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THE
MINISTRY OF INDUSTRY AND TRADE
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|
SOCIALIST REPUBLIC OF VIETNAM
Independence - Freedom - Happiness
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|
No.
18/2010/TT-BCT
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Hanoi, May
10, 2010
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CIRCULAR
ON THE OPERATION OF COMPETITIVE GENERATION MARKET
Pursuant to the Government's
Decree No. 189/2007/NĐ-CP dated December 27, 2007 on defining the functions,
tasks, powers and organizational structure of the Ministry of Industry and
Trade;
Pursuant to Law on Electricity
dated December 03, 2004;
Pursuant to the Prime Minister’s
Decision No. 26/2006/QĐ-TTg dated January 26, 2006, approving the roadmap and
conditions for establishing and developing the levels of electricity market in Vietnam;
The Ministry of Industry and
Trade prescribes the operation of competitive generation market as follows:
Chapter I
GENERAL PROVISION
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This Circular prescribes the
operation of the competitive generation market and the responsibilities of the
units participating in the electricity market.
Article
2. Subjects of application
This Circular is applicable to
the units participating in the competitive generation market, including:
1. The Single buyer.
2. Power generating units
3. The System and market operator.
4. Transmission network operators.
5. Electricity measurement units.
Article
3. Interpretation of terms
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1. Quotation is the quotation for
electricity price on the electricity market of each generating station,
submitted to the System and market operator in accordance with the form of
quotations prescribed in this Circular.
2. Scheduled quotations are the
quotations accepted by the System and market operator to schedule the
mobilization of day-ahead and hour-ahead
3. Statement of payment is the list of
payments to a power plant on the electricity market, made by the System and
market operator for each trading day and each payment cycle.
4. Electricity market intervention is
an act to change the usual operation of the electricity market taken by the System
and market operator to handle the situations prescribed in Clause 1 Article 55
of this Circular.
5. Group quoting is a quoting
mechanism performed by a representative for the whole group of conventional
hydroelectric plants.
6. Full load expense is the variable expense
of the generator when operating at full load, calculated in VND/kWh.
7. Trading cycle is the cycle of
calculating the electricity prices on the electricity market in 01 hour
starting from the first minute of an hour.
8. Payment cycle is the cycle of
making invoices for the transactions on the electricity market in 01 month
starting from the 1st.
9. Announced power is the maximum
ready power of a generator announced by quoting units or the System and market
operator and power generating units that sign the contract to provide ancillary
services according to the market schedule.
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11. Mobilized power of hour ahead is
the power of a generating stations planned to mobilize for the first hour in
the hour-ahead mobilization schedule .
12. Mobilized power of day ahead is
the power of a generating stations planned to mobilize for trading cycles in
the day-ahead mobilization schedule, considering the transmission limit of the
transmission grid.
13. Extra power is the difference
between the dispatched power and the power in the market price schedule of a
generating station.
14. Paid power is the power of the
generating stations in the hourly power schedule, and paid at CAN.
15. Ancillary services are services of
frequency control, spinning reserve, fast-start reserve, cold start reserve, reliability
must-run, voltage regulation, and black start.
16. Extra electricity is the mobilized
amount of electricity of the generating stations corresponding to the extra power.
17. Quoting units are units that
directly submit the quotations on the electricity market, including the power
generating units or power plants register to provide direct quotations, the Single
buyer providing quotations on behalf of BOT plants, and the representative that
provide quotations for groups of conventional hydroelectric plants.
18. The Single buyer (SB) is the only
unit in the electricity market that may purchase the entire electricity through
the electricity market and Power purchase agreements.
19. Power generating units are units
that possess one or multiple power plants that participate in the electricity
market and Power purchase agreements between such power plants and the Single
buyer.
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21. Direct trading generators are
power generating units of which the power plants may directly provide
quotations on the electricity market.
22. Metering Data Management Service
Provider (MDMSP) are units that provide, install, and manage the system of
collecting, processing, and storing data about electricity management and the
communication network serving the electricity market.
23. Transmission network operators (TNO)
are units licensed to transmit electricity, in charge of the management and
operation of the national electricity grid.
24. The System and market operator (SMO)
is the commanding unit that control the electricity generation, transmission,
and distribution in the national electricity system, and control the
electricity market.
25. Capacity add-on (CAN) is the price
for a unit of power in each trading cycle for calculating the power payment to
power generating units in the electricity market.
26. Floor price of the quotation is
the lowest price that the quoting unit may provide for a generating station in
the day-ahead quotation.
27. System marginal price (SMP) is the
price for a unit of electrical energy in each trading cycle for calculating the
electricity payment to power generating units in the electricity market.
