Circular No. 42/2015/TT-BCT on metering of electric energy in the power system

CIRCULAR

Regulations on measuring electric energy in the power systemn

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Pursuant to Decree No. 95/2012/NĐ-CP dated November 12, 2012, of the Government, detailing the functions, tasks, powers, and organizational structure of the Ministry of Industry and Trade;

Pursuant to the Electricity Law dated December 3, 2004 and the Law Amending and Supplementing Certain Articles of the Electricity Law dated November 20, 2012;

Based on Decree No. 137/2013/NĐ-CP dated October 21, 2013, issued by the Government, detailing the implementation of certain provisions of the Electricity Law and the Law Amending and Supplementing Certain Provisions of the Electricity Law;

At the proposal of the Director of the Electricity Regulatory Authority,

The Minister of Industry and Trade issues this Circular regulating the measurement of electric energy in the power system.

PART I

GENERAL PROVISIONS

Article 1. Scope of Regulation

This Circular stipulates the measurement of electric energy in power generation, transmission, distribution, wholesale electricity sales, and retail electricity sales, including the following contents:

1. Requirements for the Measurement System, Data Collection System, and Data Management System.

2. Responsibilities of units in measuring electric energy.

3. Procedures for technical design agreement, investment, installation, and acceptance of the Measurement System, Data Collection System.

4. Management and operation of the Measurement System, Data Collection System, and Data Management System.

5. Collection, processing, and storage of measurement data for electricity delivery and receipt.

6. General provisions on electricity delivery and receipt.

Article 2. Applicability

This Circular applies to the following subjects:

1. Power generation unit.

2. System and market operation unit (National Power Dispatch Center).

3. Wholesale electricity unit.

4. Transmission electricity unit.

5. Distribution electricity unit.

6. Distribution and retail electricity unit.

7. Units providing services related to electricity measurement, including:

a) Testing and calibration units;

b) Data management units.

8. Electricity consumers.

9. Vietnam Electricity Corporation.

Article 3. Explanation of Terms

Strategic multi-purpose hydropower plant

1. Voltage Level is one of the nominal voltage values used in the power system, including:

a) Low voltage is up to 01 kV nominal voltage;

b) Medium voltage is above 01 kV up to 35 kV nominal voltage;

c) High voltage is above 35 kV up to 220 kV nominal voltage;

d) Extra high voltage is above 220 kV nominal voltage.

2. Current transformer (hereinafter referred to as CT) is a device that transforms current, expanding the range of current measurement for the Measurement System.

3. Voltage transformer (hereinafter referred to as VT) is a device that transforms voltage, expanding the range of voltage measurement for the Measurement System.

4. Voltage switching device is a switch, logic circuit, or intermediate relay with the function of selecting voltage.

5. Measurement database is a database storing measurement data and management and operation information of the Measurement System.

6. Metering meter is a device that measures electrical energy by integrating power over time, storing and displaying the measured electrical energy value.

7. Point of Interconnection is the point where equipment, grid, and power plant are connected to the grid.

8. Wholesale electricity unit is an electricity enterprise licensed to operate in the wholesale electricity trading sector. Depending on the level of the competitive electricity market, the Wholesale Electricity Unit includes one of the following:

a) Electricity Trading Company is the sole wholesale electricity supplier in the competitive power generation market;

b) Other wholesale electricity units established at each level of the competitive electricity market.

9. Measurement system investment unit is an organization or individual investing in and installing the Measurement System and Data Collection System (if applicable).

10. Related electricity delivery and receipt unit is a unit participating in coordinating with other units in the process of agreeing on technical design, investment, installation, and management and operation of the Measurement System and Data Collection System, including:

a) Power generation unit;

b) Transmission electricity unit;

c) Wholesale electricity unit;

d) Distribution electricity unit;

e) Distribution and retail electricity unit;

f) Data management unit;

g) Electricity consumer.

11. Power Generation Unit is an electricity enterprise owning one or more power plants connected to the national power grid, licensed to operate in the power generation sector.

12. is an electricity unit licensed to operate in the field of distribution and sale of electricity, including: is an electricity enterprise licensed to operate in the distribution and sale of electricity, including:

a) State Corporation of Electricity;

b) Provincial Electricity Company under the Provincial Electricity Corporation (hereinafter referred to as Provincial Electricity Company).

13. Distribution and Retail Companies is an electricity enterprise licensed to operate in the distribution and retail of electricity, purchasing wholesale electricity from Wholesale Electricity Units or Distribution Electricity Units to sell retail electricity to Consumers.

14. Grid management unit is a unit owning and operating transmission grids or distribution grids, including:

a) Transmission electricity unit;

b) Distribution companies;

b) Distribution and retail electricity unit.

15. Data management unit is a unit investing in, installing, managing, and operating the Data Collection System and Data Management System within its jurisdiction.

16. Measurement system management and operation unit is a unit directly managing and operating the Measurement System within its jurisdiction, including:

a) Power generation unit;

b) Transmission electricity unit;

c) Distribution electricity unit;

d) Distribution and retail electricity unit;

e) Electricity consumer.

17. Measurement system ownership unit is a unit owning the Measurement System and Data Collection System (if applicable), including:

a) Power generation unit;

b) Transmission electricity unit;

c) Distribution electricity unit;

d) Distribution and retail electricity unit;

e) Electricity consumer.

18. Testing and calibration unit is a unit licensed in the field of testing, calibration, and verification of measuring devices according to the law on measurement.

19. Transmission electricity unit is an electricity enterprise licensed to operate in the transmission of electricity, responsible for managing and operating the national transmission grid.

20. Electricity consumer is an organization or individual purchasing electricity from the national power grid for use without reselling it to other organizations or individuals.

21. Transmission grid consumer is an organization or individual having equipment and grid connected to the transmission grid to use transmission services, including:

a) Power generation unit with power plants connected to the transmission grid;

b) Distribution electricity unit receiving electricity directly from the transmission grid;

c) Distribution and retail electricity unit receiving electricity directly from the transmission grid;

d) Electricity consumer receiving electricity directly from the transmission grid.

22. Distribution grid consumer is an organization or individual having equipment and grid connected to the distribution grid to use distribution services, including:

a) Power generation unit with power plants connected to the distribution grid;

b) Distribution and retail electricity unit;

c) Electricity consumer.

23. Tap is a device used to connect the metering circuit.

24. Measurement system is a system consisting of metering devices and metering circuits integrated to measure and determine the amount of electric energy transmitted through a metering point.

25. Data collection system is a collection of hardware devices, communication lines, and software programs that perform the function of collecting data from metering devices to the System Operation Management Unit or the Data Measurement Management Unit.

26. Data Measurement Management System is a system consisting of hardware devices, computers, and software programs that connect and collect measurement data from the Data Collection System to perform functions such as processing, calculating, and storing measurement data at the Data Measurement Management Unit.

27. Junction Box is a protective box for branch circuit metering connection points, connections between metering devices, with a cover to ensure sealing with lead seals.

28. Power Grid is a power transmission line system, transformers, and synchronous equipment for transmitting electricity, including:

a) Transmission Grid;

b) Distribution Grid.

29. Distribution Grid is the part of the grid network comprising lines and transformer stations with voltages up to 110 kV.

30. Transmission Grid is the part of the grid network comprising lines and transformer stations with voltages above 110 kV.

31. Metering Circuit is the electrical circuit system connecting metering devices to perform the function of measuring electric energy.

32. Large Power Plant is a power plant with total installed capacity exceeding 30 MW.

33. Small Power Plant is a power plant with total installed capacity up to 30 MW.

34. Measurement Data is the value of electric energy measured from metering meters, calculated electric energy, or estimated electric energy based on metering data for the purpose of delivery and payment.

35. Metering Equipment includes metering meters, current transformers (CT), voltage transformers (VT), and auxiliary devices serving the measurement of electric energy.

36. Metering Information is information about metering devices, the Metering System, and metering locations including characteristics, technical parameters, and related management and operation information.

37. IEC Standard is the standard for electrical engineering issued by the International Electrotechnical Commission.

38. Metering Location is the physical location on the circuit where purchased and sold electric energy is measured and determined.

39. LAN (Local Area Network) is a network system used to connect computers within a small area, also known as a local network.

40. WAN (Wide Area Network) is a network system established to link LANs in different areas, over long distances geographically, also known as a wide area network.

41. RS232/RS485 is the standard for serial communication technology between computers and peripheral devices defined by the Electronic Industries Alliance (EIA).

42. Ethernet is a frame-based communication technology standardized as IEEE 802.3 for Local Area Networks.

Chapter II

GENERAL RESPONSIBILITIES OF UNITS IN ELECTRIC ENERGY MEASUREMENT

Article 4. Responsibilities of the Power Generation Unit

1. Prepare Proposal Files and implement technical design agreements for the Metering System and Data Collection System to serve the delivery and receipt of electric energy between the power plant and the grid.

2. Invest in and install the Metering System and Data Collection System within its management scope to ensure compliance with the provisions of this Circular, consistent with the agreed design and relevant legal regulations on measurement.

3. Manage and operate the Metering System, Data Collection System, and communication lines to ensure accurate, secure, and reliable transmission of measurement data to the Data Measurement Management Unit for the delivery and receipt of electric energy between the power plant and the grid.

4. Lead the organization of acceptance testing, inspection, fault handling, replacement, upgrading, and decommissioning of the Metering System and Data Collection System within its management scope according to the provisions of this Circular and relevant legal regulations on measurement.

5. Coordinate with related Delivery and Receipt Units to collect metering data, prepare confirmation records of the power plant's delivered and received electric energy for payment as stipulated in this Circular.

6. Coordinate with the Data Measurement Management Unit, Electricity Trading Company, and Grid Management Unit in managing, securing, providing, and confirming the power plant's measurement data.

7. Coordinate with related units to calculate recovered or refunded electric energy production at delivery points in cases of Metering System faults or abnormalities.

Article 5. Responsibilities of the Electricity Trading and Dispatch Corporation

1. Take the lead in negotiating the technical design of the Metering System and Data Collection System for electricity delivery between large power plants, renewable energy power plants with the grid, or between transmission grids and distribution grids, or between electricity consumers connected to the transmission grid and the transmission grid, or international electricity trade through voltage levels of 110 kV and above.

2. Take the lead and coordinate with relevant parties to agree on the methods of electricity delivery, confirmation of meter readings, and data collection within the scope of management to serve delivery and payment of electricity.

3. Coordinate with related units in testing, acceptance, inspection, operation management, security, handling incidents, replacement, and cancellation of the Metering System and Data Collection System.

4. Provide information on electricity consumption data, manage the Metering System, and related information to the Data Management Unit to update into the measurement database.

5. Inspect and monitor the process of confirming meter readings and data serving payment within the scope of management; have permission to access the measurement data of related electricity delivery units to serve the inspection and monitoring process.

6. Take the lead and coordinate with related units to settle the volume of electricity delivered within the scope of management.

7. Take the lead in unifying the plan and calculation results of recovered or refunded electricity volumes in cases of incidents or abnormalities of the Metering System within the scope of management.

Article 6. Responsibilities of the Transmission Electricity Company

1. Coordinate with the Electricity Trading and Dispatch Corporation and related electricity delivery units in negotiating and unifying the technical design of the Metering System and Data Collection System for electricity delivery between power plants and the transmission grid, or between the transmission grid and the distribution grid, or between electricity consumers connected to the transmission grid and the transmission grid, or international electricity trade through voltage levels of 220 kV and above.

2. Invest in and install the Metering System and Data Collection System for electricity delivery between the transmission grid and the Distribution Company, or between the transmission grid and the Distribution and Retail Company, or between the transmission grid and electricity consumers receiving electricity directly from the transmission grid, except where the parties have agreed otherwise to ensure their interests but not contrary to the provisions of the law. Ensure that the Metering System and Data Collection System meet the requirements stipulated in this Circular, comply with the agreed design, and conform to legal regulations on measurement.

3. Manage and operate the Metering System and Data Collection System within the scope of management to ensure accurate, secure, and reliable transmission of measurement data to the Data Management Unit for electricity delivery.

4. Lead the organization of acceptance testing, inspection, fault handling, replacement, upgrading, and decommissioning of the Metering System and Data Collection System within its management scope according to the provisions of this Circular and relevant legal regulations on measurement.

5. Provide service for managing operation, security, confirmation of measurement data, and maintenance of equipment belonging to the Metering System and Data Collection System of electricity consumers using the transmission grid when the metering location is within the managed area.

6. Coordinate with related electricity delivery units to agree on methods of electricity delivery, data collection, and preparation of records confirming electricity delivery for payment purposes within the scope of management.

7. Coordinate with related units to calculate recovered or refunded electricity volumes at delivery points in cases of incidents or abnormalities of the Metering System.

Article 7. Responsibilities of the Electricity Distribution Unit

1. Coordinate with the Electricity Trading Company, the Transmission Unit, or the Generation Unit in agreeing and unifying the technical design of the Metering System and Data Collection System for electricity delivery and receipt between the transmission grid and the distribution grid or between large power plants connected to the distribution grid and the distribution grid or international electricity trade through 110 kV voltage levels.

