholesale Metering is to be completely transparent and free of all human intervention. Introduction of automated wholesale metering is expected to restore confidence in the commercial operation of the power sector and lead to improved loss reduction.
3.2.2 Proposed Meter Technology The proposed wholesale metering will utilise two types of modern solid state meters with programmable facility for recording four-quadrant reactive and active power for export and import, maximum power values and power-quality parameters. A typical meter is shown in Figure 9. The proposed meters will be specified to include the following standard features:
High-accuracy four-quadrant energy metering in accordance with IEC 62053-225 Minimum Class 0,2 accuracy (Meter Type A) for system metering and Class 0,5 accuracy (Meter Type B) for feeder metering Real, bidirectional, reactive, and apparent values Fully programmable integrating periods (typically 1, 5, 10, 15, 30, 60 minutes) Volts and Amps demand, minimum/maximum; cumulative demand; demand on any instantaneous measurement Block, rolling block, and predicted demand calculations such as kW, kVAr and kVA demand, minimum/maximum Power quality compliance monitoring for international quality-of-supply standards such as power frequency, magnitude of supply voltage, flicker, supply voltage sags and swells, transients and voltage interruptions Harmonics: individual harmonics and total harmonics distortion Disturbance direction detection: analysis of disturbance information and recording with timestamp in an event log Type A wholesale meters will have two ports to provide for both automated metering and SCADA data acquisition; Type B wholesale meters will have only one port for automated metering data acquisition only.
Figure 9 Typical Modern Four-Quadrant Energy Meter
5 Electricity metering equipment (a.c.) - Particular Requirements - Part 22: Static meters for active energy (classes 0,2 S and 0,5 S). June 2010 Page 15 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
NEGK‟s existing type СЭТ4ТМ and EA meters (refer Table 6) already have the key elements of the Type B above and therefore can be reused by rewiring and reconfiguring for Type B automated metering data collection.
3.2.3 Interfaces The proposed new wholesale metering will measure the energy flow at the following NEGK interfaces:
At every point where generation is connected to the NEGK transmission network (installed at the NEGK substation, plus duplicate metering on the outgoing feeder at the respective generating company‟s substation) At every point where the respective DisCo takes supply from the NEGK transmission network (installed at the NEGK substation) At every cross-border supply point where power is exported/imported from/to Kyrgyzstan (installed at the nearest NEGK substation, plus at Disco substations on their export feeders) At every point where large customers take supply from the NEGK transmission network (installed at the NEGK substation).
Figure 10 New Wholesale Metering between Entities
EPPs Small Hydro 6 kV, Existing 10 kV, M Wholesale 35 kV Metering Points 110 kV, in KGZ 6 kV, 10 kV, 220 kV, 10 kV 6 kV, 500 kV 35 kV 10 kV, 35 kV 6 kV, 10 kV, 35 kV, 220 kV, M 500 kV CAPS LICs M NEGK M Export - Import 110 kV, 220 kV M 6 kV, 10 kV, 35 kV M 6 kV, 10 kV, 35 kV
New Wholesale Meters DisCos M
LV 6 kV, 10 kV, 35 kV
Customers
3.2.4 Proposed Metering Practice Unlike the existing manual system, the proposed wholesale metering system will be fully automated with data acquisition.
Figure 11 shows the proposed new wholesale meter arrangements at each NEGK substation. In the left diagram the substation supplies a single customer in which case only Type A wholesale meter (Meter S1) is used to reconcile all energy flowing to the DisCo. Type B meters F1 to F4 measure individual energy flows for each outgoing feeder and are used for billing. The right diagram shows a substation which supplies two customers; in this case Type B meters F1 to F4 and LIC1 measure the respective feeder energy flows and are used for billing to both customers. Type A meter S1 is again used to reconcile total energy flowing through the transformer secondary.
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At each NEGK substation (total of 190 - refer Table 2) and the EPP substations (total 9 - refer Appendix 3), all wholesale meters, both Type A and Type B, will be connected to a Substation Metering Aggregator (or summation data logger) which will collate all inputs and provide the necessary interface to enable automated data acquisition through the SCADA system (if available) or through GSM GPRS connections (refer Section 6.3). Metering data from each substation will be received by a remote host computer to be installed at the National Control Centre in Bishkek.
There, all metering information will be integrated and collated to provide the necessary administrative and commercial revenue reports showing energy transferred between the respective companies and NEGK. Reports can be configured to show a combination of technical and commercial information in tabular and graphical formats. The outputs can also be prepared on a regional basis to meet the requirements of NEGK‟s six regional centres. The information can be disseminated through local and/or wide area networks to each and all of the stakeholders.
The whole process will be designed to be totally automated, fully transparent and not open to interference or manipulation.
Figure 11 Substation Metering Configurations
Substation Supplying DisCo Substation Supplying DisCo plus Large Industrial Customer HV HV Type A System Meter Class 0.2
Type B Feeder MV MV Meter Class 0.5
DisCo 1 Energy DisCo 1 Energy = Meter S1 Meter S1 = Meters S1-LIC1 LIC 1 Energy = Meters F1+F2+F3+F4 Meter S1 = Meters F1+F2+F3+F4 = Meter LIC1
Meter Meter F1 Meter F2 Meter F3 Meter F4 Meter F1 Meter F2 Meter F3 Meter F4 LIC1
Feeder 1 Feeder 2 Feeder 3 Feeder 4 Feeder 1 Feeder 2 Feeder 3 Feeder 4 Feeder 10
To LIC 1
To DisCo 1 To DisCo 1
3.2.5 Automated Data Acquisition Details of the metering data acquisition by GSM GPRS are given in Section 5.2.4.
3.3 Wholesale Metering Scope and Cost Estimate 3.3.1 Scope of Wholesale Metering Component The scope of the proposed wholesale metering component will provide for the following elements:
Complete supply, delivery, installation and configuration of all new wholesale meters and substation metering aggregators, including panels, wiring and miscellaneous equipment Complete supply, delivery, installation and programming of a main and back-up host computer system at NEGK‟s National Control Centre and a separate back-up location Complete supply, delivery, installation and programming of client metering computers in the regional centres Connection of 190 NEGK and 9 EPP substations by GSM GPRS for automated data acquisition Retro-fitting and connection of all suitable existing digital wholesale meters
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Training of NEGK technical and commercial staff in all aspects Technical support for 12 months after commissioning. Complete supply and delivery of new replacement CTs and VTs in selected substations (installation will be by NEGK) Supply and delivery of a metering high voltage test vehicle, testing benches and calibration meters
3.3.2 Estimated Quantities of Wholesale Meters, Summation and Host Equipment The estimated quantities of Type A Class 0.2 and Type B Class 0.5 wholesale meters are shown in Table 8.
Table 8 Estimated Quantities of Wholesale Meters Metering Point Type A Class 0.2 Type B Class 0.5 1 NEGK Generation (refer Appendix 4) 34 0 2 NEGK Substations - Every Feeder 0 1,818 3 Re-use of Meters (refer Table 6) 0 -214 4 Transmission lines 110-500 kV and inputs 35, 10, 6 kV* 647 0 5 HV Cross-Border Supply (refer Table 4) 46 0 Subtotal 727 1,604 Contingency ~10%, 20% 72 396 Total (rounded) 800 2,000 * Includes Large Customers (refer Table 5)
A total of 200 (190 NEGK, 9 EPP and 1 spare) Substation Metering Aggregators are required, plus panels, wiring and miscellaneous equipment. Quantities are based on one unit per substation plus one spare.
Two sets of Host Wholesale Metering Computer are required as main and back-up units. Each set will comprise computer, software, UPS power supplies, security software and the like. It is envisaged that the main Host Wholesale Metering Computer will be located at the NEGK NCC and the back-up at a separate physical location such as the ChuPVES Control Centre. In addition, six sets of Client Metering Computers will be provided in each of the Regional Centres to allow viewing of their respective wholesale metering data. These regional centres can be connected to the host computer using public internet facilities with appropriate security such as a VPN (Virtual Private Network) tunnel.
3.3.3 Replacement CTs and VTs As noted in Section 3.1.4, the accuracy of a significant number of CTs and VTs is in doubt. NEGK have identified specific locations where the CTs and VTs need immediate replacement to ensure the integrity of the metering. Three phase quantities are summarised in Table 9. In addition, it is noted that there are also quantities of CTs needed to complement the circuit breaker replacement as further discussed in Section 4.2.
Table 9 Estimated Quantities of Replacement CTs and VTs Voltage Replacement CTs (set of 3) Replacement VTs (set of 3) 1 500 kV 3 3 2 220 kV 16 17 3 110 kV 3 3 4 35 kV 17 11 5 10 kV & 6 kV 39 20 Subtotal 78 54
3.3.4 Metering Accessories NEGK have identified the following accessories needed to support the new wholesale metering component:
i. HV CT & VT Mobile Testing Equipment: This will provide for in situ testing of NEGK's 110 kV, 220 kV and 500 kV CTs and VTs and includes specialised portable injection and measuring equipment mounted in a specially designed and equipped vehicle. Quantity of one unit ii. Testing Bench for new Wholesale Meters: This will facilitate the testing, calibration and programming of the new wholesale meters. Quantity of seven units for NEGK Head office and the six regional centres
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iii. Calibration Meters: These "standards" meters are used as reference meters when calibrating the wholesale meters. Quantity of seven units for NEGK Head office and the six regional centres.
The above equipment has been included in the proposed scope of materials to be procured in this ADB- financed project.
3.3.5 Estimated Costs of Wholesale Metering Component The estimated cost of the proposed wholesale metering component is shown in Table 10. Unit costs for the Type A and Type B wholesale meters are based on 2010 costs supplied by NEGK. Costs for the other items are based on expected 2010 international prices estimated by Aecom NZ.
Table 10 Estimated Cost of Wholesale Metering Component Item Quantity Rate (USD) Cost (USD k) Wholesale Meters Type A Class 0.2 800 1,000 800 Wholesale Meters Type B Class 0.5 2,000 350 700 Substation Metering Aggregator 200 3,000 600 Host Metering Computer & Software 2 250,000 500 Client Metering Computers in regional Centres 6 5,000 30 Metering Data Acquisition by GSM/GPRS 1 520,000 520 New CT and VT 1 - 2,365 HV CT&VT Mobile Testing Equipment 1 200,000 200 Testing Bench for New Wholesale Meters 7 50,000 350 Calibration Meters 7 10,000 70 Cabling and Panels 200 3,500 700 Total 6,835
3.4 Safeguards As all work associated with the Wholesale Metering component will be within the boundaries of existing NEGK substations, existing NEGK system control centres (in Bishkek and five regional areas) and other existing NEGK facilities, there will be no significant negative impacts on the environmental or local communities. Conversely, once the project is implemented, it is expected that the public will ultimately benefit from a more efficient and reliable power system, operated in a more transparent manner.
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4.0 Substation Upgrades
4.1 Existing Situation The majority of NEGK substations are of proven Russian design utilising old-technology equipment. Although many were constructed over 30 years ago, the equipment has generally been maintained and has performed well over the years as designed. However, in the interim, the system loads and associated fault capacities have increased due to various contributing factors such as new customers, increased loads, associated new generation and the like. This means equipment load and fault ratings may be nearing or exceeding their design capacities and design life.
In order to ensure ongoing reliability and safety of operation, some of the old major equipment needs to be progressively replaced with modern equipment. In fact NEGK have started such an asset replacement programme, but only have sufficient funds available for some limited quantities of replacement. To continue operation with this equipment could prejudice the system operation and in the worse scenario of equipment failure could endanger the safety of substation personnel.
The following major high voltage equipment needs to be included in the asset replacement programme:
Power transformers Circuit breakers Current transformers Voltage transformers.
Because of budget limitations, the Substation Upgrade component of this Project excludes power transformers, nor is there an identified immediate need for replacement VTs. However, it is noted that there are also quantities of CTs and VTs needed for metering accuracy as discussed in Section 3.3.3.
Figure 12 shows typical old bulk-oil circuit breakers. Some of these older Russian designs also included CTs in the same tank. This technology has now been superseded by gas-insulated (using SF6) switchgear which is much smaller physically and provides higher fault ratings and reliability.
Figure 12 Old 220 kV Circuit Breakers
4.2 Substation Upgrades Scope and Cost Estimate 4.2.1 Scope of Substation Upgrade Component The scope of the substation upgrade component is for the supply and delivery of circuit breakers and CTs at 500 kV, 220 kV, 110 kV, 35 kV and 10&6 kV at selected NEGK substations under ADB's ICB procedure. The equipment will be installed and commissioned by NEGK who are experienced in this type of substation work.
4.2.2 Technical Specifications Technical specifications of the circuit breakers and CTs will be determined during the preparation of bidding documents by the project implementation consultant. For circuit breakers, the circuit rating and fault capacity will need to be confirmed for each application at each substation.
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NEGK advise that their CTs are generally five core, covering protection, metering and indication. The exact ratios, accuracy class (this differs for each core) and burdens will need to be confirmed for each application at each substation. Appendix 8 lists the expected values for the metering CTs.
4.2.3 Estimated Quantities of Substation Upgrade Component NEGK have provided detailed lists of substations where circuit breakers and CTs need replacing because of the equipment is at the end of its useful life. This is summarised in Table 11 and full details are given in Appendix 8.
Table 11 Estimated Quantities of Substation Replacement CBs, CTs and VTs Replacement CBs Replacement CTs Voltage (set of 3) 1 500 kV 6 1 2 220 kV 29 18 3 110 kV 83 72 4 35 kV 0 0 5 10 kV & 6 kV 150 0 Subtotal 268 91
4.2.4 Estimated Costs of Substation Upgrade Component The estimated cost of the proposed substation upgrade component is shown in Table 12. Unit costs for the equipment are based on recent prices for similar equipment procured under ADB's ICB procedures. These costs are mostly marginally higher than unit prices provided by NEGK, which are based on their procurement of Russian sourced equipment. It is noted that Russia is not a member country of ADB and therefore is ineligible to participate in the proposed Project procurement.
Table 12 Estimated Cost of Substation Upgrade Component Item Quantity Rate (USD k) Cost (USD k) Circuit Breakers 500 kV 6 500 3,000 220 kV 29 130 3,770 110 kV 83 50 4,150 10 kV & 6 kV 150 13 1,950 Subtotal 268 12,870 Current Transformers (set of 3) 500 kV 1 85 85 220 kV 18 30 540 110 kV 72 15 2,160 Subtotal 91 2,785 Total 15,655
4.3 Safeguards As all work associated with the Substation Upgrades component will be within the boundaries of existing NEGK substations. The only potential risk is that some of the old bulk-oil circuit breakers may possibly contain PCBs (Polychlorinated biphenyls6) in which case proper handling and disposal of the oil would need to be undertaken in accordance with international guidelines on the disposal of PCBs.
Otherwise, there will be no significant negative impacts on the environmental or local communities. Conversely, once the project is implemented, it is expected that the public will ultimately benefit from a more efficient and reliable power system, operated in a more transparent manner.
6 Polychlorinated biphenyls (PCBs) are a group of man-made compounds that were widely used in the past, mainly in electrical equipment. The commercial production of PCBs started in 1929 but their use has been banned or severely restricted in many countries since the 1970s and 80s because of the possible risks to human health and the environment. Because these compounds are generally very stable, they are very difficult to dispose of and remain present in the environment today.
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5.0 Communications
5.1 Existing Communications Systems 5.1.1 Backbone Communications Equipment NEGK primarily uses Power Line Carrier Communications (PLCC), point-to-point radio links, commercial telecommunication company data links and the Public Switched Telephone Network (PTSN) for their voice and data communications needs. The Global System for Mobile Communications (GSM) network has also been used on a trial basis to transmit intermittent data.
From visits to four control centres and six substations it was observed that the communications equipment is mostly old obsolete gear from Russia and other former eastern block countries. Some of the equipment is in poor working order or is not functioning at all. A bad quality, barely audible, voice connection via PLCC was demonstrated at one substation. Some more modern digital PLCC, voice switch and multiplex equipment has been or is being installed at control centres. New Russian multiplex equipment was observed at the main NEGK communications section in Bishkek. It is first received as racks then assembled and configured by NEGK engineers, then installed at other sites.
PLCC is used extensively throughout the NEGK network for voice and data communications, and for protection signalling. The photos below illustrate some of the different vintages of PLCC equipment. In the switchyards, most lines incorporate line traps and VT or CVT PLCC connections. This switchyard hardware does not date like the indoor PLCC equipment so is generally reusable when the electronic racks are updated.
Figure 13 Old PLCC Equipment Figure 14 More Modern PLCC Equipment Figure 15 Line Traps
Some “radio relay” equipment is used for point-to-point links between substations and from substations to the nearest Regional Control Centre (RCC). It operates in the UHF band and is circularly polarised (see antenna in Figure 17 and Figure 18). Note circular polarisation is more resistant to signal degradation caused by multi-path reflections, inclement weather conditions or minor obstructions such as foliage.
5.1.2 Telephone System NEGK have their own network of private telephone exchanges in control centres and in major substations. Smaller substations just have a telephone extension from an area switch. The telephone voice and signalling channels are for the most part carried over the PLCC network, with some use of Kyrgyzstan Telecom landlines. Cell phones are also used as a backup for voice communications.
As described above, most of the telephone equipment is obsolete; however some new Private Automatic Branch Exchange (PABX) equipment is being installed. NEGK presently have a project under way to upgrade the telephone systems at the National Control Centre (NCC), some regional centres and at major substations. MiniCom DX-500 equipment from Informtekhnika of Russia is being used.
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Figure 16 New Multiplexer Figure 17 Radio Relay and Figure 18 Radio Relay Antenna (one broken) Cell Phone Antennae
Figure 19 Old PABX Equipment Figure 20 Telephone Console
5.1.3 Data Communication For the most part the data communications (telemetry) channels are narrow band and are slow (600/1200 baud or less). Data is transported over PLCC channels, radio relay and some leased data circuits.
At most substations the energy meter counts are manually read once per day and the readings phoned in to the nearest regional control centre. Use of the GSM cellular network to transmit metering counts has been tried out with limited success.
5.2 New Communications Systems 5.2.1 General The ultimate goal is to provide NEGK with a modern reliable communications system connecting all substations and the national and regional control centres. This would be best achieved by fitting Optical Ground Wire (OPGW) on transmission lines in place of the normal ground wire (or adding OPGW where ground wires are not fitted).
Fibre optic cable is well suited for the power communications over transmission lines. It is robust, reliable and immune to fading. The optical fibres in an OPGW are protected by the outer aluminium clad steel strands of the cable. These serve the purpose of earth wires and carry earth fault current as well as helping disperse lightning strike energy.
Approximately 5,500 km of OPGW would be required to connect all sites, however because OPGW costs approximately USD 10,000/km (installed), there are insufficient funds to connect all sites at this stage.
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Instead, six of the major substations and two control centres will be connected under the proposed ADB funded project. This will form the basis for future expansion of the fibre network. At present there is only one North-South link via the 110 kV line from Jetigen to Rayonnaya (ignoring links through neighbouring countries). The inclusion of OPGW on the new North-South Datka-Kemin 500 kV transmission line will remedy this deficiency and provide the necessary diverse North-South communications route.
As metering data still needs to be collected from all substations, a low cost system using the General Packet Radio Service (GPRS) on the GSM cellular network is proposed (refer to Section 5.2.4). Although this is a low cost system to implement there will be ongoing rental and data charges.
5.2.2 Backbone Fibre Network It is proposed that a fibre optic network be installed linking the following sites:
OPGW on 220 kV (499 km) Frunzenskaya - Kara-Balta - Glavnaya - Chuyskaya - Bistrovka - Ala-Archa - Frunzenskaya
OPGW on 110 kV (8.5 km) Glavnaya - Karagachevaya
ADSS on 35 kV Distribution Line (10 km) Kara-Balta - National Emergency Communications Centre
Underground Fibre Cable (42 km) Karagachevaya - NCC - Ala-Archa Glavnaya - ChuPVES RCC - NCC
The fibre optic network is shown on diagram “Initial Fibre Optic Network” in Appendix 9. The list of transmission lines is also scheduled in Appendix 10 along with the proposed fibre connections. Note that the 110 kV Karagachevaya substation has been included above as it provides a convenient site close to the NEGK offices to allow NCC to be connected to the network by underground fibre cable. Appendix 11 shows the transmission network in simplified format.
The majority of the fibre network will be built by replacing the earth wire that is strung on top of tower transmission lines with OPGW. If ground wire is not presently fitted it is likely that the towers will be of standard types that are designed to support ground wire so OPGW should be able to be installed without modifications to the tower. The implementation consultant will need to complete line surveys and confirm the arrangements and spacing of all towers. They will also have to carry out structural calculations to confirm each tower type can support any additional load when OPGW is installed. (OPGW is usually slightly larger and heavier than the earth wire it replaces.)
If there is a reason that OPGW cannot be installed over a particular section then the fibre can be strung as a separate “All Dielectric Self-Supporting” (ADSS) cable. ADSS will be used on an MV 35 kV distribution line to link the emergency communications centre. See the photos below showing ADSS on MV lines.