28. Full market price (FMP) is the sum
of SMP and CAN of each trading cycle.
29. Ceiling price of the quotation is
the highest price that the quoting unit may provide for a generating station in
the day-ahead quotation.
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31. Water value is the expected price
of water in the reservoirs used for generating power as an alternative to
thermoelectricity sources in the future, converted into a unit of electrical
energy.
32. Productivity decline factor is the
productivity decline factor of the generating stations over time.
33. Annual or monthly average load factor
is the ratio of total electrical energy generated in a year or a month, to the
multiplication of the installed capacity and total hours in a year or a month
34. Electricity market information system
is the system of devices and databases serving the management and exchange of
information about the electricity market managed by the System and market
operator.
35. Ancillary service contract is the
contract to provide the services of fast-start reserve, cold start reserve, and
reliability must-run signed between a power generating unit and the System and
market operator, made under the form promulgated by the Ministry of Industry
and Trade.
36. Power purchase agreement (PPA) is
a written agreement on trading electricity between the Single buyer and power
generating units, or electricity importers, or electricity exporters.
37. Contract for difference (CfD) is a
Power purchase agreement signed by between the Single buyer and direct trading
generators, made under the form promulgated by the Ministry of Industry and
Trade.
38. Default interest rate is the
no-term interest rate of VND on the inter-bank market at the time of payment.
39. Restricted schedule is the
mobilization order of generating stations towards optimizing the generation
cost with regard to technical restriction in the electricity system, including
transmission capacity, ancillary services, and other restrictions.
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41. Power schedule is the schedule
made by the System and market operator after the operation to determine the
payment power in each trading cycle.
42. Hour-ahead schedule is the
anticipated schedule of the generating stations to generate and provide ancillary
services for the coming trading cycle and three succeeding trading cycles.
43. Day-ahead schedule is the
anticipated schedule of the generating stations to generate and provide ancillary
services for the trading cycles of the coming trading day
44. SMP schedule is the schedule made
by the System and market operator after current trading day to determine the SMP
for each trading cycle.
45. The electricity market simulation
model is the system of software that simulates the mobilization of
generating stations and calculate SMP used by the System and market operator in
the annual, monthly, and weekly operation plans.
46. Water value calculation model is
the system of software that optimize hydrothermoelectricity to calculate the
water value used by the System and market operator in the annual, monthly, and
weekly operation plans.
47. Limited water level is the lower
upstream water level of the hydroelectric reservoir at the end of the months or
weeks, calculated and announced by the System and market operator.
48. N-year is the current year of
electricity market operation, by calendar year.
49. D-day is the current trading day.
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51. BOT power plants are power plants
invested inform of Build-Operate-Transfer via contracts between foreign
investors and competent State agencies.
52. Best new power plant is the new
thermoelectric plant of which the average electricity price in the succeeding
year is lowest, and the price in the PPA is agreed according to the standard
electricity price bracket promulgated by the Ministry of Industry and Trade. The
best new power plant shall be chosen annually to calculate CAN.
53. Multi-purpose strategic hydroelectric
plants are large hydroelectric plants that are important for the economy,
society, National defense and security, exclusively built and operated by the
State.
54. Group of conventional hydroelectric
plants is a group of hydroelectric plants that the amount of water
discharged from the reservoir of the upper hydroelectric plants makes up the
whole or a large portion of water in the reservoir of the lower hydroelectric
plant, and there is no regulation reservoir between them…
55. Scheduling software is software
used by the System and market operator to make day-ahead and hour-ahead
schedules for the generating stations in the electricity market..
56. System load is the total electricity
output of the entire electricity system converted to the terminal of the
generating stations in a trading cycle.
57. Measurable generation output is
the measurable electrical energy of the power plant at the measuring position.
58. Contractual hourly generation output
is the amount of generation output distributed from the monthly contract for
each trading cycle, and paid according to contracts for difference.
59. Contractual annual generation is
the committed generation output in contracts for difference.
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61. Planned annual generation is the generation
output of a power plant planned to mobilize in the coming year.
62. Planned monthly generation is the generation
output of a power plant planned to mobilize in each month.
63. Heat loss rate is the wasted
thermal energy of the generating station or power plant to produce a unit of
electrical energy at full load, depending on the thermoelectric technology.
64. Restricted generation payment is
the payment received by a power generating unit for the extra electricity generation.
65. Participant in the electricity market
is a unit that participate in the transaction or provision of services on the
electricity market as prescribed in Article 2 of this Circular.
66. The electricity market is the competitive
generation market, established and developed as prescribed in Article 18 in the
Law on Electricity.
67. Power shortage is the situation
that the total announced power of all power generating units is smaller than
the estimated system load in a trading cycle.