2. Take the lead in agreeing and unifying the technical design of the Metering System and Data Collection System for electricity delivery and receipt between electricity customers using the distribution grid and the distribution grid, except in cases stipulated in Clause 1, Article 5 of this Circular. For electricity delivery and receipt between two Distribution Units, the responsibility for investing in the Metering System at the connection point shall be carried out according to the agreement between the Distribution Units.

3. Invest in and install the Metering System and Data Collection System for electricity delivery and receipt between the distribution grid and electricity users or between the distribution grid and the Distribution and Retail Units, except where the parties have agreed otherwise to ensure the interests of all parties but not contrary to the provisions of the law. Ensure that the Metering System and Data Collection System comply with the provisions of this Circular, conform to the approved design, and comply with the legal regulations on measurement.

4. Manage and operate the Metering System and Data Collection System within the scope of management to ensure accurate, safe, and reliable data transmission to the Data Measurement Management Unit for electricity delivery and receipt.

5. Take the lead in organizing acceptance, inspection, handling incidents, replacement, upgrading, renovation, and cancellation of the Metering System and Data Collection System within the scope of management in accordance with this Circular and legal regulations on measurement.

6. Provide management operation services, security, provision, confirmation of metering data, and maintenance of equipment belonging to the Metering System and Data Collection System of electricity customers using the distribution grid when the metering location is within the scope of management.

7. Take the lead and coordinate with related electricity delivery and receipt units to agree on methods of electricity delivery and receipt, data collection, and preparation of records confirming electricity delivery and receipt for payment purposes within the scope of management.

8. Take the lead in unifying the plan and calculation results of additional or refunded electricity consumption in cases of incidents or abnormalities of the Metering System within the scope of management.

Article 8. Responsibilities of the Distribution and Retail Units

1. Coordinate with the Electricity Distribution Unit or the Electricity Trading Company and related electricity delivery and receipt units in agreeing and unifying the technical design of the Metering System and Data Collection System for electricity delivery and receipt between the Distribution and Retail Units and the grid.

2. Take the lead in agreeing and unifying the technical design of the Metering System and Data Collection System for electricity delivery and receipt with electricity customers within the scope of management.

3. Invest in, install, manage, and operate the Metering System and Data Collection System for electricity delivery and receipt between the distribution grid within the scope of management and electricity customers, except where the parties have agreed otherwise to ensure the interests of all parties but not contrary to the provisions of the law. Ensure that the Metering System and Data Collection System comply with the provisions of this Circular, conform to the approved design, and comply with the legal regulations on measurement.

4. Manage and operate the Metering System and Data Collection System within the scope of management to ensure accurate, safe, and reliable data for electricity delivery and receipt.

5. Take the lead in organizing acceptance, inspection, handling incidents, replacement, upgrading, renovation, and cancellation of the Metering System and Data Collection System within the scope of management in accordance with this Circular and legal regulations on measurement.

6. Take the lead and coordinate with related electricity delivery and receipt units to agree on methods of electricity delivery and receipt, data collection, and preparation of records confirming electricity delivery and receipt for payment purposes within the scope of management.

7. Take the lead in unifying the plan and calculation results of recovered or refunded electricity volumes in cases of incidents or abnormalities of the Metering System within the scope of management.

Article 9. Responsibilities of Electricity Consumers

1. Create favorable conditions and cooperate with the electricity supplier in the installation, acceptance, inspection, handling of malfunctions, replacement, upgrading, and renovation of the Metering System and Data Collection System (if applicable) to serve the sale of electricity to electricity consumers.

2. In cases where connection is made to voltage levels of 110 kV or higher, electricity consumers shall be responsible for cooperating with the electricity supplier to unify the technical design of the Metering System and Data Collection System serving the delivery and receipt of electric power between electricity consumers and transmission or distribution networks.

3. In cases where electricity consumers invest in the Metering System and Data Collection System according to agreements with the electricity supplier, electricity consumers shall be responsible for establishing design agreement files, organizing acceptance, inspection, operation management, handling of malfunctions, replacement, upgrading, and renovation of the Metering System and Data Collection System (if applicable) within their management scope as stipulated in this Circular and relevant laws on measurement.

4. Cooperate with the electricity supplier or Grid Management Unit to record meter readings, compile the volume of delivered and received electricity as a basis for comparison and confirmation of electricity for payment.

5. Cooperate with the electricity supplier to calculate the volume of electricity to be recovered or refunded at points of delivery and receipt of electricity in case of malfunctions or abnormalities in the Metering System.

6. Do not arbitrarily change or illegally interfere with the Metering System; cooperate with the electricity supplier to protect the Metering System within the consumer's management scope. Timely notify the electricity supplier or Grid Management Unit about the malfunction status and abnormal operation of the Metering System.

Article 10. Responsibilities of Units Operating the Power System and Electricity Market

1. Cooperate with the Data Measurement Management Unit to manage and utilize the database for measurement data serving the operation of the power system and electricity market.

2. Cooperate with the Electricity Trading Company, Transmission Unit, and Distribution Unit to agree and unify the technical design of the Metering System and Data Collection System serving the delivery, receipt, and payment of electricity in the electricity market.

3. Manage, use, and publish measurement data on the official website of the electricity market to serve payment and market operation.

Article 11. Responsibilities of the Data Measurement Management Unit

1. Invest in and manage the operation of equipment, programs, and software belonging to the Data Collection System and Data Management System within their management scope.

2. Cooperate with the units investing in the metering system and related units delivering and receiving electricity to agree on technical design and accept the Metering System and Data Collection System. Implement the issuance of measurement point codes for measurement points under the responsibility of the Data Measurement Management Unit to collect data from.

3. Collect measurement data within their management scope and provide collected measurement data to related units delivering and receiving electricity based on principles ensuring the right to use data, security, confidentiality, and convenience in exploiting and using measurement data. Be responsible for the completeness and accuracy of collected measurement data compared to meter readings.

4. Implement legal regulations on auditing and inspecting procedures, software, and programs for collecting, processing, and storing measurement data within their management scope to ensure the accuracy of measurement data and comply with provisions of this Circular.

5. Implement measures to manage and secure meter passwords and bear legal responsibility for managing and securing meter passwords received from the System Operation Management Unit.

6. Participate in extracting data to serve the calculation of electricity volumes to be recovered or refunded at points of delivery and receipt of electricity in case of malfunctions or abnormalities in the Metering System.

7. Store measurement data for at least five years.

Article 12. Responsibilities of Testing Units and Calibration Units

1. Conduct testing, calibration, parameter setting, and lead seal installation for measuring devices according to contracts signed with the owners of the measurement systems or system operation management units, ensuring compliance with the provisions of this Circular and relevant laws on measurement.

2. Implement management and security measures for meter passwords and bear legal responsibility for managing and securing meter passwords installed by their unit.

Chapter III

REQUIREMENTS FOR MEASUREMENT SYSTEMS

Section 1

GENERAL REQUIREMENTS FOR MEASUREMENT SYSTEMS

Article 13. Principles for Determining Measurement Locations

1. The main measurement location must coincide or be adjacent to the connection point.

2. For medium voltage and above, at each connection point, the main measurement location and backup measurement locations must be determined. The number and location of backup measurement locations must be accurately determined based on the voltage level and specific characteristics of the measurement location.

3. For low voltage, at each connection point, one main measurement location must be determined.

4. In cases where conditions are not met to arrange measurement locations as stipulated in Clause 1 of this Article, related units must agree on alternative measurement locations while determining the method for converting electricity from the alternative measurement location to the connection point. In such cases, the conversion method must take into account transformer losses and the connecting line between the alternative measurement location and the connection point during operation to convert electricity from the alternative measurement location to the connection point during delivery and payment.

Article 14. Measurement Locations for Power Plants

1. In cases where power generation units own power plants participating in competitive electricity markets or large power plants

a) At each connection point, one main measurement location and two backup measurement locations must be determined;

b) Connection points belonging to the substation of the power generation unit

- The main measurement location is determined at the main circuit breaker or the high-voltage side terminal of the step-up transformer directly connected to the grid, except in cases of agreement otherwise;

- Backup measurement location 1 is determined at the outgoing lines of the substation at the power plant, except in cases of agreement otherwise;

- Backup measurement location 2 is determined at the generator terminal, except in cases of agreement otherwise.

c) Connection points not belonging to the substation of the power generation unit

- If the substation of the power generation unit has only one line connected to the power system through the connection point and there is no power circulating through the substation busbar, the main measurement location coincides or is adjacent to the connection point;

- If the substation of the power generation unit has two or more lines connected to the power system through the connection point and there is power circulating through the substation busbar, the main measurement location is determined according to the provisions of Point b of this Clause;

- Backup measurement location 1 is determined by mutual agreement among the parties involved;

- Backup measurement location 2 is determined according to the provisions of Point b of this Clause.

d) If the main measurement location or backup measurement locations are determined at the substation of the power grid management unit, an agreement must be reached between the power generation unit, the power grid management unit, the Electricity Trading Company, and the power delivery and receipt unit (if applicable).

2. In cases where power generation units own small power plants not participating in the electricity market

a) At each connection point, one main measurement location and one backup measurement location must be determined;

b) The main measurement location and backup measurement location are determined according to the provisions of Points b, c, and d of Clause 1 of this Article.

Article 15. Metering location for electricity customers or distribution and retail electricity units connected to medium voltage or higher voltage levels

1. For connection points at 110 kV or above, each connection point must determine one (1) primary metering location and one (1) backup metering location.

2. For medium voltage connection points, electricity customers or distribution and retail electricity units may agree with the distribution electricity unit on a backup metering location if deemed necessary.

3. For connection points serving the handover between distribution and retail electricity units and electricity customers: The primary metering location and backup metering location (if any) shall be determined according to the agreement between both parties in compliance with this Circular.

4. Connection points belonging to the substation of the transmission electricity unit or the distribution electricity unit

a) The primary metering location is determined at the connection point, except where otherwise agreed;

b) The backup metering location (if any) is determined according to the agreement among the relevant parties.

5. Connection points belonging to the substation of the electricity customer or the distribution and retail electricity unit

a) The primary metering location is determined at the main circuit breaker or the high-voltage terminal of the transformer directly connected to the grid, except where otherwise agreed;

b) The backup metering location

- For 110 kV or higher voltage levels: Is determined at the outgoing feeders of the substation directly connected to the grid, except where otherwise agreed;

- For medium voltage: Is determined according to the agreement among the relevant parties.

6. In cases where the connection point differs from the provisions of Clause 4 and Clause 5 of this Article, the primary metering location and backup metering location are determined according to the agreement among the relevant parties.

Article 16. Metering location between transmission grid and distribution grid

1. At each connection point, one (1) primary metering location and one (1) backup metering location must be determined.

2. Connection points belonging to the power station of the transmission electricity unit

a) The primary metering location is determined at the main circuit breaker or the low-voltage terminal of the transformer at the power station of the transmission electricity unit, except where otherwise agreed;

b) The backup metering location is determined at the outgoing feeders of the substation of the transmission electricity unit, except where otherwise agreed.

3. Connection points belonging to the substation of the distribution electricity unit

a) The primary metering location is determined at the main circuit breaker or the high-voltage terminal of the distribution transformer directly connected to the transmission grid, except where otherwise agreed;

b) The backup metering location is determined at the outgoing feeders of the substation of the distribution electricity unit, except where otherwise agreed.

Article 17. Metering location between two distribution electricity units

The primary metering location and backup metering location are determined according to the agreement between the distribution electricity units and the related power exchange units.

Article 18. Metering location for low voltage supply

The metering location for electricity customers using the distribution grid connected at low voltage level is determined at the connection point of the electricity customer using the distribution grid, except where otherwise agreed.

Article 19. Requirements for the Metering System

1. The main metering system installed at the primary metering point must accurately and fully determine the quantities of electricity bought and sold, and eliminate factors affecting the measurement results due to the loop structure of the power system, serving as the primary basis for calculating and settling electricity at the connection point.

2. The backup metering system installed at the backup metering point shall perform the following functions:

a) Replace the main metering system to serve as the basis for calculating the quantities of electricity bought and sold when the main metering system operates inaccurately or experiences malfunctions, based on the testing results from the Testing and Calibration Unit and the unified records of all relevant parties;

b) Check and monitor the measurement results of the main metering system under normal operating conditions;

c) Combine with the main metering system and other backup metering systems to calculate the amount of electricity for settlement in certain special cases.

3. Measuring devices must meet technical requirements for measurement and be approved, tested, and calibrated according to the provisions of the Measurement Law.

4. Current transformers (CTs) installed in series at the bushings of power transformers and circuit breakers shall not be used for the metering system serving the purchase and sale of electricity.

Article 20. Requirements for the Measurement Circuit

1. The secondary winding of the CT and the second cable connected to the metering meter of the main metering system shall not be used for other purposes and must be independent of the backup metering system. For the CT of the backup metering system, the measuring secondary winding may be shared between the metering meter and other measuring equipment, control devices, provided that the design ensures the safety and accurate operation of the backup metering system. The measuring secondary winding shall not supply power jointly to the metering meter and protective devices.