Underground fibre optic cable will be installed in Bishkek to connect the NCC and the ChuPVES RCC to nearby substations (refer to Appendix 9). For diversity, each is linked to the rest of the network via two routes. It is understood that for the majority of the 42 km length of underground fibre the cable can be pulled through existing ducts however some new conduit will need to be installed by trenching or by directional drilling.
Single mode (SM) fibres will be specified that are suitable for both 1310 nm and 1550 nm wavelength light. A minimum of 24 fibres is recommended for all connections with a consideration that more fibres be installed in areas (such as Bishkek) where there may be a demand from other companies wanting to lease dark fibre. The exact type of fibre will need to be determined during the detailed design, however fibre to the G.652.C or G.652.D standard is suggested rather than G.655.
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Figure 21 Workers Replacing Earth Wire with OPGW Figure 22 ADSS on MV line
5.2.3 Fibre Communications Transport Mechanism The common communications transport mechanism for large fibre networks is Synchronous Digital Hierarchy (SDH) - Synchronous Transport Module level 1 (STM-1). This is a multiplexed system operating at 155 Mbps. Sometimes STM-4 (622 Mbps) is used as a high speed backbone on central loops, with STM-1 on the outer loops. It is proposed that an SDH, STM-1, communications backbone be established connecting the ten sites that are linked by fibre optic cable. In future when more fibre is added to the network, this central loop should be upgraded to STM-4.
The SDH network is usually configured in a series of rings which have self healing properties if there is a communications fault. SDH acts as a “transport container” for underlying protocols such as E1 voice channels and Ethernet. The network will ultimately provide for transmission of the following:
Metering data Supervisory Control and Data Acquisition (SCADA) data (CB statuses, alarms, analogue values etc.) Engineering data (device configurations, fault data etc.) Voice (administrative, operational and hotline telephone networks) Protection signalling Linking of mobile radio base stations (if required).
Some utility companies in developed countries are now installing layer 2 or layer 3 routed wide area Internet Protocol (IP) networks in place of SDH multiplexed systems. These are being deployed using the Multi Protocol Label Switching (MPLS) data carrying mechanism. They provide more flexibility and scalability for the plethora of communications services being implemented by these utility businesses. In particular some of the “Smart Grid” initiatives that are being explored by utilities propose two-way communications down to an individual consumer level and these require a complex and scalable communications network. It is considered that the added complexity and cost of MPLS is not justified for the Kyrgyzstan transmission communications network at this stage, and that the established and widely used SDH mechanism is a better choice.
The SDH network will be monitored by a dedicated Network Management System (NMS) at the NCC, with a backup NMS at a standby master station at the ChuPVES RCC.
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5.2.4 Metering Data Acquisition Communications NEGK still need a nationwide communications network so that the wholesale metering data can be automatically and securely transmitted to the processing facility at NCC in Bishkek (the Metering Host Computer - MHC). Use of GPRS over the GSM network is proposed as the most cost effective solution to connect the remaining approximately 200 substations and power stations.
Metering data will be collected by a metering aggregator at each substation. This aggregator will be connected to a GPRS modem and will transmit metering data when requested by the MHC. The MHC will poll each substation aggregator in turn approximately once each half hour.
Communications Architecture An arrangement as shown below is proposed as this is commonly provided by GSM operators in other countries.
Figure 23 GPRS Network Arrangement
Enterprise Access GGSN Metering Router Router System VPN MHC
NEGK Cellular Provider GPRS Interface
GPRS Modems in 200 substations throughout Kyrgyzstan
APN
The metering system interfaces with the Gateway GPRS Support Node (GGSN) via routers and a VPN. End- to-end communications for the metering system operates as a private IP network.
Technical discussions were held with the Kyrgyzstan mobile telephone company Beeline (Bitel) and it was concluded that such an arrangement would be possible. A somewhat similar arrangement has been implemented for another client.
Beeline claim to have the widest cell phone coverage of the operators in Kyrgyzstan; however it is likely that a small number of substations would be outside their coverage area. It was suggested that coverage around Batken may be doubtful. Beeline will advise further on this.
Data Requirements The substation numbers and data requirements are estimated as follows. It is assumed that the GPRS provides a data rate of at least 9600 baud.
Number of GPRS modems: 200 Average poll message length: 50 bytes (~50 mSec) Average data response message length: 400 bytes (~400 mSec)
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Bytes per complete poll (200 sites): 85k Bytes per day (48 polls): 4M
Backup Communications If there is no cell phone coverage at a few sites then other communication methods will need to be implemented to collect metering data. This includes use of digital microwave radio links, use of existing PLCC data links or installation of new PLCC. An allowance has been made for five microwave radio links and one PLCC link. The ultimate solution, which is also a backup if communications to any other site fails, is to plug a laptop computer into the metering aggregator and download the data.
Reliability and Security A key disadvantage of using the GSM/GPRS cellular network is that this is not owned by or under the control of NEGK and is likely to fail or be turned off in crisis and disaster situations. For this reason it will be important in the future for the fibre network to be extended to all or almost all sites. This also will unlock further benefits for example by allowing implementation of a full SCADA system.
Security of data transfer will be of key importance to ensure the data cannot be manipulated. The GSM/ GPRS network does encrypt transmissions but the earlier weaker GSM encryption code has been broken forcing companies to upgrade to more secure algorithms. The situation with the Kyrgyz mobile networks is not known but anyway it is essential that the metering data acquisition system add its own layer of security which should conform to international standards. This security should apply to all data transport methods including saving files on a laptop.
5.2.5 Telephone System No allowance has been made for a new telephone system. NEGK already have funds for some telephone equipment and have purchased and installed some modern Russian digital PABX equipment at some of the 10 sites in the proposed fibre communications loop and they will complete this work themselves. They prefer this approach for reasons of compatibility and support.
5.2.6 Power Supplies New DC and UPS supplies are allowed for at the major interconnected sites. They will support the new metering as well as the new communications equipment.
5.3 Fibre Network Performance The fibre based communications system will be designed with a high level of redundancy. The technical and performance requirements of the equipment will be based on ITU-T recommendations with availability of 99.999% or better being required.
5.4 Communications System Upgrade Advantages When completed, a national communications network based on fibre optic cable will provide a high bandwidth network linking all or most NEGK facilities and it will be owned and managed by NEGK. Not only will this facilitate a vast improvement in the transmission network monitoring and control capabilities (see Section 6.4) but it will also allow more efficient business processes to be applied by the company nationwide.
For example data and business applications that could be supported on a company WAN include access to drawing and documentation on-line, access to historical data for planning and maintenance purposes, reference documents such as company policies and procedures, maintenance and outage schedules, news announcements and other staff information services and financial information.
A further advantage of installing fibre nationwide is that spare cores (dark fibres) can be leased to telecommunications companies for their use. This will particularly apply when other cities or large towns are connected by the fibre network.
In the interim the main advantage provided by the stage 1 fibre based communications network will be to facilitate real time monitoring of electrical parameters at the major substations in the North which carry the majority of the Nation‟s electricity.
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When the new North-South 500 kV transmission line and the Datka and Kemin substations are completed it is assumed that the communications and monitoring systems provided for them will be integrated with the systems provided under this TA. This should provide real time monitoring of the new 500 kV line and substations from NCC.
5.5 Communications System Scope of Work and Costs 5.5.1 Scope of Work - Communications The scope of the proposed communications component will provide for the following elements:
Survey of substation sites and transmission line routes where fibre cable is to be fitted, Supply, delivery and installation of OPGW, ADSS and underground fibre optic cable and associated accessories, Integration, supply, delivery, installation and configuration of all fibre optic transmission and multiplex equipment, Supply, delivery installation and configuration of microwave radio links (as determined at the specification stage), Supply, delivery installation and configuration of PLCC equipment (as determined at the specification stage), Supply, delivery and installation of power supplies to support communications equipment, Supply, delivery, installation and configuration of associated IT equipment, Factory acceptance testing, Commissioning of all systems, Provision of tools, test equipment, spares, documentation, training, warranty support.
5.5.2 Costs The estimated cost of the proposed stage 1 communications component is shown in Table 13 below.
Table 13 Estimated Cost of Communications Component Item Cost (USD) Fibre Optic Cable (510 km OPGW, 10 km ADSS, 50 km underground FOC) 5,536,000 Multiplex Equipment 680,000 Microwave Radio and PLC 740,000 Power Supplies 110,000 Miscellaneous (site survey, configuration, project management, tools, test equipment, 610,000 documentation, warranty) Miscellaneous Equipment 1,909,000 Total (excluding contingencies) 9,585,000
5.6 Safeguards There will be a small impact on farmland where trucks will need to cross fields to access the strain towers for pulling/retrieving the OPGW/ earthwire. This is covered in a separate Safeguards Report.
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6.0 SCADA
6.1 Existing SCADA System 6.1.1 Control Centres Each Regional Control Centre (RCC) monitors the transmission network and substations in their area (PVES), with the National Control Centre (NCC) coordinating each RCC and being responsible for overall network control, for dispatch of generation and for cross-border import/export of power.
Presently operators at the NCC have a poor view of the current state of their transmission network as most data is phoned in and manually entered only every 3 hours or more. Operators at the RCCs have even less visibility of network status and rely mostly on telephone updates.
The control centres have large tile mimics that display network status. The NCC mimic also has digital displays indicating bus voltages and some power flows. Figure 3 shows the National Control Centre mimic and Figure 24 a typical Regional Control Centre mimic.
Figure 24 ChuPVES Regional Control Room
Some status signals and analogue values are transmitted to NCC by slow speed telemetry (over a mixture of PLCC and Kyrgyzstan Telecom data circuits); however most data is collected by telephone. The “Telemetry Lady” (see Figure 25) phones substations and power stations (all manned) to obtain CB statuses and key measurements and enters data manually into the SCADA database. The update rate is about 1 “scan” every 3 hours.
Figure 25 Telemetry Lady Figure 26 SCADA Screens
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The interface between the telemetry circuits that are functional Figure 27 Interface Device and the SCADA PC is a locally made microcontroller based module shown in the photograph, Figure 27, to the right. Although an ingenious interface method, it does provide a single point of failure for the data collection.
Once in the database the statuses and values are displayed on the tile mimic and on PCs running locally-written SCADA software (see Figure 28 and Figure 29) below.
Figure 28 SCADA Screen, Load Curve Figure 29 SCADA Screen, Mimic Diagram
Generation (and spinning reserve) is dispatched by phoning power stations. Circuit breaker control is also carried out by the control room operator telephoning substation operators and getting them to initiate controls locally.
6.1.2 Substations There appeared to be no modern Remote Terminal Units (RTUs) at any of the substations visited. RTUs are required in a SCADA system to provide an interface to the substation equipment for control and indication. Some transducers that provide voltage and power measurements were noted and there were some multiplexing modules that encode CB statuses and send signals via the PLC equipment.
6.2 SCADA Upgrade 6.2.1 Overall Configuration It is proposed that a new modern SCADA system be established linking the seven substations and two control centres connected by fibre optic cable as described in Section 5.2.2. This will form the basis of a future nationwide SCADA system.
The primary SCADA master station will be installed at the NCC in Bishkek with a backup (disaster recovery) master station at ChuPVES RCC. The ChuPVES RCC will also use the SCADA to assist with regional monitoring duties.
As shown in Figure 30 and Figure 31, the metering system will also extract realtime measurements from the system meters (Type A) via a separate serial port. For fibre connected substations this data will be passed back to the SCADA master station in real time. For GPRS connected substations, only periodic readings will be sent to the master station. These may be the instantaneous value at the time of a poll and/or an average value for the previous half hour.
In the ultimate SCADA configuration NCC will coordinate all power generation, import/export of power and overall transmission grid configuration while each of the six RCCs, which will also then have a SCADA master station, will monitor and control activities in their regions.
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As all control centres will potentially have access to all data, a policy on responsibilities of each level of control (NCC and RCC) will need to be established.
6.2.2 Building Considerations Both the NCC and Chu RCC together with their associated equipment rooms will be refurbished. This will include new fittings and furniture, new false floors, new air conditioning systems and new Uninterruptable Power Supplies (UPS). Consideration should be given to refurbishing the associated offices where support personnel are located; however this is not covered in the present budget. The EPC scope of work should provide for local architect and building services inputs.
As tiled mimics are expensive to install and difficult to modify and update as the network changes, it is recommended that the old tile mimic at NCC be removed and replaced with a “video wall” made up of a bank of large, narrow-bezel, LCD screens. At Chu PVES RCC there is an allowance for two 50 inch LCD or plasma screens to be mounted at a suitable distance in front of the operators‟ desks in place of the tile mimic.
The large screens would display an overview of the network or part of the network while PC screens on the operators‟ desks would display the operating details at a substation level.
6.2.3 SCADA Master Station Software The proposed SCADA System will provide information storage, retrieval and display facilities. A separate “data historian” server system will be provided which will store operational data for at least five years. It will allow users to access subsets of the stored data on request in a variety of different formats.
Operationally the SCADA system will:
Include a full graphic display system with a well-defined and consistent graphical user interface Display real time values on the screens from fibre connected substations Display delayed values from GPRS connected substations Automatically report abnormal conditions, alarms and uncommanded changes of state through a standardised alarm/event annunciation system Include facilities for event/alarm logging, reporting, trending, recording and screen copying.
6.2.4 LAN and Security Security of the communications and SCADA networks is now an important issue because of the threats of cyber terrorism. The National Institute of Standards and Technology (NIST), Computer Security Resource Centre, in USA publishes standards relating to securing critical infrastructure and these will be referred to when the system is specified.
In general the SCADA LAN is kept separate from the office LAN/WAN with any interconnection being made via a firewall. Only operations staff, SCADA servers and RTU communications are on the main SCADA LAN. All other authorised staff gain access to data via the firewall using a browser or other suitable client software.
The SCADA LAN, servers, UPSs and communications equipment are duplicated for reliability.
6.2.5 Energy Management System (EMS) Software The initial budget does not allow for purchase of any EMS software and as only six major substations will be connected it would not be of much use anyway. It is suggested that EMS software is purchased later when more of the network is connected.
The capability to add on EMS software in the future will be considered when specifying the SCADA software. Available EMS applications include:
Network topology analysis Load shedding and restoration management Automatic Generation Control (AGC) Water management for hydro stations
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Spinning reserve monitor Economic dispatch of generation Load forecasting (short and long term) Maintenance outage coordination Unit Commitment Load flow calculation System security analysis State estimation Energy accounting.
6.3 Substations Initially the SCADA system will collect network parameters (MW, MVAr, I, V, Hz, etc.) measured by the Type A system meters and the MHC will collect metering data (kWh, kVArh, etc.) from both Type A and Type B meters. Type A meters will have two separate data ports, one of which will provide metering data and the other SCADA data. The data link to the meters will most likely be a multi-drop RS485 serial connection although, depending on the meters supplied, they may instead be separate Ethernet links connected via an Ethernet switch.
At most substations there will also be “Power Meters” („M‟ in the diagrams below) which measure network parameters on lines that are not metered for revenue. For example these will measure power flows on lines between NEGK substations.
A combined “Metering Aggregator” and “SCADA Data Collector” polls the meters and collects and stores the relevant data. The SCADA Data Collector function will poll for SCADA data quite frequently (probably once per second) while the Metering Aggregator function will poll for metering data at the metering period (usually once per half hour).
There are two types of communications connection depending on whether the substation is connected via fibre or GPRS (Refer to Figure 30 and Figure 31).
Figure 30 Equipment Architecture - Fibre Connected Substation
PABX (NEGK) SDH Router Fibre Links MULTIPLEXER
Substation LAN
SCADA DATA METERING IRIG-B GPS COLLECTOR AGGREGATOR CLOCK
Multi-drop serial SCADA data connection
Multi-drop serial metering data connection
M M A A B B B B B
Power meters Type A - System meters Type B - Feeder meters
A Global Positioning System (GPS) synchronised clock will be provided at all sites to synchronise the Metering Aggregator‟s internal time clock. This is required to ensure metering data is collected over precise
June 2010 Page 32 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report metering periods which are uniform over all sites. Each kWh meter also has an internal realtime clock which will be synchronised by the Metering Aggregator using commands over the serial link to the meter. Time synchronisation will be required for digital protection relays and for Remote Terminal Units (RTUs) when these are added. This is to allow accurate time stamping of critical events such as trips for sequence- of-events (SOE) analysis.
Figure 31 Equipment Architecture - GPRS Connected Substation
GPRS MODEM
serial data
SCADA DATA METERING IRIG-B GPS COLLECTOR AGGREGATOR CLOCK
Multi-drop serial SCADA data connection
Multi-drop serial metering data connection
M M A A B B B B B
Power meters Type A - System meters Type B - Feeder meters
Eventually an RTU will be installed at each substation to provide the interface between the physical substation and power station equipment being monitored and controlled, and the communications network.
A SCADA Standard will have to be developed that defines the alarms, status points and parameters to be monitored, as well as defining point-of-control selection and the different classes of devices to be controlled. New substations, fitted with modern computer based control systems (CSCS), may be directly interfaced via LAN or serial link with the communications network and may not need an additional RTU. An industry standard communications protocol for the RTUs and a CSCS such as DNP 3.0 or IEC 60870-5-101/1047 will be specified.
When microprocessor based digital protection relays and other Intelligent Electronic Devices (IEDs) are installed they can be connected the RTU via serial data links or via Ethernet directly to a substation LAN.
6.4 SCADA Upgrade Advantages The initial SCADA system will obtain realtime data from seven substations and periodic data from the rest. No status or alarm signals will be sent from substations however the SCADA software will be able to generate alarms if measured values fall above or below configured limits. The initial system will give operators a far better view of the network power flows than at present because more points will be monitored and update times for a lot of the measurements will be faster.
When fully completed the SCADA system will provide considerable advantages for operation and control of the network as well as for supporting business systems. These include:
Real Time Monitoring o The status displayed is up-to-date and accurate allowing operators to make informed decisions
7 IEC 60870 Part 5: Telecontrol equipment and systems. Part 5: Transmission protocols. June 2010 Page 33 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
o Faults are indicated immediately allowing for quicker remedial response o Near overload situations are alarmed and can be corrected before tripping occurs o Full fault data including “sequence-of-events” is recorded allowing determination of causes of faults in multiple tripping situations o Real time data can be exchanged with the CAPS operator in Tashkent (using ICCP or other standard communications protocol) Remote Control o Allows the system operator to immediately action controls or to dispatch generation o Will facilitate hierarchical operation of the transmission network o Facilitates de-manning of substations Data Collection o Good statistical data can be collected for planning purposes o Key Performance Indicator (KPI) parameters are readily determined using data available from the Historian and these can be displayed to operational and management staff.
6.5 SCADA System Scope of Work and Costs 6.5.1 Scope of Work - SCADA The scope of the proposed SCADA component will provide for the following elements: Survey of control centre and substation sites Integration, supply, delivery, installation and configuration of all SCADA master station equipment for two sites Integration, supply, delivery, installation and configuration of substation SCADA equipment as required Design and implementation of building upgrades Supply, delivery and installation of large screen displays Supply, delivery and installation of power supplies to support SCADA equipment Supply, delivery, installation and configuration of associated IT equipment Factory acceptance testing Commissioning of all systems Provision of tools, test equipment, spares, documentation, training, warranty support.
6.5.2 Costs Initially only partial SCADA master stations will be implemented communicating with the metering data collection sub-systems. A subsequent stage will expand the Master Stations and add RTUs to substations.
The estimated cost of the preliminary SCADA component is shown in Table 14.
Table 14 Estimated Cost of SCADA Component Item Cost (USD) SCADA Master Stations (1 NCC, 1 x RCC, 7 substations) 1,840,000 Miscellaneous Equipment 603,000 Building Upgrade 571,000 Total (excluding contingencies) 3,014,000
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7.0 Cost Summary
Table 15 summarises the estimated total cost and the cost by procurement package (refer Section 8.1) of the three physical components of the proposed project.
Table 15 Estimated Total Project Cost Item Total Cost (USD) Package 1 (USD) Package 2 (USD) Wholesale Metering 6,835,000 2,365,000 4,470,000 Communications & SCADA 12,559,000 0 12,559,000 Substation Upgrades 15,655,000 15,655,000 0 Total (excluding contingencies) 35,049,000 18,020,000 17,029,000
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8.0 Project Implementation and Procurement
8.1 Project Implementation 8.1.1 Timeframe The expected timeframe for project implementation, based on ADB expectations8, is as follows:
Fact-Finding Mission June 2010 Loan/Grant Agreement Negotiations August 2010 ADB Board Approval September 2010 Loan Effectiveness/ Project Commencement December 2010.
