Technical Assistance Consultant’s Report 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. 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
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Technical Assistance Consultant’s Report
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.
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
Asian Development Bank June 2010
Executing Agency Ministry of Energy
Implementing Agency JSC "National Electrical Grid of Kyrgyzstan"
TA Nº 7368-KGZ Transmission Metering & Communications Project
Feasibility Study Report 60146737/109
June 2010
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
TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
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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
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 ADF Asian Development Fund ADSS All Dielectric Self-Supporting AECOM NZ AECOM New Zealand Ltd CAPS Central Asian Power System CB Circuit Breaker CHP Combined Heat and Power (Plant) CSCS Computerised Substation Control System CT Current Transformer CVT Capacitor Voltage Transformer DisCo Distribution Company DNP Distributed Network Protocol EIRR Economic Internal Rate of Return EMS Energy Management System EPP Electric Power Plant FIRR Financial Internal Rate of Return GoK Government of Kyrgyzstan GGSN Gateway GPRS Support Mode GPRS General Packet Radio Service GPS Global Positioning System GSM Global System for Mobile Communications HEP Heat and Energy Plant HPP Hydroelectric Power Plant ICB International Competitive Bidding ICCP Inter Control Centre Protocol IEC International Electrotechnical Commission IED Intelligent Electronic Device IP Internet Protocol ITU-T International Telecommunication Union,
Telecommunication Standardisation Sector KPI Key Performance Indicator LAN Local Area Network LIC Large Industrial Customer
MoE Ministry of Energy MPLS Multi Protocol Label Switching MSP Ministry of State Property NCC National Control Centre NEGK National Electrical Grid of Kyrgyzstan NIST National Institute of Standards and
Technology NMS Network Management System OJSC Open Joint Stock Company OPGW Optical Ground Wire PABX Private Automatic Branch Exchange PIC Project Implementation Consultant PLCC Power Line Carrier Communications PPTA Project Preparatory Technical Assistance PTSN Public Switched Telephone Network PVES (Predpriyatie Visokih Elektricheskih Setey)
NEGK Regional Centres QCBS Quality-and-Cost-Based-Selection RCC Regional Control Centre RTU Remote Terminal Unit SCADA Supervisory Control and Data Acquisition SDH Synchronous Digital Hierarchy SM Single Mode SOE Sequence of Events STM-1 Synchronous Transport Module level 1 T&D Transmission and Distribution TA Technical Assistance ToR Terms of Reference UPS Uninterruptible Power Supply VT Voltage Transformer WAN Wide Area Network
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.
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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
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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.
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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
Region (PVES) 500 kV 220 kV 110 kV Total Nº MW Nº MW Nº MW Nº MW
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.
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.
TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
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
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).
Customers
LICs NEGK
DisCos
CAPSExport - Import
Small Hydro
6 kV, 10 kV, 35 kV
10 kV 6 kV, 10 kV, 35 kV
6 kV, 10 kV, 35 kV,
220 kV, 500 kV
110 kV, 220 kV, 500 kV
110 kV, 220 kV
6 kV, 10 kV, 35 kV
LV 6 kV,
10 kV, 35 kV
Existing Wholesale
Metering Points in KGZ
EPPs
6 kV, 10 kV, 35 kV
6 kV, 10 kV, 35 kV
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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.
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
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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
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
Optical Connection
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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 Meter 500 kV 220 kV 110 kV 35 kV 10 kV 6 kV Utility
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.
TA Nº 7368-KGZ Transmission Metering & Communications Project Feasibility Study Report
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).
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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
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.
Customers
LICs NEGK
DisCos
CAPSExport - Import
Small Hydro
6 kV, 10 kV, 35 kV
10 kV 6 kV, 10 kV, 35 kV
6 kV, 10 kV, 35 kV,
220 kV, 500 kV
110 kV, 220 kV, 500 kV
110 kV, 220 kV
6 kV, 10 kV, 35 kV
LV 6 kV,
10 kV, 35 kV
Existing Wholesale
Metering Points in KGZ
M
M
EPPs
6 kV, 10 kV, 35 kV
M
New Wholesale Meters
M
6 kV, 10 kV, 35 kV
M
MM
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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
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
HV
MV
Meter S1
Feeder 1 Feeder 2 Feeder 3 Feeder 4
To DisCo 1
DisCo 1 Energy= Meter S1
= Meters F1+F2+F3+F4
Meter F1 Meter F2 Meter F3 Meter F4
HV
MV
Meter S1
Meter F1 Meter LIC1
Feeder 1 Feeder 2 Feeder 3 Feeder 4 Feeder 10
To DisCo 1
To LIC 1
DisCo 1 Energy= Meters S1-LIC1
= Meters F1+F2+F3+F4 LIC 1 Energy= Meter LIC1
Meter F2 Meter F3 Meter F4
Type A System Meter Class 0.2
Type B Feeder Meter Class 0.5
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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
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
Voltage Replacement CBs Replacement CTs (set of 3)
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
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 Cell Phone Antennae
Figure 18 Radio Relay Antenna (one broken)
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
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)
Metering System
Enterprise Router
NEGK Cellular Provider GPRS Interface
Access Router
VPN
GGSN
GPRS Modems in 200 substations
throughout Kyrgyzstan
APN
MHC
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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
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 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.
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.
Figure 27 Interface Device
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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).
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
IRIG-B
Substation LAN
Fibre Links
Multi-drop serial metering data connection
Multi-drop serial SCADA data connection
Type A - System meters
B B B B B A A
METERING AGGREGATOR
SCADA DATA COLLECTOR
SDH MULTIPLEXER
Type B - Feeder meters
Router
PABX (NEGK)
GPS CLOCK
M M
Power meters
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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.
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.
serial data
Multi-drop serial SCADA data connection
Multi-drop serial metering data connection
Type A - System meters
B B B B B A A
METERING AGGREGATOR
SCADA DATA COLLECTOR
Type B - Feeder meters
GPRS MODEM
IRIG-B GPS CLOCK
M M
Power meters
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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.
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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.
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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.
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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.
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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.;
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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).
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.
NB: The distribution components above were cancelled - refer Review Mission Aide Memoire dated 8 February 2010
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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
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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
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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 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»
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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 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, positive-sequence voltage and average values)
±0,4 % in the range from 0,8 Unom tо 1,15 Unom
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 when the meter is switched on/off, sec/day
better than ±0,5
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 from alternating-current source
30-15 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), pulses/(kVArh)
from 1,250 tо 800,000
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
SF 6 CB 2000 USD 4,8 million Government of Switzerland
15 «Improvement of power supply of Talas area», Construction of 500 kV «Alabel» substation, 220 kV «Semetey» sub, 220 kV Transmission Line «Alabel-Semetey»
16 «Reconstruction of power supply and centralized heating system » Construction of Transmission Line 220 kV and 220 kV sub "Ala-Archa", reconstruction of 220 kV "Chuy"sub, 110 kV «Novo - Troitsk» sub, 110 kV «Ortoalish» substation.
18 «Reconstruction of power supply and centralized heating system » 220 kV and 110 kV CB Procurement
SF6 CB- 220 kV (9 pieces) and 110 kV (60 pieces)
1999 USD 3,5 million North Development
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№ Project Name Installed Equipment Commission Year
Donor
Fund 19 «Improvement of power supply of Issyk-
Kul area», Reconstruction of 220 kV «Issyk-Kul» sub. Construction of 220 kV «Тамга» sub, Transmission Line 220 kV «Balikchy-Tamga», Construction of 220 kV Transmission Line «Bistrovka-Akkiya»