2. The second cable connecting from the secondary winding of the voltage transformer (VT) to the metering meter of the main metering system shall not be used for other purposes and must be independent of the backup metering system.

3. The second cables of the measurement circuit must follow the shortest path, have the fewest connection points through terminal blocks, and must have sufficient conditions to implement sealing measures such as lead seals on terminal blocks or connection points. The second cable of the main metering system must run separately and connect directly from the CT terminal box, intermediate VT cabinet to the metering meter cabinet without passing through terminal blocks in the intermediate cabinet. The type of second cable of the measurement circuit must be flexible conductor wire with two layers of insulation.

4. In cases where the metering meter is supplied with voltage from one of the VTs through a voltage switching device, the terminals of the voltage switching device must ensure sealing conditions, and the metering meter must be programmed to record the time and duration of voltage switching.

5. The load of the secondary measuring circuit after the CT, VT must be within the rated capacity of the CT, VT as specified by the manufacturer.

6. The second measurement circuit must be connected to ensure that sealing does not affect the second control and protection circuits.

7. In cases where the current circuit of the backup metering system shares with other measuring devices, the metering meter must be connected before other measuring devices, while ensuring it does not affect the accuracy of the backup metering system and has sufficient conditions to implement sealing measures on the current circuit from the CT terminal box to the metering meter.

8. Test junction boxes installed to serve the calibration of measuring devices must have sufficient conditions for sealing and lead sealing. In cases where the secondary windings for the metering system and protective devices are placed in the same secondary terminal box and cannot be sealed entirely, separate sealing measures for the secondary windings for the metering system must be implemented to prevent unauthorized interference.

9. For primary metering points of large power plants and power plants participating in the electricity market, if the metering meters are not continuously powered from the secondary voltage measurement system, additional backup power sources must be equipped for the metering meters from the standby AC power supply circuit to ensure continuous operation of the metering meters. Backup power supply for the metering meters must ensure the accurate operation of the metering meters and meet the technical requirements of the measurement circuit.

9. For the main metering positions of large power plants and power plants participating in the electricity market, in cases where the meters are not continuously powered from the secondary voltage measurement system, additional backup power sources for the meters must be installed from the backup sinusoidal power supply system to ensure continuous operation of the meters. The provision of backup power for the meters must ensure the accurate operation of the meters and meet the technical requirements of the measurement circuit.

Article 21. Requirements for Sealing with Lead Seals and Security

1. The entire Metering System, including the CT and VT junction boxes, metering meters, current circuits, voltage circuits, logic conversion circuits, and test connection boxes (if any), must be sealed with lead seals to prevent unauthorized interference in accordance with the provisions of the law.

2. The Electricity Distribution Unit and the Electricity Distribution and Retail Unit shall issue regulations on the use of sealing pliers and lead seals for CT and VT junction boxes, metering meters, and meter protection boxes, and determine the number of sealing pliers and lead seals for CT and VT junction boxes, metering meters, and meter protection boxes appropriate to the number of metering devices under their management, and register the quantity and serial numbers of lead seals according to the prescribed regulations.

3. For Metering Systems equipped with Data Collection Systems, meter readings collected from metering points must be secured and encrypted to prevent unauthorized interference.

4. The software managing the system for reading, transmitting, and consolidating electricity metering data must be secured with multiple levels of passwords to ensure the security, accuracy, and reliability of the metering data.

Article 22. Management of Electricity Meter Passwords

1. Electricity meter passwords must be divided into three different access levels to serve the requirements for managing and operating electricity meters and are defined as follows:

a) The "Setup" password is the level of password that allows access to the electricity meter to set up and change its parameters and working programs. This password is used to set one or all parameters of the electricity meter and may only be used by authorized persons.

b) The "Time Synchronization" password is the level of password that allows access to the electricity meter to read data and synchronize time. This password does not allow setting up or changing parameters and working programs of the electricity meter and may only be used by authorized persons.

c) The "Read Only" password is the level of password that allows access to the electricity meter to read data but does not permit changes to the set parameters and working programs of the electricity meter. This password is used to collect meter data on-site or remotely.

2. The contents of each level of password for each electricity meter must be set differently. Electricity meter passwords must be stored and secured in individual envelopes with sealed labels corresponding to each electricity meter.

3. Password envelopes for electricity meters must be handed over to responsible managers for storage. The manager is responsible for compiling password envelopes for electricity meters into a password file containing the following information: Type of electricity meter, meter number, Owner of the metering system, Unit managing the operation of the metering system.

4. The handover of password envelopes for electricity meters during management and storage or the use of electricity meter passwords must be recorded in a protocol signed by both parties receiving and handing over.

5. For electricity meters using a hard-coded setup password, they must be sealed to ensure that the meter cannot be interfered with without breaking the seal.

6. The Owner of the metering system or the Unit managing the operation of the metering system is responsible for managing and securing the "Read Only" passwords of electricity meters.

7. Testing and calibration units are responsible for managing and securing the "Setup" passwords of electricity meters.

8. Units managing metering data are responsible for managing and securing the "Time Synchronization" passwords of electricity meters.

Article 23. Management of Documents for Measurement and Delivery of Electric Power

During the design, investment, operation management, delivery, and payment processes, relevant units shall be responsible for managing and storing the following documents:

1. Measurement and delivery of electric power between power plants and transmission grids or between transmission grids and distribution grids

a) Technical design documents of the measurement system that have been agreed upon uniformly among the parties concerned in accordance with regulations;

b) Certified copies of certificates of inspection for CTs, VTs, and measuring meters issued by testing and inspection units when used with type 1 inspection marks;

c) Test reports for CTs, VTs, and measuring meters issued by testing and inspection units;

d) Inspection and test reports for the second circuit of the measurement system issued by testing and inspection units;

đ) Setting parameter reports for measuring meters;

e) Completion acceptance reports for installation of the measurement system, inspection date, and seal identification;

g) Completion acceptance reports for installation of the data collection system;

h) Acceptance, inspection, fault handling, and equipment replacement reports for the measurement system during management and operation;

i) As-built drawings of the second circuit measurement system and the data collection system;

k) Reports related to meter reading and settlement of electricity consumption for billing purposes;

2. Delivery of electric power between the electricity supplier and electricity consumers

a) For voltages of 110 kV and above: The documents specified in Clause 1 of this Article;

b) For medium voltage: The documents specified at Point a, Point b (if applicable), Point c, Point d, Point e, Point g (if applicable), and Point k (if applicable) of Clause 1 of this Article;

c) For low voltage: The documents specified at Point b (if applicable), Point đ (if applicable), and Point e of Clause 1 of this Article.

Section 2

REQUIREMENTS FOR MEASUREMENT SYSTEMS AT MEDIUM AND HIGH VOLTAGES

Article 24. Configuration of the Measurement System

1. The configuration of the measurement system includes:

a) Measuring meters;

b) Current transformers (CT);

c) Voltage transformers (VT);

d) Electrical circuits and secondary cables for measurement;

đ) Equipment for data collection;

e) Safety protection devices, sealing positions, and lead seals;

g) Auxiliary equipment, meter cabinets, test connection boxes, switching devices, isolation circuits for testing, logic switching circuits, voltage (or current) circuits supplied to measuring meters, voltage and current testing devices, lightning protection devices for communication channels of measuring meters.

2. The specific configuration of a measurement system is determined accurately based on the voltage level, scale of electricity trading, and characteristics of the measurement location.

Article 25. Requirements for Measuring Meters

1. General Requirements

a) Three-phase four-wire or single-phase two-wire type;

b) Electronic type with integrated functions and programmable capabilities;

c) One or more tariff rates;

d) Measurement of active and reactive energy in both directions separately according to four quadrants;

đ) Maximum power measurement function and load profile recording;

e) Connectivity with computers for local and remote data collection and reading;

g) Powered from the secondary measurement voltage system and must ensure continued operation in case of loss of one or two phase voltages;

h) Must have internal power supply to maintain real-time clock. In necessary cases, measuring meters may integrate battery power for screen data reading;

i) Multiple levels of password protection;

k) Sealing positions and lead seals ensuring that wire terminals cannot be accessed and meter settings cannot be changed without breaking the seals;

l) Data storage function for at least 60 days with a recording cycle of 30 minutes per data channel and programmable integration cycles shorter than 30 minutes;

m) Suitable current and voltage ratings for the secondary current and voltage of CTs and VTs;

n) Measuring meters must be connected to the local or remote data collection system in compliance with connection standards and data collection software.

2. Accuracy requirements for measurement at voltages of 220 kV and above or for measurement serving the delivery of electric power between power plants participating in the electricity market or large power plants and the grid

a) Primary measuring meters must meet accuracy class 0.2 for active energy and 2.0 for reactive energy according to standards set by the Ministry of Science and Technology;

b) Backup measuring meters must meet accuracy class 0.5 for active energy and 2.0 for reactive energy according to standards set by the Ministry of Science and Technology.

3. Accuracy requirements for measurement serving the delivery of electric power in cases not covered by Clause 2 of this Article

a) Primary measuring meters must meet minimum accuracy class 0.5 for active energy and 2.0 for reactive energy according to standards set by the Ministry of Science and Technology;

b) The accuracy class of backup measuring meters is determined by agreement among the parties but must not be lower than the following accuracy classes:

- 0.5 for active energy and 2.0 for reactive energy for 110 kV voltage measurements according to standards set by the Ministry of Science and Technology;

- 1.0 for active energy and 2.0 for reactive energy for medium voltage measurements according to standards set by the Ministry of Science and Technology.

4. If the Ministry of Science and Technology has not established standards for the accuracy of measuring meters, then IEC standards or equivalent standards should be used.

Article 26. Requirements for current transformers (CTs) used for electricity consumption measurement purposes

1. General Requirements

a) Must have a separate secondary measuring winding for measuring devices and electricity meters.

b) The rated secondary current value must be 01 A or 05 A.

c) Must have a sealing position at the cover of the secondary measuring winding terminal box to ensure that it cannot be accessed without breaking the seal, thus preventing interference with the connected circuit.

2. Accuracy requirements for measurement at voltages of 220 kV and above or for measurement serving the delivery of electric power between power plants participating in the electricity market or large power plants and the grid

a) The secondary measuring winding of the CT serving as the primary metering must meet accuracy class 0.2 according to standards set by the Ministry of Science and Technology.

b) The secondary measuring winding of the CT serving as the backup metering must meet accuracy class 0.5 according to standards set by the Ministry of Science and Technology.

c) The capacity of the secondary measuring winding of the CT must be within the permissible load capacity limit of the secondary circuit as specified by the manufacturer.

3. Accuracy requirements for measurement serving the delivery of electric power in cases not covered by Clause 2 of this Article

a) The secondary measuring winding of the CT serving as the primary metering must meet a minimum accuracy class of 0.5 according to standards set by the Ministry of Science and Technology.

b) The accuracy class of the secondary measuring winding of the CT serving as the backup metering shall be determined by agreement among the relevant parties but must not be lower than accuracy class 0.5 for 110 kV voltage level metering and accuracy class 1.0 for medium voltage level metering according to standards set by the Ministry of Science and Technology.

4. In cases where the Ministry of Science and Technology has not established standards for accuracy classes for CTs, International Electrotechnical Commission (IEC) Standards or equivalent standards shall be applied.

Article 27. Requirements for voltage transformers (VTs) used for electricity consumption measurement purposes

1. General Requirements

a) Must have a separate secondary measuring winding for measuring devices and electricity meters.

b) The rated secondary system voltage value (line voltage) must be 100 V or 110 V.

c) Must have a sealing position at the cover of the secondary measuring winding terminal box to ensure that it cannot be accessed without breaking the seal, thus preventing interference with the connected circuit.

2. Accuracy requirements for measurement at voltages of 220 kV and above or for measurement serving the delivery of electric power between power plants participating in the electricity market or large power plants and the grid

a) The VT serving as the primary metering must meet accuracy class 0.2 according to standards set by the Ministry of Science and Technology.

b) The VT serving as the backup metering must meet accuracy class 0.5 according to standards set by the Ministry of Science and Technology.

c) The capacity of the secondary measuring winding of the VT must be within the permissible load capacity limit of the secondary circuit as specified by the manufacturer.

3. Accuracy requirements for measurement serving the delivery of electric power in cases not covered by Clause 2 of this Article

a) The VT serving as the primary metering must meet accuracy class 0.5 according to standards set by the Ministry of Science and Technology.

b) The accuracy class of the VT serving as the backup metering shall be determined by agreement among the relevant parties but must not be lower than accuracy class 0.5 for 110 kV voltage level metering and accuracy class 1.0 for medium voltage level metering according to standards set by the Ministry of Science and Technology.

4. In cases where the Ministry of Science and Technology has not established standards for accuracy classes for VTs, International Electrotechnical Commission (IEC) Standards or equivalent standards shall be applied.

Section 3

REQUIREMENTS FOR LOW-VOLTAGE DISTRIBUTION SYSTEM MEASUREMENT SYSTEMS

Article 28. Requirements for electricity meters

1. Must be three-phase four-wire type for three-phase meters and single-phase two-wire type for single-phase meters.

2. Must have sealing positions and lead seals to ensure that the terminals and settings inside the meter cannot be accessed or altered without breaking the seal.