8.1.2 Implementation Schedule The proposed implementation schedule is shown in Appendix 12. Implementation is expected to take 36 months from Project Commencement through to complete commissioning of the associated works. It is recommended that advance procurement procedures be put in place to appoint the project implementation consultant (PIC) upfront so that the PIC can commence immediately the loan becomes effective. Assuming that the ADB Board approves the proposed Loan/Grant in September 2010, then project implementation would be carried out during the period January 2011 - December 2013.
This time frame is subject to the following assumptions:
Timely availability of local funds NEGK‟s project implementation team appointed No delay in recruitment of the PIC No delay in ICB process for the two procurement packages Efficient performance by the implementation contractors Overall timely implementation of the Project.
Approximately 30 months has been allowed for the design, manufacture, installation, commissioning and completion of as-built drawings for the three physical components of the Project. Twelve months has been allowed for the design, manufacture testing, shipping and delivery of major plant.
The installation phase of Package 1 by NEGK can commence as soon as the detail design drawings of the equipment become available, at which time civil works for foundations at the substations can begin. Installation of the equipment can follow as soon as deliveries in Kyrgyzstan permit.
The installation phase of Package 2 by the contractor will commence immediately the equipment starts to arrive in Kyrgyzstan which is expected to be late 2012. The critical item will be the installation of the OPGW on the designated transmission circuits; NEGK will need to carefully co-ordinate the necessary line outages to allow safe access to the towers and lines.
Although construction should not be unduly hampered by the winter season (December - February), careful planning should be made to avoid any specific component of the works whose progress could be impaired due to snow conditions during that period.
8.1.3 Project Implementation Unit NEGK's Project Implementation Unit (PIU) is situated at NEGK's Head Office in Bishkek and currently has three staff, plus a Director. The three staff are all engineers; the first deals with technical issues; the second with procurement processing; and the third has just been appointed to assist with the new ADB Project. The first two engineers have been with the PIU since 1999.
The PIU's existing responsibility includes procurement, processing and co-ordination of all NEGK's major contracts. A list of their experience is included in Appendix 13.
8 Refer Aide Mermoire for Consultation Mission for Kgz: Power Sector Improvement Project., 14 June 2010. June 2010 Page 36 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
In order to meet ADB's requirements for the new Project, NEGK have agreed that they will further expand the capability of the PIU and appoint additional qualified personnel for (i) project accounting requirements and (ii) for safeguard monitoring.
As the wholesale metering equipment and protection equipment have relatively short delivery lead times, it is envisaged that these two components could be implemented within twelve months from commencement. The communications and SCADA components involve significant more design and preparation is expected to be a two to three year implementation project. All implementation would be subject to the following key factors:
Full support and co-operation of NEGK NEGK project implementation team appointed No delays in recruitment of project implementation consultant No delays in ICB process for implementation contractor Efficient performance by implementation contractor No technical issues (such as availability of NEGK‟s proposed new communications network).
8.2 Procurement All procurement of goods and services to be financed under the Project will be carried out in accordance with the ADB‟s Procurement Guidelines, with only ADB-member countries9 eligible to participate. Procurement using International Competitive Bidding (ICB) will be undertaken by NEGK, with assistance from the project implementation consultant. NEGK will administer the contracts as employer and implementing agency.
8.2.1 Procurement Packages The three physical components of the Project will be procured as two Packages.
Package 1 will provide for the (i) complete supply and delivery of new CTs and VTs for the Wholesale Metering component in selected substations; and (ii) complete supply and delivery of new CBs and CTs for the Substation Upgrade component. ADB‟s single-stage two-envelope ICB bidding procedures for supply and delivery contracts and ADB's Standard Bidding Documents for Goods will be used. Installation and commissioning of all Package 1 equipment will be by NEGK.
Package 2 will provide for the (i) complete supply, delivery, installation and configuration of the Wholesale Metering component, including wholesale meters, aggregators, host computers, and associated metering accessories; and (ii) complete supply, delivery, installation and configuration of the Communications and SCADA component. ADB‟s single-stage two-envelope bidding procedures for design-build and turnkey contracts and ADB's Standard Bidding Documents for Plant - Design, Supply and Install will be used.
Two-envelope bidding is an accepted international practice and is widely applied in many ADB member countries. It allows borrowers the option to evaluate the technical aspects of bids in the absence of price information. In some circumstances, this reduces political pressures that can result when price information is public and allows borrowers to evaluate technical proposals in an impartial setting. In ADB's single-stage, two-envelope bidding procedure, bidders submit two sealed envelopes simultaneously, one containing the technical proposal and the other the price proposal, enclosed together in an outer single envelope. The technical proposal is opened first at the date and time advised in the bidding document; and the price proposals remain sealed and are held in secure custody by the purchaser (i.e. NEGK). The technical proposal is reviewed to determine responsiveness to the bidding documents. Only the financial proposals of bidders with responsive technical proposals are opened for evaluation and comparison; the contract is awarded to the bidder whose bid is determined to be the lowest evaluated substantially responsive bid. The financial proposals of bidders whose technical proposals are not responsive are returned unopened.
8.2.2 Project Implementation Consultant It is recommended that a Project Implementation Consultant (PIC) be appointed to assist NEGK throughout the project cycle. The consultant will be selected and engaged in accordance with ADB‟s quality-and-cost- based-selection (QCBS) procedures.
9 It is noted that Russia is not a member country of ADB and therefore the Russian manufacturer of NEGK‟s existing digital meters will be unable to participate. June 2010 Page 37 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
The PIC will be responsible for assisting NEGK to implement the three physical components and to ensure timely and satisfactory completion of the project, including:
Preparation of specifications, tendering, bid evaluation and contract award of the two packages Approval of contractor's designs and factory acceptance tests Supervising construction, installation, testing and commissioning of Package 1 by NEGK and Package 2 by the contractor Ensuring satisfactory operation of the equipment during the takeover period Preparation and monitoring of comprehensive project management plans to ensure the most efficient, timely and economical implementation of the Project Co-ordination with NEGK's PIU Ensuring satisfactory safeguard monitoring Project reporting.
A total of 196 person-months comprising 73 person-months of international consultancy and 123 person- months of domestic consultancy input is envisaged. Key positions would include:
International Project Manager (Electrical Engineer) International Metering Expert International SCADA Expert International Communications Expert International Safeguards Expert National Deputy Project Manager (Electrical Engineer) National Substation Engineers x 2 National Electrical Engineer National Safeguards Expert.
Suitable office space and furniture in NEGK's Head Office in Bishkek should be provided by NEGK for the PIC team for duration of the Project.
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Appendix 1 Terms of Reference
Contract S20828 Project TA - 7368 (KGZ): Transmission and Distribution Metering Project Expertise Transmission & Distribution Metering Expert/TL Source International Category Firm
Objective/Purpose of the Assignment: The objective is to prepare the ensuing loan of Transmission and Distribution Metering Project for ADB funding in 2010. The Project is expected to contribute to the power companies' efforts to establish a solid commercial base of operations, and enhance transparency and accountability of the power sector, which will subsequently reduce system loss.
Scope of Work: To assist in producing the Feasibility Study Report (FSR) with bidding documents for equipment to be procured under the Project. The FSR will be summarized in the form of ADB's Report and Recommendation of the President. All relevant policies and guidelines of ADB must be strictly followed.
Detailed Tasks: 1. Assume overall responsibility of S-PPTA and the team of consultants including accounting/settling direct costs; 2. The team's point of contact with Ministry of Industry, Energy and Fuel Resources (MIEFR), National Electrical Grid of Kyrgyzstan, distribution companies, other stakeholders, and ADB. Make sure that all aspects of the Project are agreed with key stakeholders; 3. Review existing studies relevant to the Project. These include USAID's "Needs Assessment for Transmission Metering and Data Acquisition" and "Central Metering System and Automated Data Acquisition System Introduction", as well as other documents prepared by MIEFR, NGK, and the distribution companies; 4. Review recent/on-going projects funded by donors relevant to the Project (e.g., USAID's "Electricity Loss Reduction Demonstration Models' 2004; KfW's ongoing distribution improvement project for Bishkek); 5. Prepare a power sector assessment, including its power infrastructure features, supply and demand balance, progress in sector reform, tariff structure, issues, development plans, external assistance, etc.; 6. Prepare a separate risk assessment for the sector and project highlighting governance and corruption issues and solutions; 7. Based on the concept prepared by MIEFR with assistance of USAID, prepare a detailed phase-wise comprehensive metering development program to deploy wholesale/master metering, computerized metering and billing system, and SCADA system including a communication system; and a new organization to operate and maintain the system. Phase 1 of this Project envisaged to comprise the installation of wholesale/master metering, and the establishment of a computerized metering and billing system. Consideration must be given to the unique context of the Kyrgyz power sector, efficient use of and compatibility with existing facilities and CAPS, economical approach, and acceptance by the stakeholders; 8. Assess the status of metering and billing system and practices, including software and information technology standards, institutional structure, and recent projects; 9. With due consideration to the new metering equipment to be deployed by the Project and the comprehensive metering program, devise an improved metering and billing system concept including necessary software, practices, organizational structures, maintenance equipment, and training. (The experts to be recruited under the Project will finalize the design and implement the metering and billing system); 10. Prepare an inventory of metering facilities throughout the network through desk study and field visits. Inventory to include assessment on status of each; 11. As the basis of the Project design, prepare technical specifications of wholesale/master meters that are compatible with the systems proposed in the comprehensive metering program and the CAPS; In consultation with the EA and IAs, and with due consideration to the comprehensive metering program, devise a selection criteria and identify specific key wholesale/master metering requirements to be funded by the Project (i.e., scope of the Project). Prepare Project layout map and diagrams (single line, schematic, etc.) as necessary; 12. Prepare bill of quantities and cost estimate for wholesale/master meter installation. Cost estimate should separate: costs between the transmission company and the four distribution companies; foreign and local costs; and base costs, consulting services, environmental/social safeguards implementation NOTE: Actual schedule to be confirmed with User Unit. costs; taxes/duties; physical/price contingencies; interest during construction; front-end fees; commitment charges, etc.;
June 2010 Page 39 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
13. Prepare a procurement plan and implementation schedule with disbursement projection; 14. Prepare bidding documents for procurement of equipment under the Project; and 15. Consolidate inputs from other experts and lead the preparation of reports (FSR, RRP, and Project Administration Memorandum).
NB: The distribution components above were cancelled - refer Review Mission Aide Memoire dated 8 February 2010
Contract S21610 Project TA - 7368 (KGZ): Transmission and Distribution Metering Project Expertise Communications and SCADA Expert Source International Category Firm
Objective/Purpose of the Assignment: The objective is to prepare the ensuing loan of Transmission and Distribution Metering Project for ADB funding in 2010. The Project is expected to contribute to the power companies' efforts to establish a solid commercial base of operations, and enhance transparency and accountability of the power sector, which will subsequently reduce system loss.
Scope of Work: To assist in producing the Feasibility Study Report (FSR) with bidding documents for equipment to be procured under the Project. The FSR will be summarized in the form of ADB's Report and Recommendation of the President. All relevant policies and guidelines of ADB must be strictly followed.
Detailed Tasks: The expert shall carry out an assessment of the National Electrical Grid of Kyrgyzstan's (NEGK) existing national communications system and recommend the concept design for a replacement communications system to international standards suitable for NEGK's requirements including:
Communication links between NEGK's existing Load Dispatch Centre (LDC) in Bishkek and all NEGK's 500 kV, 220 kV and 110 kV grid substations (2, 14 and 174 respectively) as well as the generation stations connecting to the transmission grid; Communication links between NEGK's existing LDC and NEGK's six regional administration centres (Chuy, Naryn, Issyk-Kul, Talas, Jalalabad and Osh); Provision for connecting to a future new LDC; The existing NEGK communications system is a mix of HF radio and power line carrier, with some limited use of commercial GSM networks. The proposed communication system shall utilise proven technology and provide for all voice, SCADA and billing system requirements; It is envisaged that the assignment will require 3 weeks on site and two weeks in the home office. The expert shall carry out, but not be limited to, the following tasks: i. Review NEGK's existing national communications system and their future plans; ii. Prepare a concept plan for a new national communications system; iii. Prepare a concept plan for a new SCADA system; iv. Assess regional benefits of a new national communications and/or SCADA system; v. Consideration must be given to the unique context of the Kyrgyz power sector, efficient use of and compatibility with existing facilities and Central Asia Power System (CAPS), economical approach, and acceptance by the stakeholders; vi. Prepare separate bill of quantities and cost estimate for (i) a new national communications and (ii) SCADA system. Cost estimate should separate: foreign and local costs; base costs, consulting services, taxes/duties; physical/price contingencies; interest during construction; front-end fees; commitment charges, etc.; vii. Prepare a risk assessment for this project component highlighting issues and solutions; and viii. Prepare a procurement plan and implementation schedule with disbursement projection.
June 2010 Page 40 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Appendix 2 List of Key Officials Met
Key Persons Met (excludes officers under previous Government): Name Title Company Takafumi Kadono Energy Specialist ADB Roka Sanda Investment Specialist ADB Jim Liston Energy Specialist ADB Cheong-Ann Png Attorney ADB Lan Wu Country Director ADB KYRM Bobur Alimov Portfolio Management Specialist ADB KYRM Mirdin Eshenaliev Project Implementation Officer ADB KYRM Dinara Rysalieva Senior Administrative Assistant ADB KYRM Olesya Protsenko Mission Assistant ADB KYRM Artykbaev Osmonbek Minister MoE Erkin Abdykalikov Deputy Minister MoE Aftandil Kalmambetov Deputy Minister MoE Temir Sariev Minister MoF Arzibek Kojoshev Deputy Minister MoF Abdualim Nishanov Deputy Minister MoF Erik Usubaliev Deputy Minister (until 07 June 2010) MoF Saidbee Zulpuev Deputy Minister MoF Raimbek Mamirov General Director NEGK Murat Djumanalievich Durusaliev First Deputy General Director NEGK Bapa Raevich Janibekov Deputy General Director Finance NEGK Kubanychbek Ismailov Deputy General Director NEGK Alexey Borodin Technical Director Operations NEGK Leonid Popov Head of (Planning) Department NEGK Melisbek Isakovich Head PIU NEGK Kubanichbek Asanovich Smankulov Head of Communications Department NEGK Anarbek Baibachaev Head Engineer Radio Relay NEGK Sergey Ribalov Head Engineer Tele-Mechanics NEGK Erkin Kurmanov Head Engineer of HF NEGK Tunukbek Kurmanbekovich Djumabaev Head of Meterology Dept NEGK Vladimir Alexseevich Hohlov Chief Engineer Meterology Dept NEGK Alexsander Mihaylovich Burimov Chief Engineer Communications Dept NEGK Kanat Kalilov Head of Substations NEGK Jalalabad Asilbek Agashrapov Chief Engineer NEGK Jalalabad Abdykalyk Moldoisaev Director NEGK Osh Sergey Bochko Chief Engineer EPP JSC Evgeny Orlenko General Director Chakan GES Hreshev Vadim Vitalievech Chief Engineer BTel (BeeLine) Joellyn Murphy Chief of Party PA Consulting Stefan Lutz Director Central Asia Office KfW Olga Gorovenko Country Co-ordinator KfW Project Team Michael Breckon Transmission Specialist / Team Leader AECOM NZ Scott Thode Communications and SCADA Expert AECOM NZ Janybek Omorov International Consultant Energy
June 2010 Page 41 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Name Title Company Samat Sukenaliev Assistant Engineer Yuri Simakov Transmission Metering Expert Djamila Aitmatova Environmental & Social Safeguards Expert Dinara Choibekova Economic & Financial Expert
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Appendix 3 NEGK Substations
A. Sorted by Region Region № Name of Substation and Voltage kV № Name of Substation and Voltage kV ChuPVES 1 Frunzenskaya 500/220 kV 27 Parkovaya 110/35/10 kV 2 Kara-Balta 220/110/10 kV 28 Seleksionnaya 110/10 kV 3 Ala-Archa 220/110/10 kV 29 Orto-Alish 110/35/10 kV 4 Glavnaya 220/110/10 kV 30 Jani-Jer 110/35/10 kV 5 Chuyskaya 220/110/35/10 kV 31 Berlik 110/35/10 kV 6 Bistrovka 220/110/35 kV 32 Teplichnaya 110/35/10 kV 7 Ak-Bashat 110/35/10 kV 33 Abdikalikova 110/35/6 kV 8 Кosh-Tegeren 110/35/10 kV 34 Orok 110/35/10 kV 9 Rovnoe 110/35/10 kV 35 Vostochnaya 110/35/6 kV 10 Kainda 110/35/10 kV 36 Yujnaya 110/35/6 kV 11 CHP К 110/35/6 kV 37 Molodaya-Gvardiya 110/35/10 kV 12 Besh-Terek 110/35/10 kV 38 Karagachevaya 110/35/10 kV/6 kV 13 Ak-Suu 110/35/6 kV 39 Lermontova 110/35/10 kV 14 Moskovskaya 110/35/10 kV 40 Atabaeva 110/35/6 kV. 15 Sadovaya 110/10 kV 41 Promishlennaya 110/35/6 kV 16 Botbaeva 110/35/10 kV 42 Alamedin 110/35/10 kV 17 Sokuluk 110/10 kV 43 Kant 110/35/10 kV. 18 Manas 110/35/10 kV 44 Ivanovka 110/35/10 kV 19 Kun-Tuu 110/35/10 kV 45 Tokmok 110/10 kV. 20 Kizil-Asker 110/35/6 kV 46 Karoy 110/35/10 kV 21 Н-Yujnaya 110/35/10 kV 47 KHP 110/10 kV. 22 Kostromskaya 110/35/10 kV 48 Iskra 110/35/6 kV 23 N-Zapadnaya 110/35/6 kV 49 Orlovka-1 110/35/10 kV 24 Archa-Beshik 110/10 kV 50 Shabdan 110/35/10 kV 25 Ayni 110/10 kV 51 Pikovaya 110/6 kV 26 Kirgizskaya 110/10 kV NPVES 1 Ak-Kiya 220/110/10 kV 10 Kara-Kujur 110/10 kV 2 Naryn-1 110/35/10 kV 11 Kochkor 110/10 kV 3 Ala-Too 110/35/10 kV 12 Cholpon 110/35/10 kV 4 Torugart 110/10 kV 13 Davlet-Arik 110/10 kV 5 Ugut 110/35/10 kV 14 Chaek 110/10 kV 6 Ala-Buga 110/6 kV 15 Kara-Keche 110/35/10 kV 7 Jetigen 110/35/10 kV 16 Aral 110/6 kV 8 Jani-Talap 110/35/10 kV 17 Min-Kush 110/35/6 kV 9. Sari-Bulak 110/10 kV TPVES 1 Tuleberdieva 500/220/10 kV 8 Pokrovka 110/10 kV 2 Semetei 220/110/10 kV 9 Kara-Archa 110/10 kV 3 Kirovka 110/35/10 kV 10 Bala-Sary 110/6 kV 4 Talas 110/35/10 kV 11 Aral 110/10 kV 5 Chat-Bazar 110/35/10 kV 12 Ken-Kol 110/10 kV 6 Pobeda 110/35/10 kV 13 Ozgorush 110/10 kV 7 Manas 110/10 kV 14 Ivano-Allekseevka 110/10 kV OshPVES 1 Kashgar-Kishlak 110/10 kV 21 Arka 110/35/6 kV 2 Tabachnaya 110/10 kV 22 Celinnaya 110/6 kV 3 Kara-Shoro 110/35/10 kV 23 Morskaya 110/6 kV 4 Tashirova 110/10 kV 24 Batken 110/35/10 kV 5 Naukat 110/35/10 kV 25 Centrаlnaya 110/35/6 kV 6 Madaniyat 110/10 kV 26 Samat 110/35/10 kV 7 Center 110/10 kV-6 28 Kara-Kulja 110/35/10 kV 8 Kok-Jar 110/35/10 kV 29 Madi 110/6 kV 9 Salieva 110/10 kV 30 Tepe-Korgon 110/10 kV 10 Osh-6 110/35/10 kV 31 Aygul-Tash 220/110/10 kV. 11 Pamirskaya 32 Uzlovaya 220/110/10 kV.