3. For three-phase meters, the active energy meter must meet accuracy class 1.0 according to standards set by the Ministry of Science and Technology. For single-phase meters, the active energy meter must meet accuracy class 1.0 for electronic meters and accuracy class 2.0 for mechanical meters according to standards set by the Ministry of Science and Technology.

In cases where the Ministry of Science and Technology has not established standards for accuracy classes for electricity meters, International Electrotechnical Commission (IEC) Standards or equivalent standards shall be applied.

4. For electronic meters: May be equipped with multifunctional capabilities, programmable functions, and remote data collection systems compatible with connection standards and data collection software.

Article 29. Requirements for Current Transformers (CT) used for electricity consumption measurement purposes

In cases where CTs are used for measuring low-voltage electricity consumption, the CTs must meet the following requirements:

1. There must be a separate secondary winding for metering purposes to be exclusively used with the electricity consumption meter.

2. The rated secondary current value must be either 01A or 05A.

3. There must be a sealable position on the cover of the secondary winding terminal box for metering equipment and electricity consumption meters to ensure that the electrical circuit cannot be tampered with without breaking the seal.

4. The capacity of the secondary winding for metering of the CT must fall within the permissible load capacity limit of the secondary circuit as specified by the manufacturer.

5. Accuracy class 0.5 according to standards prescribed by the Ministry of Science and Technology. In cases where the Ministry of Science and Technology has not yet established accuracy standards for CTs, the IEC standard or other equivalent standards shall be applied.

Chapter IV

REQUIREMENTS FOR DATA COLLECTION SYSTEMS AND DATA MANAGEMENT SYSTEMS FOR MEASUREMENT

Article 30. Management of Data Collection Systems and Data Management Systems for Measurement

1. Responsibilities of the Data Measurement Management Unit

a) To invest in, install, manage, and operate data collection systems and data management systems within its jurisdiction to ensure that units can connect in compliance with the provisions of this Circular;

b) To provide related units with file formats and interface standards based on the data collection model and data transmission methods applied;

c) To establish, set parameters, and implement security measures, confidentiality, and safe information encryption for data collection systems and data management systems at the measurement location and at the data collection, storage, and processing center managed by the unit to ensure the accuracy and reliability of measurement data.

2. Responsibilities of the System Measurement Operation Management Unit

a) To secure the settings parameters for the software program reading meter data within its jurisdiction;

b) Not to interfere with the data reading and transmission program to modify settings parameters affecting the accuracy of measurement data. Not to alter meter readings from the electricity consumption meter to the computer or local data concentrator (if any).

Article 31. Overall Model of Data Collection Systems and Data Management Systems for Measurement

1. In cases where remote data collection technology is applied, depending on infrastructure conditions and operational jurisdiction, units may choose and apply technological solutions to remotely collect measurement data through wired or wireless transmission environments, automatically or semi-automatically, consistent with the overall model of data collection systems and data management systems described in Appendix 1 issued together with this Circular.

2. Data Collection Models

a) Depending on actual conditions and infrastructure, the data collection model includes one of the following types:

- On-site data collection from individual electricity consumption meters;

- Data collection through a centralizing device.

b) Cases applying on-site data collection from individual electricity consumption meters

- Applied to individual electricity consumption meters installed separately, which are not conducive to grouping meter connections;

- Transmitting data from electricity consumption meters to the data collection server via WAN/LAN/mobile networks;

- Applied to dispersedly placed electricity consumption meters.

c) Cases applying data collection through a centralizing device

- Interface connection with electricity consumption meters: LAN or RS232/485;

- Applied to electricity consumption meters located at the same site.

3. Technological solutions are classified according to the transmission environment and distance as follows:

a) Transmission Environment

- Wired: Including PLC, RS485/RS232, Ethernet, optical fiber cable, xDSL;

- Wireless: Including RF/RF-Mesh, mobile communication network.

b) Transmission Distance

- On-site: Is a solution using handheld index recording devices to directly collect data at the measurement location;

- Remote: Is a solution using remote data collection systems to collect data from electricity consumption meters or remote data concentrators (DCU) through wired or wireless channels.

Article 32. Requirements for the Data Collection System

The data collection system of the entity managing the operation of the measurement system (if any) or the entity managing measurement data must be equipped with minimum functions and requirements, including:

1. Possess the ability to collect measurement data through direct connection to the meter at each measurement point when there is an agreement between the relevant parties.

2. Synchronize time with the standard time source for all meters within the system.

3. The data collection system must have the following minimum functions:

a) Implement automatic data collection and transmission according to a predetermined schedule or on demand;

b) Manage the list of measurement points, data collection schedules for each meter or group of meters; manage and store measurement data after reading from the meter;

c) Manage system access including user authentication and system access rights.

4. The communication environment may use wired or wireless systems, ensuring compatibility with the Measurement Data Management System. The environment and method of information transmission must have security, confidentiality, and safe information encryption solutions.

5. Information devices connected to the meter must meet the following requirements:

a) Security, confidentiality, and safe information encryption requirements to prevent unauthorized intervention and information forgery;

b) Electrical safety and telecommunications requirements to avoid damage to the Measurement System and the Measurement Data Management System.

6. The data transmission system, file format, and interface standards of the data collection system must be compatible with the Measurement Data Management System of the entity managing measurement data.

Article 33. Requirements for the Measurement Data Management System

The measurement data management system must be equipped with minimum functions and requirements, including:

1. The communication environment may use wired or wireless environments and must apply security, confidentiality, and safe information encryption solutions.

2. Information devices connected to the data collection system must meet the following requirements:

a) Security, confidentiality, and safe information encryption requirements to prevent unauthorized intervention and information forgery;

b) Electrical safety and telecommunications requirements to avoid damaging the data collection system.

3. Possess the ability to connect and collect measurement data through computers in the data collection system. Declare and manage the list of measurement points and related information.

4. Manage, store, and generate reports for measurement data and related events.

5. Computer systems for reading and storing data must be provided with backup power supply, installed antivirus programs, administrative and operational system permissions. The database system must always be backed up to ensure rapid data recovery and the data must remain intact.

6. The server system has the capability to record the entire processing, verification, exploitation of measurement data, and is equipped with a backup system to ensure that measurement data is not lost under any circumstances.

7. Access management includes user login codes and system access rights. Administrative permissions for software are set at full control and operational levels, including full control level (installation, configuration, permission setting for operational users and data adjustment) and operational level (read, view, and export data).

8. Connect and share data with other application software programs to exploit data.

9. Manage measurement information.

10. Process measurement data.

11. Verify measurement data.

12. Possess the ability to store data for at least five years.

Article 34. Data Measurement File Formats

1. Commonly used data measurement file formats are *.txt or *.csv.

2. The Data Measurement Management Unit shall be responsible for announcing standard file formats, interface standards, and types of metering devices that the Data Collection System and the Data Management System managed and operated by the unit can connect to and read data from.

Chapter V

TECHNICAL DESIGN, INVESTMENT, INSTALLATION, COMMISSIONING

MEASUREMENT SYSTEM AND DATA COLLECTION SYSTEM

Section 1

TECHNICAL DESIGN AGREEMENT FOR MEASUREMENT SYSTEM AND DATA COLLECTION SYSTEM FOR ELECTRICITY SUPPLY SYSTEMS OF 110KV AND ABOVE, HANDOVER BETWEEN DISTRIBUTION UNITS AND HANDOVER BETWEEN POWER PLANTS AND THE ELECTRICITY GRID

Article 35. Principles for Implementing Technical Design Agreements

1. For new electricity projects

a) The technical design agreement for the Measurement System and the Data Collection System serving handover and electricity trading shall be carried out during the technical design phase of the investment project immediately after reaching an agreement on connecting the electricity project to the grid.

b) Contents related to the technical design of the Measurement System and the Data Collection System must be unified before approving the technical design and the total construction cost estimate of the electricity project.

2. For operational electricity projects

a) The technical design agreement for the Measurement System and the Data Collection System shall be implemented when a new measurement point appears or when upgrading or renovating the existing Measurement System.

b) The technical design agreement for the Measurement System and the Data Collection System must be completed before purchasing or replacing equipment of the Measurement System.

3. Principles for Implementing Technical Design Agreements for the Measurement System and the Data Collection System

a) The investment unit of the Measurement System is responsible for preparing the application for the technical design agreement for the Measurement System and the Data Collection System.

b) Electricity Trading Company, Distribution Units, and Wholesale and Retail Electricity Units are responsible for hosting the technical design agreement for the Measurement System and the Data Collection System serving electricity handover within their management scope.

c) Other relevant units involved in electricity handover have the responsibility to cooperate and provide comments upon receiving requests for the technical design agreement for the Measurement System and the Data Collection System.

4. In cases where the Distribution Unit invests in the Measurement System and the Data Collection System to sell electricity to customers using the distribution network (except when the customer using the distribution network is a Power Generation Unit) or the Wholesale and Retail Electricity Unit invests in the Measurement System and the Data Collection System to sell electricity to customers, the Distribution Unit or the Wholesale and Retail Electricity Unit shall be responsible for designing and agreeing with customers on contents related to the technical design of the Measurement System and the Data Collection System before implementing investment and installation according to this Circular.

Article 36. Application Documents for Technical Design Agreement for the Measurement System and the Data Collection System

1. Request document for technical design agreement.

2. Copy of the approval document or connection agreement for the electricity project to the national power system.

3. Technical design documents for the Measurement System and the Data Collection System including:

a) General information about the electricity project, including location, scale, and main technical parameters, and expected operation time.

b) Documents related to the Measurement System, including:

- Main measurement points, backup measurement points;

- Installation locations and technical specifications of measuring devices (type, voltage, current, current and voltage ratio, accuracy level, capacity, and other parameters);

- Connection solutions and lead seal secondary circuit of the Measurement System;

- Installation location of the meter cabinet.

c) Documents related to the Data Collection System, including:

- Connection solution of the Data Collection System;

- Technical specifications of the Data Collection System equipment.

d) List and quantity of main equipment for the Measurement System to be invested in.

4. Related drawings, including:

a) Connection diagram of the electricity project to the national power system showing all technical parameters.

b) Principle diagram of measurement and protection of the electricity project.

c) Principle diagram of the Measurement System of the electricity project.

d) Layout plan of equipment belonging to the Measurement System of the electricity project.

đ) Connection diagram of the secondary circuit of the Measurement System, which may include the lead seal solution.

e) Connection diagram of the Data Collection System.

g) Cabinet diagram of the Measurement System, intermediate cabinets used for electricity measurement (if any).

5. Draft of the Technical Design Agreement for the Measurement System and the Data Collection System according to the model prescribed in Appendix 2 issued together with this Circular.

Article 37. Implementation of the technical design agreement for the Measurement System and Data Collection System

1. Responsibilities for drafting and submitting the Request File for the Technical Design Agreement of the Measurement System and Data Collection System

a) The investment unit of the measurement system shall be responsible for drafting and submitting the Request File for the Technical Design Agreement of the Measurement System and Data Collection System to the Electricity Trading Company in the following cases:

- Measuring at the boundary between large power plants and transmission grids or distribution grids;

- Measuring at the boundary between renewable energy power plants and the grid;

- Measuring at the boundary between transmission grids and distribution grids;

- Measuring at the boundary for electricity trade with foreign countries through voltage levels of 110 kV or higher;

- Measuring at the boundary between transmission grids and customers connected to the transmission grid.

b) The investment unit of the measurement system shall be responsible for drafting and submitting the Request File for the Technical Design Agreement of the Measurement System and Data Collection System to the Distribution Company in the following cases:

- Measuring at the boundary between small power plants and distribution grids;

- Measuring at the boundary between distribution grids and distribution and retail companies or customers connected to the distribution grid when the distribution and retail company or customer invests in the measurement system.

c) For measuring at the boundary between two distribution companies

- Measuring at the boundary between two Provincial Power Companies: The investment unit of the measurement system shall be responsible for drafting and submitting the Request File for the Technical Design Agreement of the Measurement System and Data Collection System to the Electricity Trading Company. The remaining unit shall be responsible for coordinating with the Electricity Trading Company during the agreement process;

- Measuring at the boundary between two provincial power companies under the same Provincial Power Corporation: The investment unit of the measurement system shall be responsible for drafting and submitting the Request File for the Technical Design Agreement of the Measurement System and Data Collection System to the Provincial Power Corporation. The remaining unit shall be responsible for coordinating during the agreement process.

d) For other cases not specified in Points a, b, and c of this Clause, implement according to the provisions of Clause 3, Article 35 of this Circular.

2. Procedure for implementing the technical design agreement for the Measurement System and Data Collection System

a) After drafting the file as stipulated in Article 36 of this Circular, the investment unit of the measurement system shall be responsible for sending three (3) copies of the Request File for the Technical Design Agreement of the Measurement System and Data Collection System to the Electricity Trading Company or the Distribution Company as stipulated in Clause 1 of this Article to proceed with the agreement;

b) The Electricity Trading Company or the Distribution Company shall be responsible for soliciting opinions from relevant power delivery and reception units on the proposed design agreement;

c) After receiving comments from relevant power delivery and reception units, the Electricity Trading Company or the Distribution Company shall be responsible for:

- Summarizing the opinions of relevant power delivery and reception units and evaluating the contents in the file: location of electrical energy measurement, technical design of the Measurement System and Data Collection System, method of power delivery and reception, draft of the Technical Design Agreement of the Measurement System and Data Collection System, and related contents;

- Sending written comments to the investment unit of the measurement system to perfect the draft of the Technical Design Agreement;

d) Based on the opinions of the Electricity Trading Company or the Distribution Company, the investment unit of the measurement system shall be responsible for reaching a consensus and perfecting the draft of the Technical Design Agreement of the Measurement System and Data Collection System as stipulated in this Circular;

đ) After reaching an agreement, the investment unit of the measurement system and the Electricity Trading Company or the Distribution Company shall be responsible for signing the Technical Design Agreement of the Measurement System and Data Collection System. The Technical Design Agreement of the Measurement System and Data Collection System shall be prepared in two (2) copies, each party holding one copy. The investment unit of the measurement system shall be responsible for sending a copy of the signed Technical Design Agreement of the Measurement System and Data Collection System to relevant power delivery and reception units.

3. Time for agreeing and signing the Technical Design Agreement of the Measurement System and Data Collection System for the contents stipulated in this Article shall be implemented according to the provisions of Article 38 of this Circular.

Article 38. Time for Agreement and Signing of Technical Design Agreement for the Measurement System and Data Collection System

The time for reaching consensus and signing the Technical Design Agreement for the Measurement System and Data Collection System is specified in the following Table:

Section 2

INVESTMENT AND INSTALLATION OF THE MEASUREMENT SYSTEM AND DATA COLLECTION SYSTEM FOR POWER VOLTAGES FROM 110 kV ONWARDS, BETWEEN DISTRIBUTION UNITS AND BETWEEN POWER PLANTS AND THE POWER GRID

Article 39. Requirements during Investment and Installation

1. Ensure that the Measurement System and Data Collection System comply with the provisions of this Circular and are consistent with the agreed technical design of the Measurement System and Data Collection System as stipulated in Section 1 of this Chapter.

2. Ensure that the measuring equipment complies with the legal regulations on measurement.

Measuring equipment put into use must comply with the approval procedures for measurement instrument models carried out by the competent state agency on measurement. In special cases, where measuring equipment within a cabinet or integrated installation has been invested but not yet approved and cannot be installed with additional external measuring equipment, the relevant units shall guide the Investment Unit for the Measurement System to follow the legal procedures for model approval in accordance with the legal regulations on measurement.

Article 40. Responsibilities of Units in Investment and Installation of the Measurement System and Data Collection System

1. Investment Unit for the Measurement System

a) Invest in and install the Measurement System and Data Collection System in accordance with the agreed technical design of the Measurement System and Data Collection System as stipulated in Section 1 of this Chapter;

b) Enter into a contract with the Testing and Inspection Unit to perform the following tasks:

- Initial testing and inspection of measuring equipment in accordance with this Circular and legal regulations on measurement;

- Testing the secondary circuit of the measurement system to ensure compliance with technical requirements for measurement and consistency with the technical design of the Measurement System;

- Sealing the Measurement System with lead seals to prevent tampering with the measurement circuit and measuring equipment without breaking the seal;

- Programming and setting operational parameters and meter password levels.

c) Provide information about the measurement points (location, method of supply and receipt, technical specifications) to the Data Management Unit and related Power Supply and Distribution Units;

d) Cooperate with the Data Management Unit in the installation and inspection of the Data Collection System at the measurement points and remotely.

2. Grid Management Unit is responsible for cooperating with the Investment Unit for the Measurement System and related units during the installation, initial testing, and inspection of the Measurement System and Data Collection System when the Measurement System is located at the Grid Management Unit's substation.

3. Data Management Unit

a) Issue location codes and address codes for new meters in the managed area;

b) Supplement the measurement database into the Data Management System within the managed area;

c) Cooperate with the Investment Unit for the Measurement System in the installation and inspection of the Data Collection System at the measurement points and data transmission paths from the power project to the Data Management System within the managed area;

d) Install software to encrypt measurement data after reading and transmitting to the local computer, preventing unauthorized interference and falsification of measurement data before it is transmitted to the Data Management System within the managed area.

4. Testing and Inspection Unit

Perform tasks according to the contract signed with the Investment Unit for the Measurement System including:

a) Initial testing and inspection of measuring equipment in accordance with this Circular and legal regulations on measurement;

b) Testing the secondary circuit of the measurement system to ensure technical accuracy and consistency with the technical design of the Measurement System;

c) Sealing the Measurement System with lead seals to prevent tampering with the measurement circuit and measuring equipment;

d) Programming and setting operational parameters and meter password levels within the authorized scope;

đ) Provide the Investment Unit for the Measurement System with test and inspection reports of the Measurement System and meter installation reports in accordance with this Circular and legal regulations on measurement.

Section 3

ACCEPTANCE OF THE MEASUREMENT SYSTEM AND DATA COLLECTION SYSTEM FOR POWER VOLTAGES FROM 110 kV ONWARDS, BETWEEN DISTRIBUTION UNITS AND BETWEEN POWER PLANTS AND THE POWER GRID

Article 41. Participants in the Acceptance Inspection

Depending on each metering handover case, the participants in the acceptance inspection include the following units:

1. The unit investing in the metering system.

2. Electricity Trading Company or Distribution Unit.

3. The unit managing the operation of the metering system.

4. The unit managing metering data.

5. Testing and certification unit.

6. Related electricity handover units.

Article 42. Documents for Acceptance Inspection

1. Technical documents

a) Test and certification certificates for CTs, VTs, and metering meters issued by the testing and certification unit;

b) Approval decision for metering meter models, CTs, VTs (if applicable);

c) Test reports for CTs, VTs, and measuring meters issued by testing and inspection units;

d) Inspection and test reports for the second circuit of the measurement system issued by testing and inspection units;

d) Installation parameter setting record of metering meters.

2. Completion acceptance record for installation of the Metering System.

3. Completion acceptance record for installation of the Data Collection System.

Article 43. Procedure for Conducting Acceptance Inspection

1. After completing the installation of the Metering System and the Data Collection System, at least 14 days before the planned acceptance date, the unit investing in the metering system shall be responsible for sending a request to conduct acceptance inspection along with one set of documents for acceptance inspection as stipulated in Article 42 of this Circular to the Electricity Trading Company or Distribution Unit and related electricity handover units.

2. Within three working days from the date of receiving the request to conduct acceptance inspection and documents for acceptance inspection, the Electricity Trading Company or Distribution Unit shall be responsible for checking the completeness and validity of the documents as stipulated in Article 42 of this Circular and perform the following tasks:

a) In case the documents comply with regulations and meet the conditions for conducting acceptance inspection, the Electricity Trading Company or Distribution Unit shall be responsible for sending a document to the participating acceptance inspection units to unify the acceptance inspection plan;

b) In case the documents do not meet the conditions for acceptance inspection, the Electricity Trading Company or Distribution Unit shall be responsible for sending a document requesting the unit investing in the metering system to supplement the documents and notify the participating acceptance inspection units.

3. After unifying the acceptance inspection plan, the unit investing in the metering system shall organize the implementation of acceptance inspection of the Metering System and the Data Collection System with the presence of representatives of the units specified in Article 41 of this Circular.

4. The unit investing in the metering system shall be responsible for collecting all acceptance inspection documents and sending one set of documents (copy) to each participating acceptance inspection unit.

5. Participating acceptance inspection units shall be responsible for retaining acceptance inspection documents, updating measurement point information into the handover metering position list and management program of their unit.

6. The metering system may only be put into operation when the participating acceptance inspection units unanimously agree on the acceptance inspection results and jointly sign the Acceptance Record.

Article 44. Main Contents During the Acceptance Inspection Process

1. The acceptance inspection process is carried out in two steps, specifically as follows:

a) Checking equipment installation before energization

- Checking technical documents of the Metering System and the Data Collection System;

- On-site inspection of the Metering System installation including: Checking primary equipment installation location, secondary circuit installation, metering device parameters, metering meter settings;

- Comparing the actual installation results of the Metering System on site with the agreed technical design of the Metering System, technical documents of metering devices, and metering meter installation records;

- Checking the compatibility of metering meter settings with the actual installed metering device parameters;

- Checking the actual installation parameters and configuration of the Data Collection System and comparing them with the agreed technical design of the Metering System;

- The testing and certification unit sets various password levels of the metering meters, retains the "Setting" password of the metering meters, hands over the "Read Only" password to the unit investing in the metering system or the owner of the metering system, and hands over the "Time Synchronization" password to the unit managing metering data;

- Finalizing meter readings, recording programming parameters of metering meters, number of installations, and the last programming time of metering meters;

- Sealing the CT, VT, secondary circuit metering, intermediate connections, test box to ensure that the Metering System cannot be tampered with without breaking the seal. The sealing must be witnessed by all parties involved in the acceptance inspection.

b) Checking the operation of the Metering System immediately after energization

- Checking current values, voltage values, phase angles between current and voltage;

- Analyzing and evaluating current values, voltage values, phase angles between current and voltage, combined with comparing the metered power of the metering meters with the actual load power;

- Checking the operation of the Data Collection System;

- After completing all inspection items, all parties confirm that the Metering System operates normally and proceed to seal the remaining parts of the Metering System;

- Upon completion of the acceptance inspection process, all participating acceptance inspection parties jointly sign the Acceptance Record according to the model prescribed in Appendix 3 attached to this Circular.

2. During the inspection of the Metering System operation under load, if errors leading to inaccurate operation of the Metering System are discovered, all units will cooperate to rectify the situation and determine the amount of electricity to be recovered or refunded.

3. In cases where the Metering System or the Data Collection System has not been fully accepted after energization of the project, all parties shall be responsible for preparing the first acceptance record noting existing issues, measures to address these issues, and the timeframe for rectification as a basis for subsequent acceptance inspections. Electricity handover during the period when the Metering System has not completed acceptance inspection will be recalculated for recovery or refund (if applicable) upon completion of the Metering System acceptance inspection.

Section 4

DESIGN, INSTALLATION AND ACCEPTANCE OF THE METERING SYSTEM AND DATA COLLECTION SYSTEM FOR ELECTRICITY HANDOVER TO CUSTOMERS CONNECTED TO DISTRIBUTION NETWORKS WITH MEDIUM VOLTAGE AND BELOW

Article 45. General Requirements for Design, Installation, and Acceptance of Metering Systems and Data Collection Systems

1. The provision of Metering Systems and Data Collection Systems (if applicable) shall depend on each electricity consumer, operational management needs, and electricity sales requirements.

2. Investment in and installation of Metering Systems must comply with the requirements for Metering Systems at medium voltage and below as stipulated in Chapter III of this Circular and relevant laws on measurement.

3. Responsibilities of Distribution Units and Distribution and Retail Units

a) To invest in and install Metering Systems and Data Collection Systems (if applicable) to meet the timely demand for installing, replacing metering equipment, and other devices and accessories necessary for selling electricity to Consumers;

b) To organize initial verification, periodic verification, and post-repair verification of metering equipment according to this Circular and relevant laws on measurement;

c) To accept and manage to ensure that metering equipment meets technical measurement requirements during use. Only metering equipment that has been approved, verified, and meets technical measurement requirements may be put into use.

Article 46. Design of Metering Systems and Data Collection Systems

1. Distribution Units or Distribution and Retail Units are responsible for designing Metering Systems and Data Collection Systems (if applicable) to serve electricity sales to Consumers simultaneously with the procedures for agreeing on grid connection and supplying electricity to Consumers connected to medium voltage and below according to the Distribution System Regulations issued by the Ministry of Industry and Trade, specifically as follows:

a) In cases of supplying electricity to Consumers connected to medium voltage: Within five working days from the date of receiving complete and valid grid connection application files of Consumers according to the Distribution System Regulations issued by the Ministry of Industry and Trade, Distribution Units or Distribution and Retail Units must complete the design of Metering Systems and Data Collection Systems;

b) In cases of supplying electricity for residential purposes connected to low voltage: Within seven working days from the date of receiving complete and valid grid connection application files of Consumers according to the Distribution System Regulations issued by the Ministry of Industry and Trade, Distribution Units or Distribution and Retail Units must complete the design of Metering Systems and Data Collection Systems (if applicable), sign contracts, and supply electricity to Consumers;

c) In cases of supplying electricity for non-residential purposes connected to low voltage: Within eight working days from the date of receiving complete and valid grid connection application files of Consumers according to the Distribution System Regulations issued by the Ministry of Industry and Trade, Distribution Units or Distribution and Retail Units are responsible for inspecting, surveying, designing Metering Systems and Data Collection Systems (if applicable), developing power supply plans for Consumers, signing contracts, and supplying electricity to Consumers.

2. In cases where Consumers connected to medium voltage invest in Metering Systems and Data Collection Systems (if applicable), Consumers are responsible for preparing technical designs and reaching consensus with Distribution Units or Distribution and Retail Units on the technical design of Metering Systems and Data Collection Systems. The maximum time to reach consensus on the technical design of Metering Systems and Data Collection Systems is five working days from the date Consumers submit complete technical design files.