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Region № Name of Substation and Voltage kV № Name of Substation and Voltage kV 12 Tuleyken 33 Alay-220 220/110/10 kV. 13 Anar 110/10 kV/6 kV 34 Uchar 110/6 kV. 14 Kara-Suu 110/35/10 kV/6 kV 35 Besh-Moynok 110/10 kV 15 Kdamjay 110/35/10 kV 36 Karatay 110/35/10 kV 16 Jin-Jigan 110/35/6 kV 37 Gulcha 110/35/10 kV 17 Kizil-Kiya1 110/35/6 kV 38 Sofi-Korgon 110/10 kV 18 Kizil-Kiya2 110/35/6 kV 39 Uch-Dobo 110/10 kV 19 Metlaurgicheskaya 110/35/6 kV 40 Sary-Tash 110/35/10 kV 20 Plavilnaya 110/6 kV 41 Kara-Kulja 110/35/10 kV JPVES 1 Oktyabrskaya 220/110/10 kV 19 Shamaldi-Say 110/35/6 kV 2 Kristal 220/110/10 kV 20 Tash-Komur 110/35/6 kV 3 Suzak 110/35/10 kV 21 Karavan 110/35/10 kV 4 Gromadin 110/10 kV 22 Ala-Buka 110/35/6 kV 5 Tashtemirova 110/10 kV 23 Shekaftar 110/35/6 kV 6 Tash-Bulak 110/35/10 kV 24 Gorodok 110/6 kV. 7 Mirzajan 110/10 kV 25 Kainda 110/6 kV 8 Jalalabat 110/35/10 kV/6 kV 26 Kara-Kul 110/35/6 kV 9 Barpy 110/10 kV 27 Kara-Suu 110/6 kV/6 kV 10 Bek-Adab110/10 kV 28 Abasbekova 110/10 kV 11 Rayonnaya 110/35/10 kV 29 Kabilbekova 110/35/6 kV 12 Urumbash 110/35/10 kV 30 Uch-Terek 110/35/10 kV. 13 Teplichnaya 110/35/10 kV 31 Toktogul 110/35/10 kV 14 Bazar-Korgon 110/35/10 kV 32 Kozubekova 110/35/10 kV 15 Izbaskent 110/35/6 kV 33 Nijnaya 110/10 kV/6 kV. 16 Yug 110/35/6 kV 34 Padish-Ata 110/10 kV/6 kV. 17 Kok-Tash 110/6 kV 35 Jiyde 110/10 kV. 18 Ak-Korgon 110/10 kV. 36 Malkova 110/6 kV. IPVES 1 Issyk-Kul 220/110/10 kV 17 Jeti-Oguz 110/10 kV 2 Tamga 220/110/10 kV 18 Prejevalskaya 110/35/10 kV 3 Ribache-1 110/35/10 kV 19 Vostochnaya 110/35/10 kV 4 Pionerskaya 110/10 kV 20 Dolinka 110/10 kV 5 Ulahol 110/10 kV 21 Cholpon-Ата 110/35/10 kV 6 Promishlennaya 110/10 kV 22 Bosteri 110/35/10 kV 7 Sari-Kamish 110/10 kV 23 Komsomol-2 110/35/10 kV 8 Toru-Aygir 110/10 kV. 24 Grigorievka 110/10 kV 9 Ak-Terek 110/10 kV. 25 Ananevo 110/10 kV 10 Bokonbaevo 110/10 kV 26 Oytal 110/10 kV 11 Kadji-Sai 110/6 kV 27 Kurmenti 110/10 kV/6 kV 12 Toguz-Bulak 110/10 kV. 28 Tyup 110/35/10 kV 13 Barskaun 110/10 kV 29 Pristan 110/35/10 kV 14 Choktal 110/10 kV 30 Kun-Batish 110/10 kV 15 Kara-Sai 110/10 kV 31 Pokrovka 110/35/10 kV 16 Ak-Shiyrak 110/10 kV
B. Sorted by Substation Region Substation Voltage kV Russian Comment Name JPVES Abasbekova 110/10 Абасбекова ChuPVES Abdikalikova 110/35/6 АбдьiкАльiкова ChuPVES Ak-Bashat 110/35/10 Ак-Башат NPVES Ak-Kiya 220/110/10 Ак-Кия JPVES Ak-Korgon 110/10 Ак-Коргон IPVES Ak-Shiyrak 110/10 Ак-Шийрак ChuPVES Ak-Suu 110/35/6 Ак-Суу IPVES Ak-Terek 110/10 Ак-Терек ChuPVES Ala-Archa 220/110/10 Ала-Арча
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Region Substation Voltage kV Russian Comment Name NPVES Ala-Buga 110/6 Ала-Бука JPVES Ala-Buka 110/35/6 Ала-Бука ChuPVES Alamedin 110/35/10 Аламедин NPVES Ala-Too 110/35/10 Ала-Тоо OPVES Alay-220 220/110/10 Алай-220 International Connection IPVES Ananevo 110/10 Ананьево OPVES Anar 110/10/6 Анар NPVES Aral 110/10 Арал TPVES Aral 110/6 Арал ChuPVES Archa-Beshik 110/10 Арча-Бешик OPVES Arka 110/35/6 Арка International Connection ChuPVES Asanbay 110/35/6 Асанбай ChuPVES Atabaeva 110/ Атабаева NPVES Atbashinskaya HPP 10/110 Атбашинская гзс Power Plant EPP OPVES Aygul-Tash 220/110/10 Айг.-Таш International Connection ChuPVES Ayni 110/10 Айни TPVES Bala-Sari 110/6 Баласары JPVES Barpi 110/10 Барпы IPVES Barskaun 110/10 Барскаун OPVES Batken 110/35/10 Баткен International Connection JPVES Bazar-Korgon 110/35/10 Базар-Коргон JPVES Bek-Abad 110/10. Бек-Абад ChuPVES Berlik 110/35/10 Берлик OPVES Besh-Moynok 110/10 Беш-Мойнок ChuPVES Besh-Terek 110/35/10 Беш-Терек ChuPVES Bistrovka 220/110/35 Быстровка International Connection ChuPVES Bistrovka HPP 6/110 Быстровка гзс Small Hydro Power Plant IPVES Bokonbaevo 110/10 Боконбаево IPVES Bosteri 110/35/10 Бостери ChuPVES Botbaeva 110/35/10 Ботбаева OPVES Celinnaya 110/6 Цeлинная ChuPVES Cementnaya 110/35/6 Цементная OPVES Cemzavod 110/10 Цемзавод OPVES Center 110/10-6 Цeнтр OPVES Centralnaya 110/35/6 Цeнтральная NPVES Chaek 110/10 Чаек TPVES Chat-Bazar 110/35/10 Чат-Базар IPVES Choktal 110/10 Чок-Тал NPVES Cholpon 110/35/10 Чолпон IPVES Cholpon-Ata 110/35/10 Чолпон-Ата ChuPVES CHP-B 110/35/6 Тзц-Б Power Plant EPP ChuPVES CHP-K 110/35/6 Тзц-К Power Plant EPP OPVES CHP-Osh 10/110/35 Тзц-Ош Power Plant EPP ChuPVES Chuyskaya 220/110/35/10 Чуйская Datka (500/220) Датка Future NPVES Davlet-Arik 110/10 Давлет-Арык IPVES Dolinka 110/10 Долинка ChuPVES Dordoy 110/6 Дордой OPVES Echmrad 110/ Эчмрaд IPVES Enilchek 110/10 Энильчек ChuPVES Frunzenskaya 500/220 Фрунзенская International Connection ChuPVES Glavnaya 220/110/10 Главная International Connection JPVES Gorodok 110/6 Городок
June 2010 Page 45 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Region Substation Voltage kV Russian Comment Name IPVES Grigorevka 110/10 Григорьевка JPVES Gromadin 110/10 Грамадин OPVES Gulcha 110/35/10 Гульча ChuPVES Iskra 110/35/6 Искра IPVES Issyk-Kulskaya 220/110/10 Иссык-Кульская TPVES Ivano-Alekseevka 110/10 Иваново- Алексээвка ChuPVES Ivanovka 110/35/10 Ивановка International Connection JPVES Izbaskent 110/35/6 Избаскент International Connection JPVES Jalal-Abad 110/35/10/6 Джалал-Абад ChuPVES Jani-Jer 110/35/10 Джани-Джер International Connection NPVES Jani-Talap 110/35/10 Жаны-Талап NPVES Jetigen 110/35/10 Джэтигэн IPVES Jeti-Oguz 110/10 Джеты-Огуз OPVES Jin-Jigan 110/35/6 Джин-Джиган JPVES Jiyde 110/10 Джийдэ ChuPVES Kabelnaya 110/10 Кабельная JPVES Kabilbekova 110/35/6 Кабылбекова OPVES Kadamjay 110/35/10 Кадамжай International Connection IPVES Kadjisai 110/6 Каджи-Сай ChuPVES Kainda 110/6 Каинда JPVES Kainda 110/35/10 Каинда JPVES Kambar-Ata 110/35/10 Камбар-Ата ChuPVES Kant 110/35/10 Кант TPVES Kara-Archa 110/10 Кара-Арча International Connection ChuPVES Kara-Balta 220/110/10 Кара-Балта ChuPVES Karagachevaya 110/35/10/6 Карагачевая NPVES Kara-Keche 110/35/10 Кара-Кече NPVES Kara-Kujur 110/10 Кара-Кужур JPVES Kara-Kul 110/35/6 Кара-Куль OPVES Kara-Kulja 110/35/10 Кара-Кульджа IPVES Kara-Sai 110/10 Кара-Сай OPVES Kara-Shoro 110/35/10 Кара-Шоро OPVES Kara-Suu 110/35/10/6 Кара-Суу International Connection JPVES Kara-Suu 110/6/6 Кара-Суу OPVES Karatay 110/35/10 Каратай JPVES Karavan 110/35/10 Караван ChuPVES Karoy 110/35/10 Карой OPVES Kashgar-Kishlak 110/10 Кашгар-Кишлак ChuPVES Kemin (500/220) Кемин Future TPVES Ken-Kol 110/10 Кен-Кол ChuPVES KHP 110/10. КХП ChuPVES Kirgizskaya 110/10 Кыргызская TPVES Kirovka 110/35/10 Кировка ChuPVES Kizil-Asker 110/35/6 Кызыл-Аскер OPVES Kizil-Kiya 1 110/35/6 Кызыл-Кия-1 OPVES Kizil-Kiya 2 110/35/6 Кызыл-Кия-2 NPVES Kochkorka 110/10 Кочкорка OPVES Kok-Jar 110/35/10 Кок-Жар JPVES Kok-Tash 110/6 Кок-Таш IPVES Komsomol-2 110/35/10 Комсомол-2 ChuPVES Kosh-Tegirmen 110/35/10 Кош-Тегирмен ChuPVES Kostromskaya 110/35/10 Костромская JPVES Kozubekova 110/35/10 Козубекова June 2010 Page 46 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Region Substation Voltage kV Russian Comment Name JPVES Kristal 220/110/10 Кристал International Connection IPVES Kun-Batish 110/10 Кун-Батыш ChuPVES Kun-Tuu 110/35/10 Кун-Туу JPVES Kupsayskaya HPP 10/220/110 Курпсaйская гзс Power Plant EPP IPVES Kurmenti 110/10/6 Курменты ChuPVES Lenin Zavod 110/10 Ленина зaвоД ChuPVES Lermontova 110/35/10 Лермонтова OPVES Madaniyat 110/10 Маданият OPVES Madi 110/6 Мады NPVES Makmal 110/6 Макмал JPVES Malkova 110/6 Мальков ChuPVES Manas 110/35/10 Манас TPVES Manas 110/10. Манас OPVES Mangit 110/35/10 Мангыт OPVES Mash Zavod 110/6 Маш Эавод OPVES Metalurgicheskaya 110/35/6 Металлургич. NPVES Min-Kush 110/35/6 Мин-Куш JPVES Mirzajan 110/10 Мырзажан ChuPVES Molodaya-Gvardiya 110/35/10 Молодогвардей OPVES Morskaya 110/6 Морская ChuPVES Moskovskaya 110/35/10 Московская NPVES Naryn-1 110/35/10 Нарын-1 OPVES Naukat 110/35/10 Ноокат JPVES Nijnaya 110/10/6 Ниджная ChuPVES N-Yujnaya 110/35/10 H-Южная ChuPVES N-Zapadnaya 110/35/6 Н-Западная JPVES Oktyabrskaya 220/110/10 Октябрьская International Connection ChuPVES Orlovka-1 110/35/10 Орловка-1 ChuPVES Orok 110/35/10 Орок ChuPVES Orto-Alish 110/35/10 Орто-Алыш OPVES Osh-6 110/35/10 Ош-6 IPVES Oytal 110/10 Ойтал TPVES Ozgorush 110/10 Озгоруш JPVES Padish-Ata 110/10/6 Падыша-Ата OPVES Pamirskaya 110/35/10 Памирская ChuPVES Parkovaya 110/35/10 Парковая ChuPVES Pikovaya 110/6 Пиковая IPVES Pionerskaya 110/10 Пионерская OPVES Plavilnaya 110/6 Плавильная TPVES Pobeda 110/35/10 Победа JPVES Podhoz 110/10 Подхоз IPVES Pokrovka 110/35/10 Покровка TPVES Pokrovka 110/10 Покровка IPVES PP Kumtor 110/ ПП Кумтор IPVES Prejevalskaya 110/35/10 Пржевальская IPVES Pristan 110/35/10 Пристань ChuPVES Promishlennaya 110/35/6 Промышленная IPVES Promishlennaya 110/10 Промышленная JPVES Rayonnaya 110/35/10 Районная IPVES Ribache-1 110/35/10 Рыбачье-1 ChuPVES Rovnoe 110/35/10 Ровное ChuPVES Sadovaya 110/10 Садовая OPVES Salieva 110/10 Салиева
June 2010 Page 47 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Region Substation Voltage kV Russian Comment Name OPVES Samat 110/35/10 Самат International Connection JPVES Sargata 110/6 Саргата NPVES Sari-Bulak 110/10 Сары-Булак IPVES Sari-Kamish 110/10 Сары-Камыш OPVES Sari-Tash 110/35/10 Сары-Таш ChuPVES Seleksionnaya 110/10 Селекционная TPVES Semetey 220/110/10 Семетей International Connection ChuPVES Shabdan-1 110/35/10 Шабдан-1 JPVES Shamaldi-Say 1 110/35/6 Шамалды-Сай 1 JPVES Shamaldi-Say 2 110/6 Шамалды-Сай 2 JPVES Shamaldi-Say HPP 10/220/110 Шамалды-Сай гзс Power Plant EPP JPVES Shekaftar 110/35/6 Шекафтар International Connection OPVES Sofi-Korgon 110/10 Софи-Коргон ChuPVES Sokuluk 110/10 Сокулук JPVES Suzak 110/35/10 Сузак OPVES Tabachnaya 110/10 Табачная TPVES Talas 110/35/10 Талас IPVES Tamga 220/110/10 Тамга JPVES Tash-Bulak 110/35/10 Таш-Булак OPVES Tashirova 110/10 Таширова JPVES Tash-Kumir 110/35/6 Таш-Кумыр JPVES Tash-Kumir HPP 10/220 Таш-Кумыр гзс Power Plant EPP JPVES Tashtemirova 110/10 Таштемирова OPVES Tepe-Korgon 110/10 Тепе-Курган ChuPVES Teplichnaya 110/35/10 Тепличная JPVES Teplichnaya 110/35/10 Тепличная IPVES Toguz-Bulak 110/10 Тогуз-Булак ChuPVES Tokmok 110/10 Токмак JPVES Toktogul 110/35/10 Токтогул JPVES Toktogulskaya HPP 10/500 Токтогулская гзс Power Plant EPP IPVES Toru-Aygir 110/10. Тору-Айгыр NPVES Torugart 110/10 Торугарт International Connection TPVES Tuleberdieva 500/220/10 Тулебердиева OPVES Tuleyken 110/35/10 Тюлейкен IPVES Tyup 110/35/10 Тюп OPVES Uchar 110/6. Учар OPVES Uch-Dobo 110/10 Уч-Добо JPVES Uch-Kurganskaya HPP 10/110 Уч-Кургaнская гзс Power Plant EPP JPVES Uch-Terek 110/35/10. Уч-Терек NPVES Ugut 110/35/10 Угут IPVES Ulahol 110/10 Улахол JPVES Urumbash 110/35/10 Урумбаш OPVES Uzgen 110/35/10 Узген OPVES Uzlovaya 220/110/10 Узловая International Connection ChuPVES Vostochnaya 110/35/6 Восточная IPVES Vostochnaya 110/35/10 Восточная JPVES Yug 110/35/6 Юг ChuPVES Yujnaya 110/35/6 Иуджная JPVES Zavod PPM 220/6 Эaеоб ППМ
June 2010 Page 48 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Appendix 4 Interconnection of Generation with NEGK Substations
Substations Frunzenskaya and Tuleberdieva 500/220/10 kV: Transmission Line 500 kV (Л-509) Тoktogul Hydro Power Station.
Substation Glavnaya 220/110/10 kV: Transmission Line 220 kV CHP B-1 Transmission Line 220 kV CHP B-2 Transmission Line 110 kV CHP B-1 Transmission Line 110 kV CHP B-2.
Substation Kara-Balta 220/110/10 kV: Transmission Line-110 kV CHP-К.
Substation Parkovaya 110/35/10 kV: Transmission Line 110 kV CHP-B-1 Transmission Line 110 kV CHP-B-2.
Substation Orok 110/10 kV: Transmission Line 110 kV CHP-B-1 Transmission Line 110 kV CHP-B-2.
Substation Kainda 110/35/10 kV: Transmission Line 110 kV CHP-К.
Substation Ak-Suu 110/35/6 kV: F-2 КCHP-1 F-8 КCHP-2.
Substation Karagachevaya 110/35/10/6 kV: Transmission Line 35 kV Hydro Power Station 3-1; Transmission Line 35 kV Hydro Power Station 3-2.
Substation Kant 110/35/10 kV: Transmission Line 110 kV CHP-B-1 Transmission Line 110 kV CHP-B-2.
Substation Shabdan 110/35/10 kV: Transmission Line 110 kV B Hydro Power Station.
Substation Ak-Kiya 220/110/10 kV: Transmission Line 110 kV А Hydro Power Station.
Substation Oktyabrskaya 220/110/10 kV: Transmission Line 220 kV Kurpsai HPP.
Substation Kristal 220/110/10 kV: Transmission lines 220 kV Kurpsai Hydro Power Station Transmission lines 220 kV Tashkomur Hydro Power Station 1 Transmission lines 220 kV Tashkomur Hydro Power Station 2 Transmission lines 220 kV Shamaldi-say Hydro Power Station Transmission lines 110 kV Shamaldi-Say Hydro Power Station.
Substation Bazar-Korgon110/35/10 kV: Transmission Line 10 kV Hydro Power Station.
Substation Izbaskent 110/35/6 kV: Transmission Line 110 kV Uch-Kurgan Hydro Power Station.
Substation Yug 110/35/6 kV: Transmission Line 35 kV CHP-1. June 2010 Page 49 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Shamaldi-Say110/35/6 kV: Transmission Line 35 kV Ush-Kurgan.
Substation Tash-Komur110/35/6 kV: Transmission Line 110 kV Ush-Kurgan.
Substation Uzlovaya 220/110/10 kV: Transmission Line 110 kV Osh CHP-1 Transmission Line 110 kV Osh CHP-2.
Substation Kara-Suu110/35/10/6 kV: Transmission Line 110 kV Osh CHP-1 Transmission Line 110 kV Osh CHP-2.