Article 47. Suspension, Removal of Metering Systems

1. When suspending, removing, or installing Metering Systems, there must be a work permit or work order. Prior to suspending, removing, or installing the Metering System, the Electricity Distribution Unit or the Distribution and Retail Electricity Unit shall be responsible for checking the integrity of the measuring devices, seals, and seals; inspecting the operational status of the Metering System, recording the meter readings at the time of suspending or removing the measuring equipment; checking the CT and VT ratio settings, the number of the last programming, and the time of the last programming.

2. The results of suspending, removing, or installing the Metering System must be fully recorded in the Suspension, Removal, Installation Record of Measuring Equipment according to the model prescribed by the Electricity Distribution Unit or the Distribution and Retail Electricity Unit. The Suspension, Removal, Installation Record of Measuring Equipment must have the signatures of representatives of the Electricity Distribution Unit or the Distribution and Retail Electricity Unit and the signatures of representatives of the electricity-consuming Customer, established in two copies, each party retains one copy.

3. The Metering System and the Data Collection Metering System (if any) may only be put into use to serve the delivery and sale of electric energy without causing damage to the electrical equipment of the electricity-consuming Customer and ensuring human safety when the Electricity Distribution Unit or the Distribution and Retail Electricity Unit completes the suspension and removal of the Metering System and the Suspension, Removal, Installation Record of Measuring Equipment is signed unanimously by representatives of all parties.

Chapter VI

MANAGEMENT, OPERATION, AND HANDLING OF INCIDENTS IN THE METERING SYSTEM, DATA COLLECTION METERING SYSTEM, AND DATA MANAGEMENT SYSTEM

Section 1

MANAGEMENT, OPERATION OF THE METERING SYSTEM, DATA COLLECTION METERING SYSTEM, AND DATA MANAGEMENT SYSTEM

Article 48. Management, Operation of the Metering System

1. The unit managing and operating the metering system shall be responsible for managing, operating, maintaining, and repairing the Metering System within its jurisdiction to ensure accuracy, stability, reliability, and security.

2. During the management and operation process, the unit managing and operating the metering system shall be responsible for continuously monitoring and inspecting the operational status of the Metering Systems, promptly identifying any abnormal issues or potential incidents. In case of detecting abnormalities or incidents, the unit managing and operating the metering system must immediately notify relevant units to coordinate in handling, and the handling process must comply with the provisions set out in Section 2 of this Chapter.

3. Replacement of equipment or upgrading, renovation of the Metering System can only be carried out when all relevant units agree and reach consensus. For the Metering System selling electricity to electricity-consuming Customers connected to medium voltage or lower voltage levels, before carrying out replacement of equipment or upgrading, renovating the Metering System, the unit managing and operating the metering system shall be responsible for notifying the electricity-consuming Customer to cooperate in implementation.

4. The unit managing and operating the metering system or the unit owning the metering system shall be responsible for organizing the management of sealing and lead seals of the Metering System in accordance with this Circular and legal regulations on measurement.

5. Seals and inspection lead seals of measuring devices can only be removed when undergoing inspection, testing, and incident handling performed by the Testing and Inspection Unit, with the presence of representatives from relevant units.

6. The clock of the metering device and the Data Collection Metering System shall follow Vietnam Standard Time and be synchronized with the standard time source obtained from the Global Positioning System (GPS) or from a national standard time source suitable to the actual conditions of the data management unit.

7. For the Metering System serving the sale of electricity to electricity-consuming Customers, if any abnormality or incident is detected, the electricity-consuming Customer must notify the electricity supplier to take timely measures to handle it.

Article 49. Changing Parameters of the Metering System

1. In cases where metering electricity serves the transfer of electricity between power plants and the grid, or between transmission grids and distribution grids, or between distribution units, or between electricity consumers connected to voltage levels of 110 kV or higher and the grid,

a) At least five working days before the planned date for changing the parameters of the Metering System, the unit managing the operation of the metering system shall be responsible for notifying (along with relevant documents on the necessity to change the parameters of the Metering System) the Electricity Trading Company or the Distribution Unit and related transfer units;

b) Within two working days from receiving the notification from the unit managing the operation of the metering system, the Electricity Trading Company or the Distribution Unit and related transfer units shall be responsible for agreeing on the change or re-setting of the parameters of the Metering System, the implementation plan, or requesting the unit managing the operation of the metering system to supplement documents to have a complete basis for implementing the change of parameters of the Metering System;

c) The unit managing the operation of the metering system shall be responsible for leading the implementation of the change of parameters of the Metering System according to the agreed plan; the change of parameters of the Metering System must be carried out in accordance with legal regulations on measurement;

d) The Electricity Trading Company or the Distribution Unit and related transfer units shall be responsible for participating in the process of changing the parameters of the Metering System according to the agreed plan;

đ) Units must update the changed parameters of the Metering System into their own metering database. The unit managing metering data shall be responsible for updating into the Meter Data Collection System and the Meter Data Management System after receiving notification from the unit managing the operation of the metering system.

2. For metering electricity serving the transfer of electricity with electricity consumers connected to medium voltage levels or lower, the Distribution Unit or the Distribution and Retail Unit shall be responsible for changing the parameters of the Metering System but must notify the electricity consumer in advance about the reason to coordinate the implementation.

Article 50. Replacing Equipment of the Metering System

1. In cases where metering electricity serves the transfer of electricity between power plants and the grid, or between transmission grids and distribution grids, or between distribution units, or between electricity consumers connected to voltage levels of 110 kV or higher and the grid, when it is necessary to replace equipment or upgrade, renovate the Metering System, the unit managing the operation of the metering system shall be responsible for leading the implementation of specific contents as follows:

a) Except for urgent cases stipulated in Clause 3, Article 53 of this Circular, when replacing equipment of the Metering System due to malfunction or abnormal operation, if the technical specifications of the replacement equipment are equivalent to those of the old equipment or comply with agreements with related units, the replacement procedure shall be carried out as follows:

- At least five working days before the planned date, the unit managing the operation of the metering system shall be responsible for notifying (along with relevant documents) the Electricity Trading Company or the Distribution Unit and related transfer units of the plan to replace and inspect the Metering System;

- Within two working days from receiving the notification from the unit managing the operation of the metering system, the Electricity Trading Company or the Distribution Unit and related transfer units shall be responsible for agreeing on the replacement and inspection plan with the unit managing the operation of the metering system;

- The unit managing the operation of the metering system shall lead the organization to replace and inspect the Metering System according to the agreed plan.

b) For cases of replacing equipment of the Metering System during upgrading or renovating the Metering System

- Implement technical design agreements, investment, installation, and inspection of replacement equipment as stipulated in Chapter V of this Circular;

- The unit managing metering data and related transfer units shall be responsible for updating the changed parameters of the Metering System into the metering database, the Meter Data Collection System, and the Meter Data Management System.

2. In cases where metering electricity serves the transfer of electricity with electricity consumers connected to medium voltage levels or lower, the Distribution Unit or the Distribution and Retail Unit shall be responsible for replacing equipment of the Metering System as stipulated in Article 47 of this Circular and must notify the consumer in advance about the reason. When replacing equipment of the Metering System, there must be the presence and confirmation of a representative of the electricity consumer.

Article 51. Work at the site

When implementing changes to parameters or replacement of equipment of the Metering System, participating units shall be responsible for performing the following tasks:

1. Inspect the sealing status and operation of the Metering System.

2. Record meter readings, calculate production volumes during cycles not through the Metering System.

3. Calculate追加翻译结果：

recovery (if applicable).

4. Prepare a record of parameter changes, equipment replacement, or removal of the metering point, which must include the following information: metering point location, time of implementation, meter readings before and after hanging and removing, and details of work performed. The confirmation record must have signatures from representatives of participating units.

Article 52. Operation of the Data Collection System and the Data Management System

1. The unit managing and operating the metering system is responsible for managing and operating the Data Collection System at the metering point, including communication devices, computers (if any), and programs for reading meter data to ensure full and accurate data updates from meters at the metering points within its management scope and transmission to the Data Collection System and the Data Management System of the unit managing meter data for inclusion in the common database.

Section 2

HANDLING INCIDENTS OF THE METERING SYSTEM, DATA COLLECTION SYSTEM AND DATA MANAGEMENT SYSTEM

Article 53. Incidents of the Metering System, Data Collection System and Data Management System

1. The unit managing and operating the metering system and the unit managing meter data are responsible for leading and coordinating with related units in resolving incidents of the Metering System, Data Collection System and Data Management System within their management scope, except in urgent cases as stipulated in Clause 3 of this Article.

2. The process of handling incidents of the Metering System must involve participation and witnessing by representatives of the Electricity Trading Company or the Distribution Company or the Distribution and Retail Company and related power supply and receiving units; it must be recorded in a working record and signed by representatives of participating units, except in urgent cases as stipulated in Clause 3 of this Article.

3. In emergency situations where incidents with the Metering System may endanger people or equipment, the unit managing and operating the metering system has the authority to handle the incident proactively but must immediately notify the Electricity Trading Company or the Distribution Company or the Distribution and Retail Company and related power supply and receiving units and must perform the following tasks:

a) Prepare a detailed record of incident information and remedial measures including the following contents: time of incident occurrence, incident status, time taken to resolve, meter readings at the time of incident and after recovery. The record must have the signature of an authorized representative of the unit managing and operating the metering system;

b) Coordinate with the Electricity Trading Company or the Distribution Company or the Distribution and Retail Company and related power supply and receiving units to carry out procedures for sealing and calculating recovered and refunded electricity consumption according to regulations.

4. Recovered and refunded electricity consumption during the period when the Metering System is affected by an incident must be calculated uniformly by the Electricity Trading Company or the Distribution Company or the Distribution and Retail Company and related power supply and receiving units.

Article 54. Handling of Metering System Incidents

1. Upon receiving notification of a Metering System incident, the Metering System Operation Management Unit shall be responsible for:

a) Notifying the Electricity Trading Company or the Distribution Company and related Power Delivery and Reception Units, the Metering System Owner, and the Metering Data Management Unit;

b) Leading and coordinating with related Power Delivery and Reception Units to determine the cause of the incident and propose measures to address the Metering System incident.

2. In cases where metering devices need replacement and calibration due to incidents, the Metering System Owner shall be responsible for signing a contract with the Testing and Calibration Unit to perform relevant tasks.

3. At the incident site, units participating in handling the incident shall carry out the following tasks:

a) The Metering System Operation Management Unit and the Metering System Owner shall be responsible for providing relevant documentation and data to support the determination of the cause and resolution of the Metering System incident, including: Metering System operation logs, meter readings recorded at the time before the incident occurred;

b) After determining the cause and proposing measures to address the incident, the Metering System Operation Management Unit shall coordinate with the Metering System Owner to resolve the Metering System incident, specifically as follows:

- In cases where metering equipment is damaged, the Metering System Owner shall lead and coordinate with the Metering System Operation Management Unit to replace or repair the equipment within the shortest possible time to ensure compliance with the requirements set forth in this Circular and return to normal operation. Replacement or repair must be carried out in accordance with the provisions of Article 50 of this Circular;

- In cases where immediate resolution of the incident is not possible, the Metering System Operation Management Unit shall lead and coordinate with related Power Delivery and Reception Units to determine a temporary metering solution (if necessary).

c) Inspect and accept the Metering System after resolving the incident;

d) In cases where the Metering System incident leads to inaccurate meter reading data and electricity volume exchange, the Metering System Operation Management Unit shall lead and coordinate with related units to estimate and agree on meter reading data and electricity volume exchange through a record as the basis for electricity payment;

đ) The Metering System Operation Management Unit shall be responsible for preparing a record of incident handling and resolution. The record must be agreed upon by all participating units and signed by representatives of these units to confirm.

4. For low-voltage Metering System incidents, immediately upon discovery or notification by the electricity consumer about the incident or abnormality, the Distribution Company or the Distribution and Retail Company shall be responsible for leading and coordinating with the electricity consumer to resolve the incident as soon as possible.

Article 55. Handling of Incidents in the Meter Data Collection System and Meter Data Management System

1. During the management and operation of the Meter Data Collection System and Meter Data Management System, if a unit discovers errors or incidents that prevent remote data access, it shall immediately notify the Metering System Operation Management Unit and the Meter Data Management Unit to coordinate in handling and resolving the issue. Upon receiving the information, the Metering System Operation Management Unit and the Meter Data Management Unit shall be responsible for contacting related units to conduct inspections, identify errors or incidents, and promptly implement corrective measures.

2. After inspection, if errors are found at any stage, the unit responsible for that stage must urgently address and resolve them to restore the operational status of the Meter Data Collection System or Meter Data Management System as quickly as possible.

3. After the Meter Data Collection System or Meter Data Management System has been restored following the incident, the Metering System Operation Management Unit and the Meter Data Management Unit shall be responsible for implementing measures to collect meter data and submit it to the Meter Data Management Unit to supplement missing data during the system incident period.

4. In cases where the Meter Data Collection System incident cannot be resolved, the Metering System Operation Management Unit shall be responsible for directly collecting meter data at the site and using appropriate methods (email, fax) to promptly transmit the data to the Meter Data Management Unit for updating into the system-wide metering database.

5. In cases where the Meter Data Collection System and Meter Data Management System errors or incidents result in unreadable meter data or incorrect readings, the Meter Data Management Unit must coordinate with the Metering System Operation Management Unit and related units to collect accurate meter data for recovery and refund purposes. Accurate meter data must be updated into the Meter Data Management Unit's metering database.

Section 3

CALIBRATION OF METERING DEVICES

Article 56. General Provisions on Calibration of Measuring Instruments

1. Calibration of measuring instruments includes initial calibration, periodic calibration, post-repair calibration, and calibration upon request.

2. Measuring instruments may only be put into use after being calibrated in accordance with the provisions of the law on measurement and meeting all requirements stipulated in this Circular.

3. Initial calibration is the first calibration performed on measuring instruments before they are put into use. Within the scope of management, the Investment Unit of the metering system shall bear the entire cost for initial calibration of measuring instruments.

4. Periodic calibration shall be carried out according to the cycle prescribed by the State management agency on measurement or as stipulated in the power purchase and sale contract but must not contravene the provisions of the law on measurement. The owner of the metering system shall bear the entire cost for periodic calibration of measuring instruments.

5. Post-repair calibration shall be carried out in accordance with the provisions of the law on measurement.

6. Calibration upon request shall be carried out in the following cases:

a) Calibration at the request of the owner of the metering system;

b) Calibration at the request of the power delivery and receipt unit related to the metering system that does not own or invest in the metering system, except for the case provided for in Point c Clause of this Article;

c) In the case where the electricity consumer requests the implementation of calibration of the measuring instrument currently used to sell electricity to the consumer, the Electricity Distribution Unit or the Electricity Distribution and Retail Unit and the electricity consumer shall have the responsibility to cooperate in accordance with the provisions of Clause 3, Clause 4 Article 25 of the Electricity Law and Article 19 Decree No. 137/2013/ND-CP dated October 21, 2013 of the Government detailing a number of articles of the Electricity Law and the Law amending and supplementing a number of articles of the Electricity Law.

7. The investment unit of the metering system or the owner of the metering system shall be responsible for collecting all calibration records (Calibration Certificate and Working Report) and submitting one set of records to the Data Management Unit and each participating calibration unit.

8. The Data Management Unit and the participating calibration units shall be responsible for retaining calibration records, updating measurement point information into the list of measurement positions and the unit's management program.

Article 57. Participants in Calibration of High Voltage Measuring Instruments

Depending on the specific metering delivery and calibration purpose, the participants in the calibration of measuring instruments may include:

1. The owner of the metering system or the investment unit of the metering system.

2. Electricity Trading Company or Distribution Unit.

3. The unit managing the operation of the metering system.

4. Testing and calibration units.

5. Related power delivery and receipt units.

Article 58. Periodic Calibration of High Voltage Measuring Instruments

1. Before December 5th each year, the System Operation Management Unit shall coordinate with the owner of the metering system to notify the related power delivery and receipt units and testing and calibration units of the periodic calibration plan for each month of the following year.

2. Before December 20th each year, based on the periodic calibration plan sent by the System Operation Management Unit, the related power delivery and receipt units and testing and calibration units shall be responsible for unifying the periodic calibration plan for the following year.

3. In the event of changes to the annual periodic calibration plan, before the last day of the quarter in each year, the System Operation Management Unit shall coordinate with the owner of the metering system to update and unify the plan with the related power delivery and receipt units and testing and calibration units for the remaining months of the year.

4. Based on the unified next-year periodic calibration plan and quarterly updated plans, at least ten days prior to the scheduled periodic calibration date, the System Operation Management Unit shall be responsible for notifying the time of periodic calibration to the units specified in Article 57 of this Circular.

5. The System Operation Management Unit shall be responsible for organizing and coordinating with the owner of the metering system to carry out periodic calibration of measuring instruments; the testing and calibration unit shall perform calibration in accordance with the provisions of the law on measurement and the signed contract with the System Operation Management Unit or the owner of the metering system.

6. In the event that the results of periodic calibration show that the measuring instrument does not meet the requirements stipulated in this Circular and technical requirements under the law on measurement, the owner of the metering system must replace the measuring instrument as soon as possible.

Article 59. Calibration on Request for High Voltage Measuring Equipment

1. Cases of calibration on request by the Owner of the Measurement System

a) The Owner of the Measurement System shall notify the relevant Power Supply and Reception Units at least 10 days before the planned date of calibration on request. Within three days from the date of receipt of the notification, the relevant Power Supply and Reception Units shall send their opinions to the Owner of the Measurement System regarding the calibration plan;

b) Calibration on request can only be carried out after the relevant Power Supply and Reception Units have agreed on the plan;

c) The Owner of the Measurement System shall bear all costs for calibration on request.

2. Cases of calibration on request by the relevant Power Supply and Reception Unit that does not own or invest in the Measurement System, except for cases stipulated in Point c Clause 6 Article 56 of this Circular

a) The relevant Power Supply and Reception Unit requesting calibration shall notify the Owner of the Measurement System and other relevant Power Supply and Reception Units at least 10 days before the planned date of calibration. Within three days from the date of receipt of the notification, the Owner of the Measurement System and other relevant Power Supply and Reception Units shall send their opinions to the relevant Power Supply and Reception Unit requesting calibration;

b) Calibration on request can only be carried out after the relevant Power Supply and Reception Units have agreed on the plan;

c) Costs for calibrating measuring equipment

- In case the measuring equipment meets the requirements specified in this Circular and technical requirements under the law on measurement after calibration on request, the requesting unit shall pay all calibration costs;

- In case the measuring equipment does not meet the requirements specified in this Circular and technical requirements under the law on measurement after calibration on request, the Owner of the Measurement System shall pay all calibration costs.

3. The Owner of the Measurement System shall organize the calibration on request of the measuring equipment. The testing and calibration units shall carry out calibration in accordance with the provisions of the law on measurement and the contract signed with the Owner of the Measurement System.

4. In case the results of calibration on request show that the measuring equipment does not meet the requirements specified in this Circular and technical requirements under the law on measurement, the Owner of the Measurement System must replace the measuring equipment as soon as possible.

Article 60. Post-Repair Calibration of High Voltage Measuring Equipment

1. After repair, the measuring equipment must be calibrated to ensure compliance with the requirements specified in this Circular and technical requirements under the law on measurement.

2. The Owner of the Measurement System or the Management Unit of the Measurement System shall be responsible for organizing the post-repair calibration of the measuring equipment in accordance with the law on measurement.

3. The procedures and contents of post-repair calibration shall be carried out in accordance with the provisions of the law on measurement.

Article 61. Implementation of Calibration for High Voltage Measuring Equipment

1. In cases where energy measurement serves power supply and reception between power plants and the grid, or between transmission grids and distribution grids, or between distribution units, or between customers connected to voltage levels of 110 kV and above and the grid, the calibration procedures for measuring equipment shall be carried out as follows:

a) Participating units check the lead seals and operational status of the measuring equipment before calibration;

b) Participating units synchronize meter readings and remove lead seals;

c) The testing and calibration unit retrieves meter data, connects the calibration circuit diagram, and conducts calibration of the measuring equipment according to the meter calibration procedure prescribed by the state management agency on measurement;

d) The testing and calibration unit re-establishes the measuring equipment, connects information between the meter and the data collection system, and re-seals the measuring system;

đ) The testing and calibration unit and participating units are responsible for calculating additional electricity consumption and unmetered electricity (if any) during the calibration process;

e) Prepare a working record with signatures from representatives of participating units.

2. In cases where energy measurement serves power supply and reception with customers connected to medium voltage levels, the Distribution Unit or the Distribution and Retail Unit organizes the calibration of measuring equipment according to the following procedures:

a) Coordinate with the customer to check the lead seals and operational status of the measurement system, synchronize meter readings and remove lead seals before conducting calibration or periodic replacement;

b) Organize calibration or periodic replacement in accordance with the law on measurement;

c) Re-establish the measurement system for the customer and re-seal the measurement system;

d) Prepare a working record with signatures from representatives of the parties involved.

Article 62. Requirements for Testing Low Voltage Metering Equipment

In addition to the testing requirements for metering equipment stipulated in Article 56 of this Circular, testing of low voltage metering equipment must meet the following requirements:

1. Annually, the Distribution Unit or the Distribution and Retail Unit shall develop a plan to regularly test metering equipment currently in use for selling electricity to customers within their management scope.

2. The Distribution Unit or the Distribution and Retail Unit shall bear all costs for initial testing, regular testing, and post-repair testing of metering equipment to ensure that the metering equipment operates normally and meets technical requirements as prescribed by laws on measurement and the provisions of this Circular.

Article 63. Regular Testing of Low Voltage Metering Equipment

1. Regular testing of metering equipment can be conducted on-site or in a laboratory. In the case of laboratory testing, the Distribution Unit or the Distribution and Retail Unit must install alternative metering equipment meeting the standards prescribed by laws on measurement to replace the metering equipment being removed.

2. The Distribution Unit or the Distribution and Retail Unit shall replace or conduct regular testing of metering equipment according to the following procedures:

a) Coordinate with the customer to check the lead seals and operational status of the measurement system, synchronize meter readings and remove lead seals before conducting calibration or periodic replacement;

b) Organize calibration or periodic replacement in accordance with the law on measurement;

c) Re-establish the measurement system for the customer and re-seal the measurement system;

d) Prepare a working record with signatures from representatives of the parties involved.

Chapter VII

COLLECTION, PROCESSING OF MEASUREMENT DATA AND ELECTRIC ENERGY TRANSFER

Article 64. Principles of Electric Energy Transfer and Data Collection

The main principles in electric energy transfer for payment purposes include:

1. Electric energy transfer for payment purposes must be determined through the Measurement System in accordance with the agreed method of electric energy transfer between the seller and buyer.

2. Electric energy transfer for payment purposes shall be collected using one of the two methods prescribed in Article 70 of this Circular.

3. The location of electric energy measurement and the Measurement System shall be determined in accordance with the provisions of Chapter III of this Circular.

Section 1

METHODS OF ELECTRIC ENERGY TRANSFER

Article 65. Principles and Basis for Establishing Methods of Electric Energy Transfer

1. Principles for establishing methods of electric energy transfer

a) The method of electric energy transfer reflects the relationship between units in the transfer of electric energy; the method of electric energy transfer must ensure the accurate determination of the volume of electric energy transferred between the seller and buyer;

b) At each measurement point, the method of electric energy transfer must clearly indicate the unit transferring the energy and the direction of energy transfer, the formula for determining and aggregating the volume of electric energy through one or more related measurement points as the basis for confirming the volume of energy transferred;

c) During the technical design agreement process of the Measurement System, the principles, requirements, and feasibility of the method of electric energy transfer must be considered;

d) It is permissible to combine multiple Measurement Systems to accurately determine the volume of electric energy transferred in specific cases.

2. Basis for establishing methods of electric energy transfer includes:

a) Primary diagrams of substations or power plants;

b) Diagrams of the grid wiring in the area;

c) Technical design agreements for the Measurement System, locations of electric energy measurement (primary measurement points, backup measurement points, or related measurement points);

d) Official operation or decommissioning dates of the Measurement System.

Article 66. Establishing Methods for Power Supply and Reception

1. The methods for power supply and reception shall be newly established or adjusted in the following cases:

a) New metering point is established;

b) Metering point is abolished;

c) The unit for power supply and reception is changed.

2. Establishing new methods for power supply and reception

a) Within their management scope, the Electricity Trading Company or Distribution Unit or Retail and Distribution Unit shall take the lead in establishing new methods for power supply and reception at metering points that have been agreed upon in the Technical Design Agreement of the Metering System and notify the Investment Unit of the Metering System and related power supply and reception units in writing;

b) The Investment Unit of the Metering System and related power supply and reception units shall be responsible for agreeing on the new methods for power supply and reception in writing and sending it to the leading unit in establishing the methods for power supply and reception (Electricity Trading Company or Distribution Unit or Retail and Distribution Unit).

3. Adjusting methods for power supply and reception

a) Adjusting methods for power supply and reception shall be carried out in the following cases: Changing the wiring of the power grid or changing the management and operation range and power supply and reception between units;

b) The owner of the metering system or the management unit of the metering system shall be responsible for notifying in writing the reasons and proposals for adjusting the methods for power supply and reception (abolishing the metering point or changing the unit for power supply and reception), along with relevant documents to the leading unit in establishing the methods for power supply and reception and related power supply and reception units;

c) Based on the notification document and attached documents, within their management scope, the Electricity Trading Company or Distribution Unit or Retail and Distribution Unit shall take the lead in reviewing the adjustment of the methods for power supply and reception and send a notification document to the owner of the metering system or the management unit of the metering system and related power supply and reception units about the adjustment of the methods for power supply and reception, along with the organized implementation plan that has been agreed upon.