Total Connections = 34
June 2010 Page 50 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Appendix 5 Interconnection of DisCos with NEGK Substations
Substation Connection Point CT Type Factory Nº Year Purpose Ratio ChuPVES- Severelektro Kara-Balta 220/110/10/. Input 10 kV АТ-1 1000/5 Э-704 41318 2009 2 balance Input 10 kV АТ-2 1000/5 Э-704 37211 2009 2 balance Ala-Archa 220/110/10. Input 10 kV Т-1 800/5 С3V025 НS401039 2007 01 balance Input 10 kV Т-2 800/5 C3V025 НS401038 2007 01 balance Glavnaya 220/110/10. Input 10 kV АТ-1 1000/5 СЭТ-4ТМ.03 804090407 2009 3 balance Input 10 kV АТ-2 1000/5 СЭТ-4ТМ.03 804090325 2009 3 balance Chuyskaya Input 35 kV Т1 300/5 АМС-1400 6087 2007 02 balance 220/110/35/10. Input 35 kV Т2 300/5 АМС-1400 6036 2007 02 balance Input 10 kV Т-1 1000/5 Э-704 40015 2009 3 balance Input 10 kV Т-2 1500/5 Э-704 103474 2009 3 balance Bistrovka 220/110/35. Input 35 kV АТ-1 600/5 СЭТ4ТМ 12032040 2008 02 balance Input 35 kV АТ-2 600/5 СЭТ4ТМ 2030054 2008 02 balance Ak-Bashat 110/35/10 Input 35 kV Т-1 400/5 AMC-1400 5956 2007 02 balance Input 10 kV Т-1 1000/5 Э-704 37381 2007 03 balance Кosh-Теgeren 110/35/10 Input 35 kV Т-1 400/5 АМС-1400 6001 2007 02 balance Input 35 kV Т-2 400/5 АМС-1400 6044 2008 4 balance Input 10 kV Т-1 3000/5 АМС-1400 5930 2007 02 balance Input 10 kV Т-2 3000/5 АМС-1400 5960 2007 02 balance Rovnoe 110/35/10 Input 35 kV Т-1 150/5 АМС-1400 6010 2009 1 balance Input 10 kV Т-1 1500/5 Э-704 103391 2007 02 balance Kainda 110/35/10. Input 35 kV Т-1 300/5 АМС-1400 5983 2007 02 balance Input 35 kV Т-2 200/5 АМС-1400 6090 2007 02 balance Input 10 kV Т-1 1000/5 Э-704 56808 2007 01 balance Input 10 kV Т-2 800/5 Э-704 40011 2007 01 balance Беш-Терек 110/35/10 Input 35 kV Т-1 600/5 АМС-1400 5964 2007 01 balance Input 10 kV Т-1 800/5 Э-704 103167 2007 01 balance Ak-Suu 110/35/6 Input 35 kV Т-1 400/5 АМС-1400 6079 2007 02 balance Input 35 kV Т-2 300/5 АМС-1400 5998 2007 02 balance Input 6 kV Т-1 1500/5 Э-704 39940 2008 02 balance Moskovskaya 110/35/10 Input 35 kV Т-1 300/5 АМС-1400 5967 2007 02 balance Input 35 kV Т-2 200/5 АМС-1400 6052 2007 02 balance Input 10 kV Т-1 1000/5 Э-704 57482 2009 2 balance Input 10 kV Т-2 600/5 Э-704 39852 2009 2 balance Sadovaya 110/10 Input 10 kV Т-1 800/5 Э-704 57535 2009 2 balance Input-10 kV Т-2 1000/5 Э-704 26247 2009 2 balance Botbaeva 110/35/10. Input 35 kV Т-1 600/5 АМС-1400 6032 2007 02 balance Input 35 kV Т-2 600/5 АМС-1400 13040 2007 02 balance Input 10 kV Т-1 1500/5 Э-704 41293 2009 01 balance Input 10 kV Т-2 3000/5 Э-704 41329 2009 01 balance Sokuluk 110/10 Input 10 kV Т-1 1000/5 Э-704 41299 2007 02 balance Input 10 kV Т-2 1000/5 Э-704 42075 2007 02 balance Manas 110/35/10. Input 35 kV Т-1 100/5 EA02RAL 1082936 2008 03 balance Input 35 kV Т-2 100/5 АМС-1400 6058 2007 02 balance Input 10 kV Т-1 600/5 Э-704 56633 2008 03 balance Input 10 kV Т-2 600/5 Э-704 39982 2008 03 balance Kun-Tuu 110/35/10 Input 35 kV Т-1 400/5 АМС-1400 5150 2007 02 balance Input 10 kV Т-1 800/5 Э-704 56825 2008 03 balance Kizil-Asker 110/35/6 Input 35 kV Т-1 600/5 СЭТ-4ТМ 2030091 2009 4 balance Input 35 kV Т-2 600/5 СЭТ-4ТМ 2030055 2009 4 balance Input 6 kV Т-1 1500/5 Э-704 39873 2009 4 balance Input 6 kV Т-2 1500/5 Э-704 57408 2009 4 balance N-Yujnaya 10/35/10 Input 35 kV Т-1 300/5 АМС-1400 6055 2007 03 balance Input 35 kV Т-2 300/5 АМС-1400 5933 2007 03 balance Input 10 kV Т-1 1500/5 Э-704 37389 2009 4 balance Input 10 kV Т-2 1500/5 Э-704 41313 2009 4 balance
June 2010 Page 51 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Kostromskaya 110/35/10 Input 35 kV Т-2 600/5 АМС-1410 13043 2007 02 balance Input 10 kV Т-2 1500/5 Э-704 56707 2009 2 balance N-Zapadnaya 110/35/6 Input 35 kV Т-1 600/5 АМС-1400 5144 2007 01 balance Input 35 kV Т-2 600/5 АМС-1400 5951 2007 02 balance Input 6 kV Т-1 3000/5 Э-704 103282 2009 3 balance Input 6 kV Т-2 2000/5 Э-704 39993 2009 3 balance Archa-Beshik 110/10 Input-10 Т-1 1000/5 Э-704 39879 2008 03 balance Ayni 110/10 Input 10 kV Т-1 1500/5 Э-704 39963 2009 01 balance Input 10 kV Т-2 1500/5 Э-704 39975 2009 01 balance Kirgizskaya 110/10 Input 110 kV Т-1 300/5 Э-704 103247 2009 4 balance Input 10 kV Т-1 1500/5 Э-704 27073 2009 4 balance Parkovaya 110/35/10 Input 35 kV Т-1 300/5 ЕА 10RL 1034456 2007 04 balance Input 10 kV Т-1 500/5 ЕА 10RL 1034457 2008 03 Balance Pikovaya 110/6 Input 6 kV Т-1 1500/5 Э-704 39926 2008 01 balance Input 6 kV Т-2 1500/5 Э-704 39920 2008 01 balance Seleksionnaya 110/10 Input 10 kV Т-2 1000/5 Э-704 39872 2008 01 balance Orto-Alish 110/35/10 Input 35 kV Т-1 300/5 АМС-1400 6051 2007 03 balance Input 35 kV Т-2 400/5 АМС-1400 6088 2007 03 balance Input 10 kV Т-1 100/5 Э-704 39857 2009 1 balance Input 10 kV Т-2 1500/5 Э-704 27215 2009 3 balance Jani-Jer110/35/10 Input 35 kV Т-1 200/5 АМС1400 6030 2007 02 balance Input 35 kV Т-2 200/5 АМС1400 5984 2007 02 balance Input 10 kV Т-1 1000/5 Э-704 37215 2009 2 balance Input 10 kV Т-2 1500/5 Э-704 42021 2009 2 balance Berlik 110/35/10 Input 35 kV Т-1 150/5 АМС1400 6009 2008 02 balance Input 35 kV Т-2 200/5 АМС1400 6005 2007 02 balance Input 10 kV Т-2 600/5 Э-704 56830 2009 3 balance Input 10 kV Т-1 600/5 Э-704 41129 2009 3 balance Teplichnaya 110/35/10 Input 35 kV Т-1 600/5 АМС-1400 5153 2007 2 balance Input 35 kV Т-2 600/5 СЭТ-4ТМ 0.3 106070171 2007 04 balance Input 10 kV Т-1 1000/5 Э-704 39856 2007 03 balance Abdikalikova 110/35/6. Input 35 kV Т-1 600/5 АМС-1400 6072 2006 02 balance Input 35 kV Т-2 400/5 ЕА 1082968 2005 04 balance Input 6 kV Т-1 2000/5 АМС-1400 5944 2006 02 balance Input 6 kV Т-2 2000/5 АМС-1400 5990 2006 02 balance Vostochnaya 110/35/6 Input 35 kV Т-1 600/5 АМС-1400 5977 2006 02 balance Input 35 kV Т-2 600/5 АМС-1400 5992 2006 02 balance Input 6 kV Т-1 2000/5 Э-704 39976 2008 02 balance Input 6 kV Т-2 2000/5 Э-704 57569 2008 02 balance Yujnaya 110/35/6 Input 35 kV Т-1 600/5 АМС-1400 6047 2007 01 balance Input 35 kV Т-2 600/5 АМС-1400 6033 2007 04 balance Input 6 kV Т-1 2000/5 Э-704 27278 2009 3 balance Input 6 kV Т-2 2000/5 Э-704 39948 2009 3 balance Molodaya-Gvardiya Input 35 kV Т-1 600/5 СЭТ4ТМ 0.3 106070017 2007 4 balance 110/35/10 Input 35 kV Т-2 400/5 АМС-1400 6034 2007 03 balance Input 10 kV Т-1 1500/5 СЭТ4ТМ 0.3 106070170 2008 01 balance Input 10 kV Т-2 1500/5 Э-704 27163 2008 01 balance Karagachevaya Input 35 kV Т-1 400/5 АМС-1400 6075 2007 01 balance 110/35/10/6 Input 35 kV Т-2 600/5 АМС-1400 5980 2006 02 balance Input 10 kV Т-2 1500/5 Э-704 56799 2009 4 balance Input 6 kV Т-1 1500/5 Э-704 39945 2009 3 balance Lermontova 110/35/10 Input 10 kV Т-1 1000/5 Э-704 27074 2008 01 balance Input 10 kV Т-2 1000/5 Э-704 27240 2008 01 balance Atabaeva 110/35/6. Input 35 kV Т-1 400/5 ЦЭ6823 64465 2007 2 balance Input 35 kV Т-2 400/5 ЦЭ6823 66208 2007 2 balance Input 6 kV Т-1 3000/5 Э704 39993 2008 03 balance. Input 6 kV Т-2 3000/5 Э704 26269 2009 3 balance. Promishlennaya 110/35/6 Input 35 kV Т-1 600/5 ЦЭ6823 66211 2007 2 balance Input 35 kV Т-2 600/5 ЦЭ6823 65526 2006 01 balance
June 2010 Page 52 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Input 6 kV Т-1 2000/5 Э-704 41320 2007 03 balance Input 6 kV Т-2 2000/5 Э-704 37205 2007 02 balance Alamedin 110/35/10 Input 35 kV Т-1 600/5 АМС1400 6092 2006 02 balance Input 35 kV Т-2 600/5 АМС1400 6070 2006 02 balance Input 10 kV Т-2 1500/5 Э-704 0.00009 2008 01 balance Input 10 kV Т-1 1500/5 Э-704 56883 2008 02 balance Kant 110/35/10 Input 35 kV Т1 400/5 А1800 6874627 2007 02 balance Input 35 kV Т2 400/5 А1800 6874629 2007 02 balance Input 10 kV Т1 1500/5 А1800 6874630 2007 02 balance Input 10 kV Т2 800/5 А1800 5874738 2008 02 balance Ivanovka 110/35/10 Input 35 kV Т-1 400/5 АМС-1400 5148 2007 02 balance Input 35 kV Т-2 300/5 АМС-1400 13037 2007 02 balance Input 10 kV Т-1 1000/5 Э-704 39921 2009 2 balance Input 10 kV Т-2 1000/5 Э-704 56892 2009 2 balance Tokmok 110/10. Input 10 kV Т-2 1500/5 ELA7wb 4441919 2008 03 balance Input 10 kV Т-1 1500/5 ELA7wb 4441920 2008 03 balance Karoy 110/35/10 Input 35 kV Т-1 200/5 АМС-1400 5159 2007 02 balance Input 10 kV Т-1 600/5 Э-704 39866 2007 01 balance KHP 110/10. Input 10 kV Т-1 1500/5 Э-704 39842 2008 3 balance Input 10 kV Т-2 1500/5 Э-704 39884 2008 3 balance Iskra 110/35/6 Input 35 kV Т-1 200/5 АМС-1400 5171 2007 02 balance Input 35 kV Т-2 200/5 АМС-1400 5191 2007 02 balance Input 6 kV Т-1 1500/5 Э-704 56614 2007 02 balance Input 6 kV Т-2 1500/5 Э-704 103035 2007 01 balance Orlovka-1 110/35/10 Input 35 АТ-1 200/5 СЭТ-4ТМ 2030034 2007 01 balance Input 35 АТ-2 600/5 СЭТ-4ТМ 2030012 2007 04 balance Input 10 kV Т-1 600/5 Э-704 27161 2009 2 balance Input 10 kV Т-2 600/5 Э-704 27262 2009 2 balance Shabdan 110/35/10 Input 10 kV Т-1 400/5 Э-704 42054 2007 01 balance IPVES Ribache-1 110/35/10 Input 35 kV Т-1 150/5 Э-704 27060 2008 03 balance Input 35 kV Т-2 150/5 Э-704 27154 2008 03 balance Input 10 kV Т-1 1500/5 Э-704 39886 2008 03 balance Input 10 kV Т-2 1000/5 Э-704 39850 2008 03 balance Tamga 220/110/10 Input 10 kV Т-1 1000/5 Э-704 35199 2008 04 balance Vostochnaya 110/35/10 Input 35 kV Т-1 600/5 Э 704 40052 2008 4 встр Input 10 kV Т-1 1500/5 Э-704 34842 2008 02 balance Input 10 kV Т-2 1500/5 Э-704 34818 2008 01 balance Pionerskaya 110/10. Input 10 kV Т-1 600/5 Э-704 39930 2008 03 balance Input 10 kV Т-2 В-1 600/5 Э-704 39863 2008 03 balance Input 10 kV Т-2 В-2 600/5 Э-704 39878 2008 03 balance Ulahol 110/10. Input 10 kV Т-1 150/5 Э-704 39844 2008 02 balance Promishlennaya 110/10. Input 10 kV Т-1 1000/5 Э-704 39831 2008 03 balance Input 10 kV Т-2 600/5 Э-704 39935 2008 03 Sari-Kamish 110/10. Input 10 kV Т-2 150/5 Э-704 39944 2008 03 balance Toru-Aygir 110/10. Input 10 kV Т-1 400/5 Э-704 39939 2008 03 balance Bokonbaevo 110/10. Input 10 kV Т-1 400/5 Э-704 39883 2008 04 balance Input 10 kV Т-2 400/5 Э-704 39828 2008 04 balance Ak-Terek 110/10. Input 10 kV Т-1 300/5 Э-704 39832 2008 3 balance Input 6 kV Т-1 800/5 Э-704 35195 2008 04 balance Input 6 kV Т-2 800/5 Э-704 26229 2008 04 balance Toguz-Bulak 110/10. Input 10 kV Т-1 200/5 Э-704 39845 2008 03 balance Barskaun 110/10 Input 10 kV Т-1 400/5 Э-704 34790 2008 04 balance Input 10 kV Т-2 200/5 Э-704 34783 2008 04 balance Ak-Shiyrak 110/10 Input 10 kV Т-1 100/5 Э-704 40033 2009 3 balance Kara-Sai 110/10 Input 10 kV Т-1 150/5 Э-704 39894 2009 3 balance Choktal 110/10 Input 10 kV Т-1 400/5 Э-704 40017 2008 03 balance Jeti-Oguz 110/10. Input 10 kV Т-1 600/5 Э-704 34771 2008 04 balance Prejevalskaya 110/35/10 Input 35 kV Т-1 600/5 Э704 27170 2008 02 balance
June 2010 Page 53 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Input 35 kV Т-2 600/5 Э704 27115 2008 02 balance Input 10 kV Т-3 400/5 Э-704 34832 2008 02 balance Input 6 kV Т-1 2000/5 Э-704 34835 2008 02 balance Input 6 kV Т-2 2000/5 ЦЭ6823 БН64478 2006 01 balance Dolinka 110/10 Input 10 kV Т-1 1000/5 Э-704 39858 2008 03 balance Input 10 kV Т-2 400/5 Э-704 39936 2008 03 balance Cholpon-Ата 110/35/10 Input 10 kV Т-1 1500/5 Э-704 34801 2008 03 balance Input 10 kV Т-2 1500/5 Э-704 34821 2008 03 balance Bosteri 110/35/10 Input 35 kV Т-1 600/5 Э704 26315 2008 03 встр Input 35 kV Т-2 600/5 Э704 27075 2008 03 встр Input 10 kV Т-1 1000/5 Э-704 39848 2008 03 balance Input 10 kV Т-2 1000/5 Э-704 40004 2008 03 balance Komsomol-2 110/35/10 Input 35 kV Т-1 300/5 Э704 27081 2008 03 balance Input 10 kV Т-1 600/5 Э-704 34836 2008 03 balance Grigorievka 110/10 Input 10 kV Т-1 600/5 Э-704 34824 2008 03 balance Input 10 kV Т-2 400/5 Э-704 34791 2008 03 balance Ananevo 110/10 Input 10 kV Т-1 1000/5 Э-704 34763 2008 03 balance Oytal 110/10 Input 10 kV Т-1 150/5 Э-704 34808 2008 03 balance Kurmenti 110/10/6 Input 10 kV Т-1 800/5 Э-704 34743 2008 03 balance Input 6 kV Т-2 800/5 Э-704 40020 2009 3 balance Tyup 110/35/10 Input 35 kV Т-1 150/5 Э704 27166 2008 02 встр Input 35 kV Т_2 150/5 Э704 27123 2008 02 встр Input 10 kV Т-1 600/5 Э-704 34847 2008 02 balance Input 10 kV Т-2 1000/5 Э-704 34799 2008 02 balance Pristan 110/35/10 Input 35 kV Т-1 600/5 Э704 27120 2008 02 встр Input 35 kV Т-2 300/5 Э704 27148 2008 02 встр Input 6 kV Т-1 600/5 Э-704 34784 2008 02 balance Input 6 kV Т-3 300/5 Э-704 34805 2008 02 balance Kun-Batish 110/10 Input 10 kV Т-1 600/5 Э-704 39874 2008 04 balance Pokrovka 110/35/10 Input 35 kV Т-1 150/5 Э704 26315 2008 04 balance Input 35 kV Т-2 150/5 Э704 27075 2008 04 balance Input 10 kV Т-1 600/5 Э-704 34788 2008 04 balance Input 10 kV Т-2 600/5 Э-704 34741 2008 04 balance Naryn-1 110/35/10. Input 35 kV Т-1 600/5 Э-704 103353 2008 1 контр Input 35 kV Т-2 600/5 Э-704 103409 2008 1 контр Input 10 kV Т-1 1500/5 Э-704 103274 2008 1 контр Input 10 kV Т-2 1000/5 Э-704 103371 2008 1 контр Ala-Too 110/35/10 Input 35 kV Т-1 100/5 Э-704 103322 2008 1 контр Input 35 kV Т-2 75/5 Э-704 103318 2008 1 контр Input 10 kV Т-1 800/5 Э-704 56867 2008 2 контр Input 10 kV Т-2 600/5 Э-704 41997 2008 1 контр Input 10 kV Т-3 300/5 Э-704 57653 2008 2 контр Torugart 110/10 Input 10 kV Т-1 100/5 Э-704 27165 2008 2 контр Ugut 110/35/10 Input 35 kV Т-1 300/5 Э-704 27268 2008 1 контр Input 35 kV Т-2 150/5 Э-704 27151 2008 1 контр Input 10 kV Т-1 600/5 Э-704 35198 2008 1 контр Input 10 kV Т-2 600/5 Э-704 34831 2008 1 контр Ala-Buga 110/6 Input 6 kV Т-1 1000/5 Э-704 103410 2008 2 контр Input 6 kV Т-2 1000/5 Э-704 103337 2009 1 контр Jetigen 110/35/10 Input 35 kV Т-1 300/5 Э-704 27155 2008 1 контр Input 35 kV Т-2 300/5 Э-704 27257 2008 1 контр Input 10 kV Т-1 1000/5 Э-704 103175 2009 1 контр Input 10 kV Т-2 1000/5 Э-704 103095 2009 1 контр Jani-Talap 110/35/10 Input 35 kV Т-1 300/5 Э-704 41988 2009 1 контр Input 10 kV 300/5 Э-704 40062 2009 1 контр Sari-Bulak 110/10 Input 10 kV Т-1 150/5 Э-704 35134 2008 2 контр Kara-Kujur 110/10 Input 10 kV Т-1 150/5 Э-704 26243 2008 2 контр Kochkor 110/10 Input 10 kV Т-1 600/5 Э-704 56955 2008 1 контр Input 10 kV Т-2 1000/5 Э-704 39967 2008 1 контр
June 2010 Page 54 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Cholpon 110/35/10 Input 35 kV Т-2 150/5 Э-704 26232 2008 1 контр Input 10 kV Т-1 400/5 Э-704 26241 2008 1 контр Input 10 kV Т-2 600/5 Э-704 27067 2008 1 контр Davlet-Arik 110/10 Input 10 kV Т-1 300/5 Э-704 26216 2009 1 контр