4. The methods for power supply and reception notified by the Electricity Trading Company or Distribution Unit or Retail and Distribution Unit serve as the basis for the parties to implement power supply and reception and aggregate power consumption. In case a related power supply and reception unit has not yet reached an agreement, during the waiting period, the previously notified methods for power supply and reception by the Electricity Trading Company or Distribution Unit or Retail and Distribution Unit shall continue to be applied.

Section 2

INSTALLATION OR REMOVAL OF POWER SUPPLY AND RECEPTION METERING POINTS

Article 67. Principles and Basis for Including Metering Points in Power Supply and Reception

The metering system at the metering point can only be included as a basis for power supply and reception when it meets the requirements stipulated in this Circular, technical requirements according to the law on measurement, is inspected and accepted according to regulations, and completes the procedures for including the metering point in power supply and reception as prescribed in Article 68 of this Circular.

Article 68. Including Metering Points in Power Supply and Reception

1. In the case of power supply and reception between power plants and the power grid or between transmission grids and distribution grids or between distribution units or between electricity consumers connected to voltage levels of 110 kV and above and the power grid, based on the acceptance documents of the metering system as stipulated in Article 42 of this Circular, within their management scope, the Electricity Trading Company or Distribution Unit or Retail and Distribution Unit shall notify related power supply and reception units about the method of power supply and reception, the initial time and period for aggregating power supply and reception of the metering point, the appendix for finalizing meter readings, and the power supply and reception summary form.

2. In the case of power supply and reception with electricity consumers connected to medium voltage and below, the metering point can only be included in power supply and reception after completing the procedures as stipulated in Article 47 of this Circular.

3. Related power supply and reception units and the data management unit of the metering system shall be responsible for updating the metering points, technical parameters of the metering system, and the methods for power supply and reception.

Article 69. Revocation of Metering Positions

1. In cases where electricity is exchanged between power plants and transmission grids, or between transmission grids and distribution grids, or among distribution units, or between electricity consumers connected to voltage levels of 110 kV or higher and the grid,

a) When there is a request to revoke one or more metering positions for electricity exchange, the metering system owner unit or the metering system operation management unit shall be responsible for notifying in writing the plan to revoke the metering position to the main unit revoking the metering position for electricity exchange (Electricity Trading Company or Distribution Unit or Distribution and Retail Unit) and related electricity exchange units at least 10 working days before the date of revoking the metering position;

b) Within five working days, within their scope of management, the Electricity Trading Company or Distribution Unit or Distribution and Retail Unit shall be responsible for notifying the related units to agree on the revocation of the metering position and the implementation plan, or requesting the metering system owner unit or the metering system operation management unit to supplement the documentation to have sufficient grounds to determine the revocation of the metering position;

c) Depending on specific circumstances and the purpose of electricity exchange, the units participating in the revocation of the metering position may include:

- The metering system owner unit;

- The metering system operation management unit;

- The Electricity Trading Company or Distribution Unit or Distribution and Retail Unit;

- Testing and certification unit;

- Metering data management unit;

- Electricity consumer.

d) Upon completion of the revocation of the metering position, the metering system owner unit or the metering system operation management unit shall be responsible for sending a revocation notice of the metering position to related electricity exchange units to update in the database.

2. In cases where electricity is exchanged with electricity consumers connected to medium voltage levels or lower, the Distribution Unit or Distribution and Retail Unit shall be responsible for revoking the metering position upon receiving a request from the electricity consumer.

3. Based on the revocation documentation of the metering position, related electricity exchange units and the metering data management unit shall carry out the revocation of the metering position, the method of electricity exchange in the electricity exchange management system, and the list of boundary metering positions within their scope of management.

4. Total electricity when revoking the metering position: The amount of electricity exchanged is calculated up to the meter reading index recorded in the final meter reading record by all relevant parties.

Section 3

COLLECTION, PROCESSING AND STORAGE OF METERING DATA

Article 70. Method of Collecting Metering Data

Depending on specific conditions and infrastructure systems, related electricity exchange units may apply one of the following methods of collecting metering data:

1. On-site recording (collecting at the metering position) is a method of collecting metering data using one of the following means: Meter reading book, handheld meter reading device.

2. Remote recording (remote collection of metering data) is a method of remotely collecting metering data through wired or wireless transmission environments.

Article 71. Requirements for On-Site Recording Method

1. Record all index numbers of metering devices listed in the metering point handover list between units.

2. Record according to the specified cycle, on the correct date, at the designated time.

3. Accurately and clearly record all digits displayed on the screen or in the counter of the metering device.

4. The metering device index numbers and related parameters read and confirmed must meet the requirements for payment file establishment.

5. Conduct recording of metering device index numbers and aggregate energy handover at the metering points for Metering Systems within the property and operational management scope or within the energy handover range of the unit.

Article 72. Requirements for Remote Recording Method

1. Data collected from metering devices include metering device data and information stored over a defined period that meets the requirements for payment file establishment and operational management.

2. Record all index numbers of metering devices listed in the metering point handover list between units.

3. Record according to the specified cycle, on the correct date, at the designated time.

4. Accurately record all digits displayed on the screen or in the counter of the metering device.

5. Conduct recording of metering device index numbers and aggregate energy handover at the metering points for Metering Systems within the property and operational management scope or within the energy handover range of the unit.

Article 73. Reading and Transmitting Metering Data

1. The reading and transmission of metering data for energy handover must be conducted through one or more of the following methods:

a) Method 1: The unit managing the metering system collects metering data from metering devices via the Metering Data Collection System within its management scope. Subsequently, this metering data is transmitted to the Unit managing metering data.

b) Method 2: The Unit managing metering data synchronizes time and directly collects metering data from all metering devices within its management scope via the Metering Data Collection System and the Metering Data Management System managed by the unit managing the metering system.

2. Daily, the Unit managing the metering system is responsible for monitoring and checking the meter reading system at the metering points to ensure that metering device data at these points is fully and accurately transmitted to the Metering Data Collection System (if applicable) and to the Unit managing metering data via the Metering Data Management System. In case of failure or other reasons leading to unreadable data, incomplete data, or inaccurate data, the Unit managing the metering system is responsible for immediately informing the Unit managing metering data about the information and reasons through email, phone, or fax.

3. If remote metering data collection cannot be performed, it must switch to on-site data collection, while simultaneously checking the operation status of the metering devices and the Metering Data Collection System.

4. Daily, the Unit managing metering data is responsible for verifying the completeness and accuracy of the metering data collected from all metering devices.

Article 74. Processing Metering Data

1. The Unit managing metering data is responsible for processing the collected metering data to ensure accuracy and consistency with actual energy handover at metering points; coordinating with the Unit managing the metering system and relevant energy handover Units during the metering data processing process.

2. The Unit managing the metering system and relevant energy handover Units are responsible for providing detailed information about the results of handling incidents or calibration that affect metering data to the Unit managing metering data to assist in processing the collected metering data.

3. Hàng tháng, Đơn vị quản lý số liệu đo đếm thực hiện đối chiếu giữa tổng sản lượng điện năng đo đếm thu thập theo chu kỳ xác định với sản lượng điện năng chốt hàng tháng.

4. Cục Điều tiết điện lực có trách nhiệm tổ chức xây dựng và ban hành các Quy trình về thu thập, xử lý và quản lý số liệu đo đếm phù hợp với từng mục đích giao nhận điện năng phục vụ thanh toán.

Điều 75. Kiểm toán Đơn vị quản lý số liệu đo đếm

1. Đơn vị quản lý số liệu đo đếm có trách nhiệm tổ chức kiểm toán các quy trình thực hiện, phần mềm và chương trình phục vụ thu thập, xử lý và lưu trữ số liệu đo đếm trong các trường hợp sau:

a) Kiểm toán định kỳ: Kiểm toán được thực hiện hàng năm;

b) Kiểm toán theo yêu cầu: Kiểm toán được thực hiện khi có yêu cầu của Đơn vị giao nhận điện liên quan. Chi phí kiểm toán theo yêu cầu do bên đề nghị chi trả.

2. Nội dung, trình tự thực hiện kiểm toán đối với Đơn vị quản lý số liệu đo đếm được thực hiện theo các quy định pháp luật.

Điều 76. Lưu trữ và quản lý số liệu đo đếm

1. Đơn vị quản lý số liệu đo đếm chịu trách nhiệm tổng hợp các số liệu đo đếm phục vụ giao nhận giữa các đơn vị sau khi đã hoàn thành quá trình xử lý và xác thực số liệu.

2. Đơn vị quản lý số liệu đo đếm có trách nhiệm thực hiện lưu trữ tối thiểu các dữ liệu sau đây:

a) Số liệu điện năng thu thập từ các công tơ đo đếm trước khi xử lý số liệu;

b) Số liệu điện năng của từng công tơ đo đếm sau khi đã xử lý số liệu;

c) Số liệu điện năng giao nhận tổng hợp theo ngày, tháng, năm của từng đơn vị.

3. Thời hạn lưu trữ các số liệu đo đếm quy định tại Khoản 2 Điều này ít nhất là 05 năm.

Chương VIII

TỔ CHỨC THỰC HIỆN

Điều 77. Quy định về chuyển tiếp

1. Đối với Hệ thống đo đếm có cấp điện áp từ 110 kV trở lên hoặc đo đếm giữa nhà máy điện với lưới điện đã vận hành hoặc có hợp đồng mua sắm, lắp đặt thiết bị được ký trước ngày Thông tư này có hiệu lực mà chưa đáp ứng các yêu cầu quy định tại Thông tư này, các đơn vị có trách nhiệm đầu tư, nâng cấp thiết bị đo đếm đáp ứng các yêu cầu quy định tại Thông tư này khi thiết bị đo đếm hết thời hạn sử dụng hoặc phải thay thế.

2. Đối với Hệ thống đo đếm hiện hữu cấp điện áp trung áp hoặc công tơ đo đếm 03 pha cấp điện áp hạ áp mà chưa đáp ứng các yêu cầu quy định tại Thông tư này, trong thời hạn 05 năm kể từ ngày Thông tư này có hiệu lực, các đơn vị có trách nhiệm đầu tư, nâng cấp thiết bị đo đếm đáp ứng các yêu cầu quy định tại Thông tư này.

3. Trường hợp không thực hiện đúng quy định tại Khoản 1 và Khoản 2 Điều này, đơn vị phải báo cáo Cục Điều tiết điện lực để xem xét, giải quyết theo thẩm quyền hoặc báo cáo Bộ Công Thương để giải quyết.

Điều 78. Tổ chức thực hiện

1. Cục Điều tiết điện lực có trách nhiệm phổ biến, hướng dẫn và kiểm tra việc thực hiện Thông tư này. Trong quá trình thực hiện, tổ chức nghiên cứu, xây dựng và ban hành Quy trình hướng dẫn và yêu cầu kỹ thuật đối với hệ thống đo đếm hai chiều (Net Metering) để phục vụ mua bán, giao nhận điện năng giữa Khách hàng sử dụng điện đầu tư hệ thống điện mặt trời lắp mái với lưới điện quốc gia.

2. Tập đoàn Điện lực Việt Nam có trách nhiệm chỉ đạo các đơn vị trực thuộc thực hiện Thông tư này.

3. Đơn vị đầu tư hệ thống đo đếm, Đơn vị sở hữu hệ thống đo đếm và các Đơn vị giao nhận điện liên quan có trách nhiệm xây dựng kế hoạch đầu tư, nâng cấp và cải tạo Hệ thống đo đếm, thiết bị đo đếm trong phạm vi quản lý đảm bảo đáp ứng các yêu cầu quy định tại Thông tư này.

4. Trong quá trình thực hiện, nếu xảy ra tranh chấp giữa các đơn vị liên quan đến việc thực hiện Thông tư này, các đơn vị có quyền trình vụ việc lên Cục Điều tiết điện lực để giải quyết theo quy định về trình tự, thủ tục giải quyết tranh chấp trong hoạt động điện lực do Bộ Công Thương ban hành.

Điều 79. Hiệu lực thi hành

1. Thông tư này có hiệu lực kể từ ngày 18 tháng 01 năm 2016.

2. Bãi bỏ các nội dung quy định tại Chương IX Thông tư số 12/2010/TT- BCT ngày 15 tháng 4 năm 2010 của Bộ Công Thương quy định hệ thống điện truyền tải và Chương II, Chương III và Chương IV Thông tư số 27/2009/TT- BCT ngày 25 tháng 9 năm 2009 của Bộ Công Thương quy định đo đếm điện năng trong thị trường phát điện cạnh tranh.

3. Đối với các vấn đề về đo đếm điện năng phát sinh trong thị trường điện theo từng cấp độ, Cục Điều tiết điện lực có trách nhiệm nghiên cứu, đề xuất Bộ Công Thương xem xét sửa đổi, bổ sung Thông tư hoặc có hướng dẫn cụ thể.

4. Trong quá trình thực hiện Thông tư này, nếu có vấn đề vướng mắc, nội dung mới phát sinh, các đơn vị có liên quan có trách nhiệm báo cáo Cục Điều tiết điện lực để nghiên cứu, đề xuất, trình Bộ Công Thương sửa đổi, bổ sung Thông tư cho phù hợp./.