Chaek 110/10 Input 10 kV Т-1 400/5 Э-704 24269 2008 2 контр Input 10 kV Т-2 600/5 Э-704 26239 2008 2 контр Kara-Keche 110/35/10 Input 10 kV Т-1 600/5 Э-704 103346 2009 3 контр Aral 110/6 Input 6 kV Т-1 1000/5 Э-704 35203 2008 1 контр Min-Kush 110/35/6 Input 35 Т-1 50/5, Э-704 27150 2008 1 контр Input 6 kV Т-1 600/5 Э-704 39965 2008 2 контр Input 6 kV Т-2 600/5 Э-704 103410 2005 04 контр TPVES Tuleberdieva. 500/220/10 Input-10 АТ-1 150/5 СЭТ 6010049 2008 1 balance Semetei 220/110/10 Input-110 kV АТ-1 600/1 СЭТ 7020023 2008 1 balance Input-10 АТ-1 1000/5 СЭТ 7020032 2008 1 balance Kirovka 110/35/10 Input 35 kV Т-1 400/5 Э-704 26318 2008 1 balance Input 35 kV Т-2 300/5 Э-704 27156 2008 1 balance Input 10 kV Т-1 1000/5 Э-704 35133 2008 1 balance Input 10 kV Т-2 600/5 Э-704 26186 2008 1 balance Talas 110/35/10 Input 35 kV Т-1 600/5 Э-704 26303 2008 1 balance Input 35 kV Т-2 400/5 Э-704 57525 2006 03 balance Input 10 kV Т-1 1000/5 Э-704 57666 2008 1 balance Input 10 kV Т-2 1000/5 ЦЭ-6823 БN 65530 2008 1 balance Chat-Bazar 110/35/10 Input 35 kV Т-1 400/5 Э-704 26199 2008 1 balance Input 10 kV Т-1 400/5 Э-704 26268 2008 1 balance Pobeda 110/35/10 Input 35 kV Т-1 150/5 Э-704 57657 2008 1 balance Input 35 kV Т-2 200/5 Э-704 353756 2009 3 balance Input 10 kV Т-1 600/5 Э-704 354392 2009 3 balance Input 10 kV Т-2 600/5 Э-704 353838 2009 3 balance Manas 110/10 Input 10 kV Т-1 400/5 Э-704 35176 2007 02 balance Input 10 kV Т-2 400/5 Э-704 34844 2008 1 balance Pokrovka 110/10 Input 10 kV Т-1 400/5 Э-704 57544 2008 1 balance Input 10 kV Т-2 400/5 Э-704 27272 2008 1 balance Kara-Archa 110/10 Input 10 kV Т-1 1000/5 Э-704 34840 2008 1 balance Bala-Sary 110/6 Input 6 kV Т-1 800/5 Э-704 56885 2008 1 balance Aral Input 10 kV Т1 400/5 Э-704 26225 2008 1 balance Ken-Kol 110/10 Input 10 kV Т-1 600/5 Э-704 34810 2008 1 balance Ozgorush 110/10 Input 10 kV Т-1 600/5 Э-704 35109 2008 1 balance Ivano-Allekseevka 110/10 Input 10 kV Т-1 400/5 Э-704 35189 2008 1 balance JPVES Kristal 220/110/10. Input 10 АТ-1 1500/5 Э-704 103481 2009 3 balance Suzak 110/35/10 Input 35 kV Т-1 200/5 Э-704 40061 2008 01 balance Input 10 kV Т-1 1500/5 Э-704 103414 2008 01 balance Tashtemirova 110/10 Input 10 kV Т-1 1500/5 Э-704 34765 2008 01 balance Input 10 kV Т-2 1500/5 Э-704 27168 2008 04 balance Tash-Bulak 110/35/10 Input 35 kV Т1 300/5 Э-704 56801 2009 3 balance Input 10 kV Т-1 1500/5 Э-704 26226 2008 01 balance Mirzajan 110/10 Input 10 kV Т-1 400/5 Э-704 103355 2008 01 balance В-6 kV Т-2 1500/5 Э-704 103152 2009 03 balance Jalal-Abad 110/35/6 Input 35 kV Т1 600/5 Э-704 103364 2008 01 balance Input 35 kV Т3 75/5 Э-704 103256 2008 01 balance Input 35 kV Т4 300/5 Э-704 56705 2008 02 balance Input 6 kV Т-2 I 1500/5 СЭТ-4ТМ03 112069203 2007 03 контр Input 6 kV Т-2 II 1500/5 СЭТ-4ТМ03 111065193 2007 03 контр Barpy 110/10. Input 10 kV Т-2 600/5 Э-704 27175 2008 01 balance Bek-Adab 110/10. Input 10 kV Т-1 1500/5 АМС1400 6062 2006 01 balance Rayonnaya 110/35/10 Input 35 kV Т-1 600/5 АМС1400 5924 2008 01 balance Input 35 kV Т-2 600/5 АМС1400 5989 2008 01 balance
June 2010 Page 55 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Input 10 kV Т-2 600/5 Э-704 0.04131 2008 02 balance Urumbash 110/35/10 Input 35 kV Т-1 200/5 Э-704 5700 2009 02 контр. Input 10 kV Т-1 1500/5 Э-704 0.03986 2008 1 balance Teplichnaya 110/35/10 Input 35 kV Т-1 600/5 Э-704 103420 2008 01 balance Input 35 kV Т-2 600/5 Э-704 103381 2008 01 balance Input 10 kV Т-1 1000/5 Э-704 39859 2008 02 balance Bazar-Korgon 110/35/10 Input 35 kV Т-1 300/5 Э-704 40008 2008 2 balance Input 35 kV Т-2 300/5 Э-704 27235 2008 2 balance Input 10 kV Т-1 600/5 Э-704 34750 2008 2 balance Input 10 kV Т-2 1500/5 Э-704 56995 2009 2 balance Izbaskent 110/35/6 Input 35 kV Т-1 150/5 Э-704 35169 2009 2 balance Input 35 kV Т-2 300/5 Э-704 42023 2009 2 balance Input 6 kV Т-1 1000/5 АМС-1400 5157 2007 1 balance Input 6 kV Т-2 1500/5 АМС-1400 6083 2008 2 balance Yug 110/35/6 Input 35 kV Т-1 300/5 Э-704 57476 2008 01 balance Input 35 kV Т-2 600/5 Э-704 37255 2008 01 balance Input 6 kV Т-1 1500/5 Э-704 37243 2008 2 balance Input 6 kV Т-2 3000/5 Э-704 103482 2008,02 balance Kok-Tash 110/6 Input 6 kV Т-1 600/5 Э-704 37243 2008 04 balance Ak-Korgon 110/10. Input 10 kV Т-1 600/5 Э-704 56656 2009 3 balance Shamaldi-Say 110/35/6 Input 35 kV Т-1 300/5 Э-704 0.035076 2008 2 balance Input 35 kV Т-2 300/5 Э-704 0.026195 2008,02 balance Input 6 kV Т-1 1000/5 Э-704 42032 2009 3 balance Input 6 kV Т-2 1500/5 Э-704 56577 2009 3 balance Tash-Komur 110/35/6 Input 35 kV Т-1 100/5 Э-704 56593 2009 3 balance Input 35 kV Т-2 100/5 Э-704 56686 2009 3 balance Input 6 kV Т-1 1000/5 Э-704 57489 2009 3 balance Input 6 kV Т-2 1500/5 Э-704 103152 2009 2 balance Karavan 110/35/10 Input 35 kV Т-1 200/5 Э-704 40037 2008 4 balance Input 35 kV Т-2 300/5 Э-704 0.02624 2008,2 balance Input 10 kV Т-1 200/5 Э-704 103352 2008 4 balance Input 10 kV Т-2 300/5 Э-704 26309 2008 4 balance Malkova 110/6. Input 6 kV Т-1 2000/5 Э-704 56860 2009 2 balance Ala-Buka 110/35/6 Input 10 kV Т-1 1000/5 Э-704 37260 2008 4 balance Input 10 kV Т-2 1000/5 Э-704 41324 2008 4 balance Shekaftar 110/35/6 Input 35 kV Т-1 200/5 АМС1400 6097 2007 02 balance Input 6 kV Т-1 200/5 АМС1400 5943 2007 02 balance Gorodok 110/6. Input 6 kV Т-1 3000/5 Э-704 103176 2005.04 balance Gorodok 110/6 Input 6 kV Т-2 3000/5 Э-704 0.026237 2008,02 balance Input 6 kV Т-1 1500/5 Э-704 103191 2009 4 balance Kainda 110/6 Input 6 kV Т-2 1500/5 Э-704 103468 2009 4 balance Kara-Kul 110/35/6 Input 35 kV Т-2 75/5 Э-704 35211 2008 02 balance Input 6 kV Т-2 1500/5 Э-704 56945 2008 02 balance Kara-Suu 110/6/6 Input 6 kV Т-1 3000/5 Э-704 103157 2009 2 balance Input 6 kV Т-2 3000/5 Э-704 42001 2009 2 balance Abasbekova 110/10 Input 10 kV Т-1 300/5 Э-704 57675 2009 3 balance Input 10 kV Т-2 300/5 Э-704 41380 2008 02 balance Kabilbekova 110/35/6 В-35 Т-2 300/5 Э-704 39809 2009 2 balance В-10 Т-2 600/5 Э-703 27138 2008 03 balance Uch-Terek 110/35/10. В-35 kV Т-1 600/5 Э-704 27180 2008 04 balance Input 10 kV Т-1 600/5 Э-704 42057 2009 2 balance Toktogul 110/35/10 Input 35 kV Т-1 150/5 Э-704 56579 2009 2 balance Input 10 kV Т-1 1000/5 Э-704 103397 2009 2 balance Kozubekova 110/35/10 Input 10 kV Т-1 1500/5 Э-704 0.026291 2008,02 balance Nijnaya 110/10/6. Input 6 kV Т-1 1000/5 Э-704 56539 2005.01 balance Padish-Ata 110/10/6. В-10 Т-1 200/5 Э-704 103009 2005 04 balance Jiyde 110/10. Input 10 kV 600/5 Э-704 57398 2008,02 OshPVES Alay-220 220/110/10. Input 10 АТ-1 1500/5 Э-704 103331 2007 02 balance
June 2010 Page 56 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Center 110/35/10 Input-35 Т-1 400/5 АМС1400 6103 2008 01 balance Input 6 Т-1 1500/5 Э-704 103244 2010 1 balance Mangit 110/35/10 Input 35 kV Т-1 600/5 Э-704 57472 2009 2 встр Input 10 Т-2(СВ-10) 300/5 Э-704 56942 2008 4 balance Uchar 110/6. Input 6 Т-1 1500/5 Э-704 56721 2009 2 balance Besh-Moynok 110/10 Input 10 Т-2 150/5 Э-704 103263 2009 2 balance Osh-6 110/35/10 Input 35 kV Т-1 300/5 Э-704 39928 2007 04 встр Input 35 kV Т-2 300/5 Э-704 26285 2007 04 встр Input 10 kV Т-1 1500/5 Э-704 26196 2009 3 balance Input 10 kV Т-2 1500/5 Э-704 103116 2009 3 balance Pamirskaya 110/35/10 Input 35 kV Т-1 300/5 Э-704 103029 2008 1 встр Input 35 kV Т-2 300/5 Э-704 103193 2008 1 встр Input 10 kV Т-1 1500/5 Э-704 56810 2010 1 balance Input 10 kV Т-1 1500/5 Э-704 56810 2010 1 balance Tuleyken 110/35/10 Input 35 kV Т-1 150/5 Э-704 27095 2007 04 встр Input 10 Т-1 800/5 Э-704 56621 2005 02 balance Anar 110/10/6 Input 10 kV Т-1 600/5 Э-704 26215 2008 3 balance Input 6 kV Т-2 1000/5 Э-704 56805 2009 2 balance Karatay 110/35/10 Input 35 kV Т-1 200/5 Э-704 37247 2009 2 balance Input 35 kV Т-2 300/5 Э-704 56620 2009 2 встр Input 10 kV Т-1 800/5 Э-704 27140 2007 02 balance Input 10 kV Т-2 800/5 АМС1400 5973 2007 04 balance Gulcha 110/35/10 Input 10 kV Т-1 600/5 Э-704 103036 2007 02 balance Input 10 kV Т-2 600/5 Э-704 34782 2007 02 balance Input 35 kV Т-1 200/5 н.у встр Input 35 kV Т-2 300/5 н.у встр Sofi-Korgon 110/10 Input 10 kV Т-1 150/5 Э-704 103344 2007 02 balance Uch-Dobo 110/10 Input 10 kV Т-1 150/5 Э-704 57565 2009 3 balance Sary-Tash 110/35/10 Input 35 kV Т-1 600/5 Э-704 103341 2007 02 встр Input 35 kV Т-2 150/5 Э-704 26219 2008 02 встр Input 10 kV Т-1 75/5 Э-704 35112 2007 02 balance Input 10 kV Т-2 400/5 Э-704 26223 2007 02 balance Kashgar-Kishlak 110/10 Input 10 kV Т-1 600/5 Э-704 40051 2005 01 balance Input 10 kV Т-2 600/5 Э-704 37238 2005 01 balance Tabachnaya 110/10 Input 10 Т-1 600/5 Э-704 56999 2008 4 balance Kara-Suu 110/35/10/6 Input 35 kV Т-2 600/5 н.у встр Input 10 kV Т-1 1000/5 Э-704 41979 2005 01 balance Input 6 kV Т-1 1500/5 Э-704 37258 2009 3 balance Input 6 kV Т-2 2000/5 Э-704 42001 2009 3 balance Kara-Shoro 110/35/10 Input 35 kV Т-1 200/5 Э-704 103165 2007 02 встр Input 10 kV Т-1 800/5 Э-704 103184 2007 02 balance Tashirova 110/10 Input 10 kV Т-1 600/5 Э-704 0.027154 2008.01 balance Naukat 110/35/10 Input 35 kV Т-1 300/5 Э-704 26223 2008 01 встр Input 35 kV Т-2 300/5 Э-704 35072 2008 01 встр Input 10 kV Т-3-1 800/5 Э-704 103338 2007 03 balance Input 10 kV Т-3-2 600/5 Э-704 103011 2007 03 balance Input 10 Т-2 600/5 Э-704 26310 2009 2 balance Madaniyat 110/10 Input 10 kV Т-1 1500/5 Э-704 103312 2007 02 balance Kok-Jar 110/35/10 Input 35 kV Т-1 75/5 Э-704 42093 2009 1 встр Input 35 kV Т-2 75/5 Э-704 103333 2009 1 встр Input 10 kV Т-1 600/5 Э-704 103375 2007 01 balance Input 10 kV Т-2 600/5 Э-704 56899 2005 02 balance Jin-Jigan 110/35/6 Input 35 kV Т-1 150/5 н.у н.у н.у встр Input 6 kV Т-1 1000/5 Э-704 35020 2008 01 balance Input 6 kV Т-2 1000/5 Э-704 103324 2007 04 balance Salieva110/10 Input 10 kV Т-1 600/5 Э-704 39851 2008 01 balance Kizil-Kiya 110/35/6 Input 35 kV Т-1 200/5 Э-704 34776 2008 01 встр Input 35 kV Т-2 200/5 Э-704 27273 2008 01 встр Input 6 kV Т-1 1000/5 Э-704 103377 2007 01 balance
June 2010 Page 57 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Connection Point CT Type Factory Nº Year Purpose Ratio Input 6 kV Т-2 1000/5 Э-704 27114 2008 01 balance Kizil-Kiya2 110/35/6 Input 35 kV Т-2 600/5 Э-704 26258 2008 01 встр Input 6 kV Т-1 800/5 Э-704 26297 2007 04 balance Input 6 kV Т-2 1500/5 Э-704 35103 2008 02 balance Metlaurgicheskaya Input 35 kV Т-1 600/5 Э-704 27245 2007 03 встр 110/35/6. Input 35 kV Т-2 600/5 Э-704 27210 2007 03 встр Input 6 kV Т-1 3000/5 АМС1400 6042 2009 2 balance Input 6 kV Т-2 3000/5 Э-704 26272 2007 03 balance Kadamjay 110/35/10 Input 35 kV Т-1 200/5 Э-704 26260 2008 01 встр Input 35 kV Т-2 200/5 Э-704 27265 2008 01 встр Input 6 kV Т-1 1000/5 СЭТ-4ТМ 2030128 2006 02 balance Input 6 kV Т-2 1500/5 СЭТ-4ТМ 2030036 2007 02 balance Arka110/35/6 Input 6 kV Т-1 600/5 AMC-1400 13045 2007 4 balance Celinnaya 110/6 Input 6 kV Т-1 300/5 AMC-1400 5988 2007.04 конт Morskaya 110/6 Input 6 kV Т-1 400/5 AMC-1400 13048 2008 01 balance Batken 110/35/10 Input 35 kV Т-1 600/1 СЭТ-4ТМ 1030014 2003 02 встр Input 35 kV Т-2 600/1 СЭТ-4ТМ 2030027 2007 01 встр Input 10 kV Т-1 200/1 СЭТ-4ТМ 2030030 2007 01 balance Input 10 kV Т-2 1000/1 СЭТ-4ТМ 2030001 2007 01 balance Centralnaya 110/35/6 Input 35 kV Т-1 300/5 Э-704 37249 2009 1 встр Input 35 kV Т-2 400/5 Э-704 40039 2009 1 встр Input 6 kV Т-1 1500/5 Э-704 39808 2007 02 balance Input 6 kV Т-2 1500/5 Э-704 0.039942 2008.01 balance Samat 110/35/10 Input 35 kV Т-1 300/5 Э-704 57513 2005 03 встр Input 35 kV Т-2 300/5 Э-704 57530 2005 03 встр Input 10 kV Т-1 600/5 Э-704 37195 2007 04 balance Input 10 kV Т-2 600/5 Э-704 26244 2007 04 balance Uzgen 110/35/10 Input 35 kV Т-1 200/5 Э-704 27099 2008 03 встр Input 35 kV Т-2 300/5 Э-704 57585 2008 03 встр Input 10 kV Т-1 1500/5 Э-704 57528 2008 02 balance Input 10 kV Т-2 1500/5 Э-704 57432 2005 02 balance Kara-Kulja 110/35/10 Input 35 kV Т-1 200/5 Э-704 35187 2008 03 встр Input 35 kV Т-2 200/5 Э-704 56928 2005 02 Input 10 kV Т-1 1500/5 Э-704 40024 2008 03 balance Input 10 kV Т-2 600/5 Э-704 34841 2008 03 Madi 110/6. Input 6 kV Т-1 400/5 Э-704 103208 2009 2 balance Tepe-Korgon 110/10 Input 10 kV Т-1 400/5 Э-704 40042 2005 01 balance Input 10 kV Т-2 400/5 Э-704 56553 2009 4 balance Aygul-Tash 220/110/10. Input 10 kV АТ-1 1250/1 СЭТ-4ТМ 2030014 2007 02 balance Input 10 kV АТ-2 1250/1 СЭТ-4ТМ 2030011 2007 01 balance
June 2010 Page 58 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Appendix 6 International Transmission Lines
In the north part of the Country, interconnection of the Kyrgyz power system with Kazakhstan power system is through “Glavnaya”, “Frunzenskaya”, “Bistrovka”, “Jani-Jer”, “Ivanovka”, “Kara-Archa”, “Semetei” substations via 500 kV, 220 kV, 110 kV and 35 kV transmission lines. Details are as follows:
Substation Frunzenskaya 500/220/10 kV: Transmission Line 500 kV «Frunzenskaya - Almaty» (dispatch name - Л514) Transmission Line Transmission Line 500 kV «Frunzenskaya - Jambil» (Л515) Transmission Line 220 kV «Frunzenskaya - JAMBIL GRES» (ЛДФ)
Substation Glavnaya 220/110/10 kV: Transmission Line 220 kV «Glavnaya - Chu» (LGCH) Transmission Line 220 kV «Glavnaya - Almaty» (LAG) Transmission Line 110 kV «Glavnaya - Georgievka»
Substation Bistrovka 220/110/10 kV: Transmission Line 220 kV «Bistrovka- Zapadnaya» (LBZ)
Substation Ivanovka 110/35/10 kV: Transmission Line 35 kV «Ivanovka - Trudovik»
Substation Jani-Jer 110/35/10 kV: Transmission Line 110 kV «Jani-Jer- Blagoveshenka»
Substation Semetei 220/110/10 kV: Transmission Line 110 kV «Semetei- Jambil»
Substation Kara-Archa 110/10 kV: Transmission Line 110 kV Jambil L-117 "JES" Taraz city L-128 GRES.
In the south, the Kyrgyz power system is interconnected with the power systems of Uzbekistan and Tajikistan thru “Kristal”, “Oktyabrskaya”, “Jalalabat”, “Izbaskent”, “Shekaftar”, “Kara-Suu”, “Uzlovaya”, “Alay”, “Batken”, “Samat”, “Aygul-Tash” and “Torugart” substations as follows:.
Substation Kristal 220/110/10 kV: Transmission Line 220 kV «Kristal - Kizil-Rabat» Transmission Line 220 kV «Kristal - Yulduz» Transmission Line 220 kV «Kristal - Sardor»
Substation Oktyabrskaya 220/110/10 kV: Transmission Line 220 kV «Oktyabrskaya - Lochin, right» Transmission Line 220 kV «Oktyabrskaya - Lochin, left» Transmission Line 220 kV «Oktyabrskaya - Fazilman» Transmission Line 220 kV «Oktyabrskaya - Foton»
Substation Jalal-Abad 110/35/10/6 kV: Transmission Line 110 kV «Jalalabat - Andijon. Hydro Power Station»
Substation Izbaskent 110/35/6 kV: Transmission Line 35 kV «Izbaskent -Коkon-Kish-к»
Substation Shekaftar 110/35/6 kV: Transmission Line 35 kV «Shekaftar - Abadan» Transmission Line 6 kV «Shekaftar- 1-May»
Substation Uzlovaya 220/110/10 kV: Transmission Line 220 kV «Uzlovaya - Lochin-1» Transmission Line 220 kV «Uzlovaya - Lochin-2» June 2010 Page 59 TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
Substation Alay-220 220/110/10 kV: Transmission Line 220 kV «Alay - Sokin-1» Transmission Line 220 kV «Alay - Sokin-2» Transmission Line 110 kV «Alay - Kuv.GRES-1» Transmission Line 110 kV «Alay - Kuv.GRES-2»
Substation Kara-Suu 110/35/10/6 kV: Transmission Line 110 kV «Kara-Suu - Кemp.-Ravat» Transmission Line 110 kV «Kara-Suu - Andijan Hydro Power Station»
Substation Batken 110/35/10 kV: Transmission Line 110 kV «Batken - Zumrad (Isfara) »
Substation Samat 110/35/10 kV: Transmission Line 110 kV «Samat - Proletarskaya» «Samat - Fider Kurgancha».
Substation Aygul-Tash 220/110/10 kV: Transmission Line 220 kV «Aygul-Tash - Kanibadam» Transmission Line 110 kV «Aygul-Tash - Zumrad».
Substation Torugart 110/10 kV: КНР.
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Appendix 7 Digital Wholesale Meters
A. Typical Manufacturer’s Information
Source: http://www.zaotk.ru /
B. Manufacturer’s Specifications for E-704 Meter Three-phase one-rate electric meter; rated voltage 3х100 V with RS interface. Nominal (maximal) current 5 (7.5) Frequency - 50 Hz ±5 % Sensitivity 10 мА (4,4 Вт). Transformer inclusion, the three-prowater liquid crystal indicator Telemetering output with transfer number 16,000 of ¿¼»/kWh. Temperature range:-25 ºC up to 55 ºC
C. Manufacturer’s Specifications for SET-4ТМ.03М, SET-4ТМ.02.2М Meters Purpose and Field of Application The meters are designed for measuring and multi-tariff accounting of active and reactive energy (also taking into account losses), for keeping of power profile arrays with programmable integration time (also taking into account losses), registration of maximum power value, measurement of three-phase network parameters and power-quality parameters, with either current transformer and voltage transformer connection or direct voltage connection.
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The meters can be used for commercial and technical accounting of electrical energy in domestic households and small-motor sectors, in production enterprises and electric energy systems, can register power flows in electric energy systems and intersystem overflows.
The meters are available in various configurations which differ in accuracy class, nominal voltage and number of interfaces. SET-4ТМ.03М meters have three communication interfaces, SET-4ТМ.02М meters have two communication interfaces and are designed to be used both independently and as a component of automated systems for commercial energy accounting and as a component of automated dispatch control systems.
The meters can be configured to operate in unidirectional mode (ignoring current direction in each phase of the network) and using three metering channels will register:
Active energy of the forward and reverse direction as active energy of the forward direction (metering in magnitude); Reactive energy in the first and third quadrants as reactive energy of the forward direction (inductive load); Reactive energy in the fourth and second quadrants as reactive energy of the reverse direction (capacity load).
Technical Features Digital signal processing Extended voltage range 3×(57,7-115)/(100-200) or 3×(120-230)/(208-400) V; 50 ±2,5 Hz Increased reliability (no aluminium electrolytic capacitors) Alternate 100-265 V AC or DC power supply Independent communication interfaces which are of equal priority: two RS-485 interfaces and one optical interface of SET-4ТМ.03М meter and one RS-485 interface and one optical interface of SET- 4ТМ.02М meter ModBus-similar, SET-4ТМ.02-compatible exchange protocol with the extended addressing possibility Four insulated configurable test outputs Two digital configurable inputs Built-in real-time clock with high accuracy movement (much better than 0,5 sec/day) Testing in accordance with IEC 62052-11.
Functional Capabilities The meters keep records of the measured energy (rated and not rated) taking into account losses in electric power line and power transformer (active, reactive, of the forward and reverse direction and four-quadrant reactive energy - eight channels):
In total from the date of meter resetting (with accrual accounting) For the current and preceding calendar day As at the beginning of the current day and preceding calendar day For every preceding calendar day with the depth of up to 30 days As at the beginning of every preceding calendar day with the depth of up to 30 days For the current month and for 12 preceding calendar months As at the beginning of the current month and 12 preceding calendar months For the current and preceding calendar year As at the beginning of the current year and preceding calendar year.
Tariff options include:
Eight tariffs (Т1-Т8) Eight day types (Monday, Tuesday, Wednesday, Thursday, Friday, Saturday, Sunday, holiday), Twelve seasons (for every month of the year) Tariff zone increment is 10 minutes, tariff zones interface per day is up to 144 intervals Holiday schedule and list of postponed days are used.
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Three independent profile arrays of power (active and reactive in both forward and reverse direction, also taking into account losses) are kept:
Integration time from 1 tо 60 minutes (ignoring losses) Integration time from 1 tо 30 minutes (taking into account losses) Storing depth of each array with integration time of 30 minutes is 113 days.
Registration of maximum demand for power in the mornings and in the evenings as per each profile array of power (active, reactive, of the forward and reverse direction) with the use of twelve-seasons demand schedule:
Interval demand (time interval between meter resets) Month demand (for the current month and 12 preceding calendar months).
Measurement of electric energy parameters and auxiliary parameters in each phase and in sum of phases includes:
Active, reactive and total power Active and reactive power losses in electric power line and power transformer Power factor Network frequency Phase voltage, voltage between phases and positive-sequence voltage Waveform distortion factor of phase voltage and voltage between phases Zero-plus-negative-phase-sequence voltage unbalance factor Current and current waveform distortion factor Zero-plus-negative-phase-sequence current unbalance factor Current time, date and temperature.
Measurement of power-quality parameters includes:
Steady-state deviation of phase voltage, voltage between phases, positive-sequence voltage and network frequency with standardised metrological characteristics Waveform distortion factor of phase voltage and voltage between phases Zero-plus-negative-phase-sequence voltage unbalance factor with un-standardised metrological characteristics Automatic control and registration of the time when network parameters fall outside the fixed limits.
The meters have four independent test outputs; each output can be configured to form:
Telemetry pulses of one of the channels for energy metering (active, reactive, energy of the forward and reverse direction and four-quadrant reactive energy, also taking into account losses) Signals about programmed power threshold exceeding Supervisory control signals Control signal of accuracy movement of the clock.
The meters have two digital inputs; each of them can be configured:
As an input to control telemetry modes (А or В, only input 1) from external voltage As an inverting input to count leading edge and/or trailing edge pulses of external sensors and to register them in records (analogous to measured energy records) As a remote signalling input to keep a log concerning changed input status.
The electricity meters keep event logs, power-quality logs, logs concerning power threshold exceeding and a status log. The electricity meters provide the possibility to programme, reprogramme, control and read parameters and data through RS-485 communication interfaces or optical port.
Technical Data Parameter Value Nominal (maximum) current, А 1(2) or 5(10)
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Parameter Value
Sensitivity current, mА 0,001 Inom Nominal measured voltage, V 3 x (57,7-115)/(100-200) or 3 х (120-230)/(208-400)
Working range of measured voltages, V from 0,8 Unom tо 1,15 Unom Nominal voltage of alternate power supply, V 230 (constant or alternating current) Working voltage range of alternate power supply, V from 100 tо 265 (constant or alternating current) Nominal network frequency, Hz 50 Working range of network frequencies, Hz from 47.5 tо 52.5 Accuracy class when measuring in the forward and reverse direction: active energy 0.2 S or 0.5 S reactive energy 0.5 or 1.0 Maximum permissible main relative error when measuring, %:
voltage (phase voltage, voltage between phases, ±0,4 % in the range from 0,8 Unom tо 1,15 Unom positive-sequence voltage and average values)
current ±0,4% when Inom ≤I ≤Imax
when 0,01 Inom ≤I ≤Inom frequency ±0,05 in the range from 47,5 tо 52,5 Hz active power losses in the line and transformer
reactive power losses in the line and transformer
Accuracy movement of built-in clock at normal conditions better than ±0,5 when the meter is switched on/off, sec/day Active (total) power consumed by each parallel voltage circuit, not more than, W (VА)
Unom =3x(57,7-115)/(100-200)V 1.0 (1.5)
Unom =3x(120-230)/(208-400)V 1.5 (2.5) Total power consumed by each serial circuit, VА not more than 0.1 Consumption current of alternate power source within voltage range from 100 tо 265 V, mА: from constant-current source 30-15 from alternating-current source 45-28 Number of indicated liquid-crystal display digits 8 Rate of data exchange, bit/sec: through optical port 9600 via RS-485 interfaces 38,400, 19,200, 9,600, 4,800, 2,400, 1,200, 600 Range of the meter constant values pulses/(kWh), from 1,250 tо 800,000 pulses/(kVArh) Data saving when switching off the power supply, years: of information more than 40 of inner clock not less than 10 (lithium battery supply) Data protection Two access levels and memory hardware protection of metrological factors Self-diagnostics Iterative, incessant Working and service conditions: ambient air temperature, °С from -40 tо +60 relative humidity, % 90 % at 30 °С pressure, kPa (mm of mercury) from 70 tо 106,7 (from 537 tо 800) Recalibration interval, years 12 Guaranteed service life, months 36 Average error-free running time, h 140,000 Average service life, years 30 Mass, kg 1,6 Measurements, mm 330 х 170 х 80,2
D. Elster-Metronica and Energosfera At the present time in Kyrgyzstan, two certified system of commercial electric power metering is used.
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Alpha Centre - production "Elster-Metronica" Moscow, "Energosfera" - the production of "ProSoft-system" Ekaterinburg.
Elster Metronica - the leading enterprise in Russia and Europe for the production of equipment for automated electricity metering systems. Metronica Elster (formerly ABB VEI Metronica) - Russian company, a member of the group Elster, which unites the world's largest manufacturers of devices and systems for metering of electricity, heat, water and gas. Main activities: - System integration and implementation of AIMS CSE for ORE "turnkey". - Development of software for Alpha Centre metering. - Design / manufacture / delivery of multi-electricity meters Alpha series and metering equipment.
Elster Metronica has the technology, expertise and experience to create a large geographically distributed projects AMR. System Solutions Elster Metronica used by enterprises to operate in the wholesale and competitive electricity market. The company offers comprehensive automation solutions for electricity metering "turnkey" based on the latest hardware and software, and also supplies components for metering systems integrators.
Elster Metronica has unique experience in implementing large projects AMR for JSC"UES FGC", JSC "RZD", Rosenergoatom, JSC-Energo, power systems of Armenia and Georgia, power plants, oil and metallurgical companies.
All equipment and system solutions of Elster Metronica satisfy the requirements of Russian standard called GOST international standards and have certificates authorizing their use in Russia and CIS countries. The company is successfully working and developing since 1994, supplying its products to Russia, Ukraine, Belarus, Kazakhstan, CIS, Baltic and CIS countries, including Poland, Czech Republic, Germany, Italy, Finland, Norway, Spain, Turkey and Mongolia. The company Elster Metronica in Moscow implemented quality system certified to ISO 9001.
Software for Energosfera
PC Energosfera ® is designed to create the metering systems of various types:
Automated information-measuring systems of commercial electric power metering (AIMS CSE) Automated systems of technical metering of electricity (ASTUEl) Automated systems for commercial electricity metering (AMR) Integrated management of energy systems (KSUER).
Energosfera ® consists of a series of software modules and performs the following functions:
Parameter RTU Automatic collection of data from RTU and metering system Information exchange between the components of the system Administration database AIMS Operational control of the incoming data, the fixation of abnormal conditions in accordance with established criteria Formation of historical data in the archives of various discrete displaying data in the form of mimic diagrams, tables, bar charts Creation and maintenance of reporting forms, withdrawal data to the printer Relaying data, organize data exchange with adjacent systems Output data (signals) for control of technological equipment Remote control operating modes of electrical, heating and gas networks, power equipment Calculation of payment for the consumed energy for multi-rate system and the formation of metering documents Calculation of cost per unit of energy.
Although requested several times by Aecom NZ, Elster declined to provide budgetary prices for the ProjeCTs metering component.
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Appendix 8 Details of Substation Upgrade Equipment
A. Wholesale Metering Component
Substation 500 kV 220 kV 110 kV 35 kV 10 kV & 6 kV CBs CTs VTs CBs CTs VTs CBs CTs VTs CTs VTs CBs CTs VTs (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) Quantities
Metering Upgrade Frunzenskaya 3 3 7 7 Glavnaya 3 2 2 2 Bistrovka 2 2 Kristal 2 Octoberskaya 3 2 Uzlovaya 2 2 Jani-Jer 1 1 MV CT&VT Replacement 17 11 39 20 Subtotal 0 3 3 0 17 17 0 3 3 17 11 0 39 20
Substation TL Transformer Ratio N° of Windings Accuracy Burden VA ChuPVES Transmission Line 500 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 Shu (Л514) Р 60 Transmission Line 500 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 Jambyl (Л515) Р 60 0,2S 20 0.5 20 Frunzenskaya 500 kV Л 509 2000/1 5 P 60 P 60 Р 60 Transmission Line 220 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 JGRES (ЛДФ) Р 60 0,2S 20 0.5 20 ОВ 220 kV 2000/1 5 P 60 P 60 Р 60 Transmission Line 220 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 Almaty(ЛАГ) Р 60 Transmission Line 220 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 Shu (ЛГЧ) Р 60 0,2S 20 0.5 20 Glavnaya 220 kV ОВ 220 kV 1000/1 5 P 60 P 60 Р 60 Transmission Line 110 kV 0,2S 20 0.5 20 200/5 5 P 60 P 60 Georgievka Р 60 0,2S 20 0.5 20 ОВ 110 kV 750/1 5 P 60 P 60 Р 60 Transmission Line 220 kV 0,2S 20 0.5 20 1000/5 5 P 60 P 60 Zapadnaya (ЛБЗ) Р 60 Bistrovka 220 kV 0,2S 20 0.5 20 ОВ 220 kV 1000/5 5 P 60 P 60 Р 60 Transmission Line 110 kV 0,2S 20 0.5 20 Djani-Jer 110 200/5 5 P 60 P 60 Blagoveshenka Р 60
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Substation TL Transformer Ratio N° of Windings Accuracy Burden VA OshPVES Transmission Line 220 kV 0,2S 20 0.5 20 300/1 5 P 60 P 60 Foton Р 60 Oktyabrskaya 220 Transmission Line 220 kV 0,2S 20 0.5 20 300/1 5 P 60 P 60 Fazilman Р 60 Transmission Line 220 kV 0,2S 20 0.5 20 2000/1 5 P 60 P 60 Kizil-Ravat Р 60 Transmission Line 220 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 Yulduz Р 60 Kristall 220 Transmission Line 220 kV 0,2S 20 0.5 20 1000/1 5 P 60 P 60 Sardor Р 60 0,2S 20 0.5 20 ОВ 220 kV 2000/1 5 P 60 P 60 Р 60 OshPVES Transmission Line 220 kV 0,2S 20 0.5 20 1000/5 5 P 60 P 60 Lochin-1 Р 60 Uzlovaya 220 Transmission Line 220 kV 0,2S 20 0.5 20 1000/5 5 P 60 P 60 Lochin-2 Р 60
B. Substation Upgrade Component
Substation 500 kV 220 kV 110 kV 35 kV 10 kV & 6 kV CBs CTs VTs CBs CTs VTs CBs CTs VTs CTs VTs CBs CTs VTs (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) (set of 3) Quantities Substation Rehabilitation Frunzenskaya 6 1 0 9 Kara-Balta 8 8 Kristal 10 10 Glavnaya 11 Octoberskaya 2 Others 72 72 150 Subtotal 6 1 0 29 18 0 83 72 0 0 0 150 0 0
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Appendix 9 Fibre Optic Network
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Appendix 10 Schedule of Transmission Lines
Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio 500kV 500kV Toktogulskaya HPP Tuleberdieva 500 130.60 27.95 1 Toktogulskaya HPP Tuleberdieva Frunzenskaya 500 76.00 27.70 1 Tuleberdieva TOTAL 500kV: 0 0 0.0 220kV 220kV Frunzenskaya Kara-Balta 1 220 68.30 58.68 1 Separate route 68.3 0.5 Frunzenskaya Frunzenskaya Kara-Balta 2 220 63.20 1.35 1 Separate route Frunzenskaya *Earth wire only on Frunzenskaya Ala-Archa (T-junction) 220 88.85 88* 1 Frunzenskaya sections into substations Frunzenskaya Ala-Archa 220 108.80 108* 108.8 0.5 Frunzenskaya Ala-Archa Ala-Archa (T-junction) 220 18.60 18* 18.6 Ala-Archa Ala-Archa (T-junction) Bistrovka 220 113.65 113* 1 113.7 0.5 Ala-Archa (T-junction) Glavnaya Kara-Balta 220 90.50 1 90.5 0.5 Glavnaya Glavnaya CHP-B 220 13.25 2 Glavnaya Glavnaya Chuyskaya 220 59.90 1 59.9 0.5 Glavnaya Chuyskaya Bistrovka 220 39.40 1 39.4 0.5 Chuyskaya Bistrovka Issyk-Kulskaya 1 220 70.80 62.64 Separate route? Bistrovka Bistrovka Issyk-Kulskaya 2 220 79.40 1 Separate route? Bistrovka Bistrovka Ak-Kiya 220 193.20 44.36 1 OPGW requires amplifier Bistrovka Issyk-Kulskaya Tamga 220 154.00 153* 1 Issyk-Kulskaya Tuleberdieva Semetey 220 73.40 64.30 1 Tuleberdieva Kupsayskaya HPP Oktyabrskaya 220 106.70 87.36 1 Generation Company Kupsayskaya HPP Kupsayskaya HPP Kristal 220 33.60 17.70 1 Generation Company Kupsayskaya HPP Kristal Zavod PPM 220 4.35 2 Kristal Tash-Kumir HPP Kristal 220 18.30 2 Generation Company Tash-Kumir HPP Shamaldi-Say HPP Kristal 220 1.00 1 Generation Company Shamaldi-Say HPP Alay-220 Aygul-Tash 220 131.20 1 Alay-220 TOTAL 220kV: 499 0 3.0 110kV 110kV Kara-Balta Kainda 110 36.20 1 Kara-Balta Ak-Bashat (T-junction) 110 0.14 1 Ak-Bashat Kosh-Tegirmen (T-junction) 110 9.20 1 Kosh-Tegirmen Kara-Balta CHP-K 110 23.00 3.79 1 Generation Company Kara-Balta Kosh-Tegirmen (T-junction) 110 2.10 1 Kosh-Tegirmen Kainda CHP-K 110 13.10 0.17 1 Generation Company Kainda Kainda Kabelnaya 110 1.00 2 Kainda Kainda Rovnoe 110 26.80 1 Kainda Kara-Balta Ak-Suu 110 20.10 3.70 1 Kara-Balta Sokuluk Ak-Suu 110 16.80 1 Sokuluk
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Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio Kara-Balta Botbaeva-1 110 37.10 1 Kara-Balta Moskovskaya (T-junction) 110 0.20 1 Moskovskaya Sadovaya (T-junction) 110 0.10 1 Sadovaya Kara-Balta Botbaeva-2 110 37.10 1 Kara-Balta Moskovskaya (T-junction) 110 0.15 1 Moskovskaya Sadovaya (T-junction) 110 0.20 1 Sadovaya Kara-Balta Besh-Terek 110 22.16 1 Kara-Balta Botbaeva Sokuluk 110 11.30 1 Botbaeva Manas Botbaeva 110 32.40 1 Manas Kizil-Asker Manas 110 27.90 1 Kizil-Asker Kun-Tuu (T-junction) 110 0.20 1 Kun-Tuu Glavnaya Jani-Jer 110 36.30 1 Glavnaya Berlik (T-junction) 110 2.70 1 Berlik Glavnaya Berlik 110 13.10 1 Glavnaya Glavnaya Kizil-Asker 110 25.80 2 Glavnaya Teplichnaya (T-junction) 110 1.60 2 Teplichnaya N-Zapadnaya (T-junction) 110 0.15 2 N-Zapadnaya Kostromskaya (T-junction) 110 0.40 1 Kostromskaya Glavnaya Karagachevaya 1 110 8.50 1 8.5 Glavnaya Dordoy (T-junction) 110 0.10 1 Dordoy Molodaya-Gvardiya (T-junction) 110 6.35 1 Molodaya-Gvardiya Glavnaya Karagachevaya 2 110 8.30 1 Glavnaya Ala-Archa Kizil-Asker 110 7.90 2 Ala-Archa Pikovaya (T-junction) 110 3.47 2 Pikovaya Ala-Archa Lenin Zavod 110 11.20 2 Factory? Ala-Archa Seleksionnaya (T-junction) 110 1.20 2 Seleksionnaya N-Yujnaya (T-junction) 110 0.00 2 N-Yujnaya Parkovaya Ala-Archa 110 8.40 2 Parkovaya Archa-Beshik (T-junction) 110 0.55 1 Archa-Beshik Ayni (T-junction) 110 1.20 2 Ayni Kirgizskaya (T-junction) 110 0.05 2 Kirgizskaya Parkovaya Orto-Alish 110 8.28 2 Parkovaya CHP-B Parkovaya 110 9.30 2 CHP-B Asanbay (T-junction) 110 0.47 1 Asanbay Abdikalikova (T-junction) 110 1.42 2 Abdikalikova Orok (T-junction) 110 0.92 2 Orok CHP-B Yujnaya 110 8.50 2 CHP-B Vostochnaya (T-junction) 110 0.13 2 Vostochnaya CHP-B Glavnaya 110 11.70 1 T10 CHP-B Lermontova (T-junction) 110 6.40 1 Lermontova CHP-B Glavnaya 110 11.70 1 T11 CHP-B Promishlennaya (T-junction) 110 5.16 1 Promishlennaya
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Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio Lermontova (T-junction) 110 6.40 1 Lermontova CHP-B Kant 110 23.40 0.46 2 CHP-B Promishlennaya (T-junction) 110 3.36 1 Promishlennaya Alamedin (T-junction) 110 0.15 2 Alamedin Promishlennaya Atabaeva 110 3.12 2 Promishlennaya Kant Ivanovka 110 21.60 1 Kant Kant Cementnaya 110 6.02 2 Kant Ivanovka Chuyskaya 110 29.80 1 Ivanovka Chuyskaya Tokmok 1 110 1.30 1 Chuyskaya Chuyskaya Tokmok 2 110 2.01 1 Chuyskaya Chuyskaya Karoy 110 14.20 1 Chuyskaya Chuyskaya KHP 110 2.30 2 Chuyskaya Chuyskaya Iskra 110 18.90 1 Chuyskaya Bistrovka Iskra 110 28.10 0.23 1 Bistrovka Bistrovka Bistrovka HPP 110 7.00 1 Generation Company Bistrovka Bistrovka HPP Shabdan-1 110 59.10 22.10 1 Bistrovka HPP Bistrovka Orlovka-1 110 9.00 2 Bistrovka Issyk-Kulskaya Kochkorka 110 68.30 1 Issyk-Kulskaya Issyk-Kulskaya Tamga 110 142.00 25.00 1 Issyk-Kulskaya Ulahol (T-junction) 110 0.70 1 Ulahol Ak-Terek (T-junction) 110 2.00 1 Ak-Terek Bokonbaevo (T-junction) 110 1.90 1 Bokonbaevo Kadjisai (T-junction) 110 0.00 1 Kadjisai Issyk-Kulskaya Kadjisai 110 91.60 1 Issyk-Kulskaya Toguz-Bulak (T-junction) 110 7.72 1 Toguz-Bulak Bokonbaevo (T-junction) 110 1.90 1 Bokonbaevo Issyk-Kulskaya Cholpon-Ata 110 85.80 2 Issyk-Kulskaya Pionerskaya (T-junction) 110 0.00 2 Pionerskaya Promishlennaya (T-junction) 110 1.00 2 Promishlennaya Sari-Kamish (T-junction) 110 0.00 2 Sari-Kamish Toru-Aygir (T-junction) 110 0.00 2 Toru-Aygir Choktal (T-junction) 110 0.00 1 Choktal Dolinka (T-junction) 110 4.20 2 Dolinka Issyk-Kulskaya Ribache-1 110 0.00 2 Issyk-Kulskaya Cholpon-Ata Ananevo 110 49.50 1 Cholpon-Ata Bosteri (T-junction) 110 2.33 1 Bosteri Komsomol-2 (T-junction) 110 0.20 1 Komsomol-2 Grigorevka (T-junction) 110 0.00 1 Grigorevka Cholpon-Ata Komsomol-2 110 19.60 1 Cholpon-Ata Bosteri (T-junction) 110 2.33 1 Bosteri Ananevo Tyup 110 64.50 49.70 1 Ananevo Oytal (T-junction) 110 0.00 1 Oytal
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Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio Kurmenti (T-junction) 110 0.00 1 Kurmenti Tyup Prejevalskaya 110 35.80 1 Tyup Pristan (T-junction) 110 3.20 1 Pristan Kun-Batish (T-junction) 110 0.00 1 Kun-Batish Prejevalskaya Tamga 110 80.20 1 Prejevalskaya Jeti-Oguz (T-junction) 110 0.30 1 Jeti-Oguz Pokrovka (T-junction) 110 1.40 1 Pokrovka Barskaun (T-junction) 110 0.00 1 Barskaun Prejevalskaya Vostochnaya 110 8.70 1 Prejevalskaya Tamga Kadjisai 110 31.50 31* 1 Tamga Tamga PP Kumtor 110 46.00 1 Tamga PP Kumtor Kara-Sai 110 28.10 1 PP Kumtor Kara-Sai Ak-Shiyrak 110 71.38 71* 1 Kara-Sai Ak-Shiyrak Enilchek 110 76.00 75* 1 Ak-Shiyrak Ak-Kiya Kochkorka 110 108.00 1 Ak-Kiya Jani-Talap (T-junction) 110 1.70 1 Jani-Talap Sari-Bulak (T-junction) 110 0.92 1 Sari-Bulak Sari-Bulak Kara-Kujur 110 47.00 1 Sari-Bulak Kochkorka Chaek 110 113.70 1 Kochkorka Cholpon (T-junction) 110 0.00 1 Cholpon Davlet-Arik (T-junction) 110 3.30 1 Davlet-Arik Chaek Min-Kush 110 42.30 1 Chaek Aral (T-junction) 110 5.50 1 Aral Chaek Kara-Keche 110 12.80 12* 1 Chaek Ak-Kiya Naryn-1 110 12.00 2 Ak-Kiya Ak-Kiya Atbashinskaya HPP 110 27.90 27* Generation Company Ak-Kiya Atbashinskaya HPP Ugut 110 70.40 1 Atbashinskaya HPP Atbashinskaya HPP Ala-Too 110 51.60 61* 1 Atbashinskaya HPP Ala-Too Torugart 110 140.40 14* 1 Ala-Too Ugut Ala-Buka 110 60.00 59* 1 Ugut Ala-Buka Makmal 110 35.30 35* 1 Ala-Buka Makmal Jetigen 110 30.44 30* 1 Makmal Jetigen Rayonnaya 110 96.60 96* 1 Jetigen Urumbash (T-junction) 110 0.00 1 Urumbash Semetey Kirovka 110 63.99 13.80 1 Semetey Ozgorush (T-junction) 110 0.52 1 Ozgorush Pobeda (T-junction) 110 6.84 1 Pobeda Kirovka Manas 110 36.10 1 Kirovka Pokrovka (T-junction) 110 2.03 1 Pokrovka Semetey Kara-Archa 110 57.30 1 Semetey Aral (T-junction) 110 3.90 1 Aral Bala-Sari (T-junction) 110 0.20 1 Bala-Sari
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Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio Semetey Talas 110 19.80 4.20 2 Semetey Ivano-Alekseevka (T-junction) 110 0.00 1 Ivano-Alekseevka Semetey Chat-Bazar 110 39.92 39* 1 Semetey Ken-Kol (T-junction) 110 4.10 1 Ken-Kol Shamaldi-Say HPP Kristal 110 1.00 1 Generation Company Shamaldi-Say HPP Kristal Tash-Kumir 110 12.70 1.50 1 Kristal Tash-Kumir Yug 110 28.70 0.58 1 Tash-Kumir Uch-Kurganskaya HPP Tash-Kumir 110 24.10 7.90 1 Uch-Kurganskaya HPP Shamaldi-Say 2 (T-junction) 110 0.00 1 Shamaldi-Say 2 Uch-Kurganskaya HPP Shamaldi-Say 1 110 1.10 1 On to Uzb. Uch-Kurganskaya HPP Uch-Kurganskaya HPP Shamaldi-Say 1 110 0.51 1 Uch-Kurganskaya HPP Uch-Kurganskaya HPP Izbaskent 110 36.10 17.70 1 Uch-Kurganskaya HPP Izbaskent Yug 110 33.60 33* 1 Izbaskent Kok-Tash (T-junction) 110 0.00 1 Kok-Tash Izbaskent Bazar-Korgon 110 30.40 1 Izbaskent Bazar-Korgon Oktyabrskaya 110 21.80 12.40 1 Bazar-Korgon Oktyabrskaya Teplichnaya 110 28.50 28* 1 Oktyabrskaya Oktyabrskaya Kara-Suu 110 35.90 No info 1 Oktyabrskaya Jiyde (T-junction) 110 0.15 1 Jiyde Oktyabrskaya Rayonnaya 110 63.40 1 Oktyabrskaya Oktyabrskaya Rayonnaya 110 71.80 71* 1 Oktyabrskaya Jalal-Abad (T-junction) 110 7.70 1 Jalal-Abad Barpi (T-junction) 110 3.88 1 Barpi Oktyabrskaya Jalal-Abad 110 37.40 37* 1 Oktyabrskaya Mirzajan (T-junction) 110 0.00 1 Mirzajan 1 cct stops before Tash- Oktyabrskaya Tash-Bulak 110 15.55 2 Oktyabrskaya Bulak Gromadin (T-junction) 110 0.65 2 Gromadin Tashtemirova (T-junction) 110 1.36 2 Tashtemirova Oktyabrskaya Suzak 110 14.90 No Info 1 Oktyabrskaya Nijnaya (T-junction) 110 6.00 1 Nijnaya Jalal-Abad Bek-Abad 110 10.50 10* 1 Jalal-Abad Jalal-Abad Uzgen 110 30.20 1 Jalal-Abad Uzgen Kara-Kulja 110 29.23 1 Uzgen Kara-Suu Kara-Shoro 110 45.49 1 Kara-Suu Tashirova (T-junction) 110 11.60 No Info 1 Tashirova Kara-Suu CHP-Osh 110 18.00 2 Kara-Suu Tabachnaya (T-junction) 110 4.40 1 Tabachnaya Kashgar-Kishlak (T-junction) 110 5.40 2 Kashgar-Kishlak Uzlovaya CHP-Osh 110 17.00 No Info 2 Uzlovaya Anar (T-junction) 110 0.00 2 Anar Tuleyken (T-junction) 110 0.05 2 Tuleyken
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Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio CHP-Osh Pamirskaya 110 6.30 No Info 1 CHP-Osh CHP-Osh Karatay 110 24.44 No Info 1 CHP-Osh Madi (T-junction) 110 1.00 No Info 1 Madi Karatay Sari-Tash 110 165.80 No Info 1 Karatay Gulcha (T-junction) 110 0.00 1 Gulcha Sofi-Korgon (T-junction) 110 0.00 1 Sofi-Korgon Uch-Dobo (T-junction) 110 0.00 1 Uch-Dobo Uzlovaya Osh-6 110 13.60 No Info 1 Uzlovaya Uzlovaya Mangit 110 19.00 2 Uzlovaya Uchar (T-junction) 110 0.80 1 Uchar Uzlovaya Center 110 8.37 1 Uzlovaya Uzlovaya Besh-Moynok 110 9.80 1 Uzlovaya Osh-6 Pamirskaya 110 4.10 No Info 1 Osh-6 Uzlovaya Naukat 110 31.30 No Info 1 Uzlovaya Naukat Kok-Jar 110 13.50 No Info 1 Naukat Madaniyat (T-junction) 110 0.00 1 Madaniyat Alay-220 Kok-Jar 110 29.70 No Info 1 Alay-220 Kizil-Kiya 1 (T-junction) 110 0.00 1 Kizil-Kiya 1 Jin-Jigan (T-junction) 110 0.00 1 Jin-Jigan Salieva (T-junction) 110 2.80 1 Salieva Alay-220 Kizil-Kiya 2 110 12.60 2 Alay-220 Alay-220 Mash Zavod 110 0.25 1 Alay-220 Alay-220 Cemzavod 110 7.70 No Info 1 Alay-220 Kizil-Kiya 1 (T-junction) 110 0.00 1 Kizil-Kiya 1 Jin-Jigan (T-junction) 110 0.00 1 Jin-Jigan (Uzb.) Kadamjay 110 32.90 2 Isolated network (Uzb.) Plavilnaya (T-junction) 110 0.30 1 Plavilnaya Metalurgicheskaya (T-junction) 110 0.60 2 Metalurgicheskaya Aygul-Tash Centralnaya 110 46.90 No Info 1 Aygul-Tash Aygul-Tash Batken 110 1.50 2 Aygul-Tash Batken Echmrad 110 19.47 2 Batken Kupsayskaya HPP Gorodok 110 32.80 32* 1 Kupsayskaya HPP Gorodok Abasbekova 110 2.50 2.50 1 No earth wire Gorodok Kainda (T-junction) 110 0.00 1 Kainda Kupsayskaya HPP Kara-Kul 110 31.80 31* 1 Kupsayskaya HPP Kara-Kul Abasbekova 110 3.90 3* 1 Kara-Kul Kara-Suu (T-junction) 110 0.00 1 Kara-Suu Abasbekova Uch-Terek 110 51.49 5.30 1 Abasbekova Abasbekova Sargata 110 39.72 39* 1 Abasbekova Podhoz (T-junction) 110 6.70 1 Podhoz Sargata (T-junction) 110 6.06 6* 1 Sargata Kambar-Ata Uch-Terek 110 13.89 13.89 1 Kambar-Ata
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Substation Name Voltage Circuit No Earth Nº of Comment NEW SUPPLY From To kV Length Wire km Ccts PLCC / OPGW km ADSS km FOC km km Radio Uch-Terek Kozubekova 110 46.70 46.70 1 Uch-Terek Kambar-Ata (T-junction) 110 1.59 1 Kambar-Ata Kabilbekova (T-junction) 110 0.00 1 Kabilbekova Toktogul (T-junction) 110 0.00 1 Toktogul Tash-Kumir Karavan 110 59.00 27.10 1 Tash-Kumir Karavan Malkova 110 19.90 1 Karavan Karavan Ala-Buka 110 34.90 28.70 1 Karavan Padish-Ata (T-junction) 110 0.30 1 Padish-Ata Ak-Korgon (T-junction) 110 8.90 1 Ak-Korgon Ala-Buka Shekaftar 110 37.90 1 Ala-Buka Tepe-Korgon (HPP?) 110 2 Isolated import Tepe-Korgon (Tadj.) Morskaya 110 1 Isolated import (Tadj.) Arka (T-junction) 110 0.24 1 Arka Celinnaya (T-junction) 110 1.58 1 Celinnaya (Tadj.) Samat 110 1 Isolated import (Tadj.) TOTAL LINE LENGTH: 6,016 TOTAL 110kV: 9 0 0.0 PVES CONNECTION PVES CONNECTION allow for buried FOC, NCC Ala-Archa 20 14.0 NCC mostly via existing ducts allow for buried FOC, NCC Karagachevaya 20 6.0 NCC mostly via existing ducts allow for buried FOC, ChuPVES Glavnaya 30 15.0 ChuPVES mostly via existing ducts allow for buried FOC, ChuPVES NCC 30 7.0 ChuPVES mostly via existing ducts IPVES Prejevalskaya 0.2 allow for buried FOC IPVES JPVES Jalal-Abad 3.5 allow for buried FOC JPVES NPVES Naryn-1 8 allow for ADSS NPVES
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Appendix 11 Simplified Transmission Single Line Diagram
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Appendix 12 Implementation Schedule
2010 2011 2012 2013 2014 Activity SONDJFMAMJJASONDJFMAMJJASONDJFMAMJJASONDJFMAMJ Loan Approval Loan Effectiveness
A. DMF Output 1: Wholesale Metering Activity 1.1: Wholesale Meters (Package 2) Activity 1.2: HV Instrument Transformers (Package 1) Output 2: Communications & SCADA Activity 2.1: Communications (Package 2) Activity 2.2: SCADA (Package 2) Output 3: Substation Upgrades Activity 3.1: Upgrade of CB's, CT's and VT's (Package 1) Appointment of Package 1 Supply and Delivery Contractor ICB Advertising ICB Bid Period ICB Technical Evaluation and NEGK Approval ADB Approval of Technical Evaluation ICB Financial Evaluation and NEGK Approval ADB Approval of Financial Evaluation ICB Negotiation and Contract Aw ard Package 1 Manufacture by Supply and Delivery Contractor Equipment Draw ings Equipment Manufacture Equipment Inspection & Testing Equipment Delivery Installation & Commissioning of Package 1 by NEGK Civil Works Installation Commissioning As-Built Draw ings Appointment of Package 2 EPC Contractor ICB Advertising ICB Bid Period ICB Technical Evaluation and NEGK Approval ADB Approval of Technical Evaluation ICB Financial Evaluation and NEGK Approval ADB Approval of Financial Evaluation ICB Negotiation and Contract Aw ard Package 2 Detailed Design & Manufacture by EPC Contractor Equipment Draw ings Substation Surveys Confirmation of Major Quantiities Detailed Design Equipment Manufacture Equipment Inspection & Testing Equipment Delivery Package 2 Installation & Commissioning by EPC Contractor Installation Commissioning As-Built Draw ings Output 4: Consulting Services Activity 4.1: Implementation Consultant Appointment of Implementation Consultant Preparation of Bidding Documents Supervision of Procurement Supervision of Detailed Designs Supervision of Installation, Construction & Commissioning Activity 4.2: NEGK Business Plan Consultant Appointment of Consultant NEGK Business Plan Activity 4.3: Settlement Centre Consultant Appointment of Consultant NEGK Business Plan
B. MANAGEMENT ACTIVITIES Procurement Plan Key Activities Consultant Selection Procedures Mid-Term Review Project Completion Report
Project Completion -4 -3 -2 -1 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42
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Appendix 13 NEGK's PIU Experience
№ Project Name Installed Equipment Commission Donor Year 1 Installation of SF6 Circuit Breakers in SF6 Circuit Breakers Ongoing NEGK budget Glavnaya substation 2 Replacement of Circuit Breakers in Kant SF-6 Circuit Breaker ongoing substation 3 « Transmission Line 110 kV Aygultash - Trellised poles, wires, Ongoing USD 11.9 million Samat and substation», earth-wire IsDB Construction of 110 kV Transmission Line «Aygultash- Samat» 4 Installation of SF-6 Circuit Breakers in SF-6 Circuit Breakers 2009 Nookat substation 5 Replacement of oil circuit breakers in High Voltage Circuit 2009 “Vostochnaya Bosteri” substation Breakers 6 Replacement of Circuit Breakers in SF-6 Circuit Breaker 2009 Cholpon-Ata substation 7 Replacement of circuit breakers in High Voltage Circuit 2008 Kirovka substation Breakers 8 Replacement of Oil Circuit Breakers in High Voltage Circuit 2007 Kadji-Say substation Breakers 9 Replacement of oil circuit breakers in High Voltage Circuit 2007 Uzlovaya substation Breakers 10 Installation of AT-125 MVA in Kara- Auto-Transformers 125 2007 Balta and Oktyabrskaya substations MVA 11 Replacement of circuit breakers in High Voltage Circuit 2007 “Moloddogvardeyskaya” substation Breakers 12 «Rural electrification of Osh area», Ankerno-angular trellised 2004 USD 10 million, Construction of 220 kV Transmission and tubular support, wires IsDB Line «Alay - Aygultash» and earth wire 13 «Rural electrification of Osh area», АТ 125 МVА (1 unit), 2003 USD 10 million Construction of 220 kV «Aygultash» transformer 25 МVА (2 KFAED sub, reconstruction of 220 kV «Alay» unit) sub, 110 kV «Batken» sub SF6-CB
14 Rehabilitation of Substation Akkiya 220 SF 6 CB 2000 USD 4,8 million kV Government of Switzerland 15 «Improvement of power supply of Talas АТ 75 МVА (4 units), 2000 USD 24,7 million area», Transformer 125 МVА EBRD Construction of 500 kV «Alabel» (1unit.) substation, 220 kV «Semetey» sub, 220 Wires, SF6-CB kV Transmission Line «Alabel- Semetey» 16 «Reconstruction of power supply and АТ 125 МВА (2 units), 2000 USD 15,6 million centralized heating system » Transformers 40 МВА (2 ADB Construction of Transmission Line 220 units), 25 МВА (2 units) kV and 220 kV sub "Ala-Archa", SF6-CB, wires reconstruction of 220 kV "Chuy"sub, 110 kV «Novo - Troitsk» sub, 110 kV «Ortoalish» substation. 17 «Construction of 110 kV “Parkovaya” Transformer 25 МVА (1 2000 USD 3 million sub unit) ADB SF6-CB 18 «Reconstruction of power supply and SF6 CB- 220 kV (9 pieces) 1999 USD 3,5 million centralized heating system » and 110 kV (60 pieces) North 220 kV and 110 kV CB Procurement Development
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№ Project Name Installed Equipment Commission Donor Year Fund 19 «Improvement of power supply of Issyk- 200 МVА (2 units), 125 1996 USD 38,2 million Kul area», МVА (1 unit) EBRD Reconstruction of 220 kV «Issyk-Kul» SF6-CB, sub. lattice pole, wires Construction of 220 kV «Тамга» sub, Transmission Line 220 kV «Balikchy- Tamga», Construction of 220 kV Transmission Line «Bistrovka-Akkiya» 20 «Construction of 110 kV«Токмок» Transformers 25 МVА (3 1996 USD 10 million sub,110 kV«Orok» sub, 110 kV units), 16 МVА (1unit), 10 Switzerland «Lermontovo » sub. МVА (1 unit) Government
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