68. Confidential information are the
confidential information as prescribed by law or agreed by parties.
69. Market information is all the data
an information related to the operation of the electricity market.
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71. Mobilization order is the
arrangement of the power ranges in the quotation according to the principle of
unrestricted schedule.
72. Power excess is the situation that
the total power offered at the floor price, and the total power of the multi-purpose
strategic hydroelectric plants announced by the System and market operator in a
trading cycle is smaller than the estimated system load.
73. Peak load stations are generating
stations mobilized at peak hours in the chart of electricity system load.
74. Intermediate load stations are
generating stations mobilized at peak hours and usual hours in the chart of
electricity system load.
75. Base load stations are generating
stations mobilized at peak hours, usual hours and in the chart of electricity
system load.
76. Slow-start stations are generating
stations that are not able to start and join the grid within less than 30
minutes.
Chapter
II
PARTICIPATING IN THE ELECTRICITY MARKET
Article
4. Responsibility to participate in the electricity market
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2. The power plants exempted from
participate in the electricity market include:
a) BOT power plants;
b) Wind power plants and
geothermal power plant;
c) Power plants in industrial
zones that only sell part of the generation output to the national electricity
system, and cannot determine the long-term electricity sale plan. Vietnam
Electricity must make the list of these power plants and submit to The
Electricity Regulatory Authority for approval.
3. The power plants prescribed in
Clause 1 this Article must invest in and complete the equipment to connect to
the electricity market information system, SCADA/EMS system, and the
electricity measurement system in order to meet the demand of the electricity
market.
Article
5. Dossier of application for participating in the electricity market
1. The power generating units
that possess the power plants prescribed in Article 4 of this Circular must
apply for participating in the electricity market separately for each power
plant.
2. The dossier of application for
participating in the electricity market include:
a) The application for
participating in the electricity market, specifying the name, address of the
power generating unit and power plant;
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c) The documents about the
appraisal and acceptance of the equipment to connect to the electricity market
information system, SCADA/EMS system, and the electricity measurement system.
d) Other necessary information at
the request of the System and market operator.
Article
6. Order for approving dossiers of application for participating in the
electricity market
1. Within 10 working days as from
receiving the valid dossier, the System and market operator must appraise and
submit it to The Electricity Regulatory Authority for approving the
participation in the electricity market of the power plant.
2. If the dossier is not valid,
within 05 working days as from receiving the dossier, the System and market
operator must request the power generating unit to complete their dossier in
writing.
3. Within 05 working days as from
receiving the papers from the System and market operator, The Electricity
Regulatory Authority must make decisions on approving the power plant to
participate in the electricity market, and notify the System and market
operator in writing so that they shall add the power plant in the list of the
electricity market participants.
4. Within 05 working days as from
the power plant is allowed to participate in the electricity market, the power
generating units must register the quoting subject (generating units or power
plants) with the System and market operator
Article
7. Information about participants in the electricity market
1. Transmission network operators,
the Single buyer, and MDMSP must register the general information about the
units with the System and market operator.
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3. Participants in the
electricity market must notify the System and market operator when changing the
registered information.
4. The System and market operator
must disclose the registration information of the participants in the
electricity market, and the changed information.
Article
8. Suspending and restoring the participation in the electricity market of
power plants
1. A power plant shall have their
participation in the electricity market suspended in the following cases:
a) Failing to comply with Article
4 of this Circular;
b) Committing the following acts:
- Failing to provide information
or provide false information for planning electricity market operation and
making mobilization schedule for generating stations in the electricity system;
- Making agreements with other
power generating units or the System and market operator when providing
quotations for the purpose of making mobilization schedules improperly;
- Directly or indirectly making
agreements with other units on announcing power and providing quotations on the
electricity market in order to increase SMP and affect the electricity supply
security;
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2. The Electricity Regulatory
Authority is entitled to suspend the participation in the electricity market of
power plants that violate Clause 1 this Article. The order and procedures for
suspending the participation of power plants are prescribed in Article 108 of
this Circular.
3. While the participation in the
electricity market of a power plant is suspended:
a) The power generating unit or
power plant must not directly provide quotations on the electricity market and
must comply with other provisions of this Circular;
b) The Single buyer must provide
quotations on behalf of the power plant;
c) The power plant must provide
information for the Single buyer to make quotations.
4. A suspended power plant may
have their participation in the electricity market restored when the following
conditions are satisfied:
a) The suspension period expires;
b) The obligations in the penalty
decision are fulfilled.
5. When the conditions prescribed
in Clause 4 this Article are satisfied, the power plant must send a written
request for the restoration of the participation in the electricity market
enclosed with the proving documents to the System and market operator. The System
and market operator must verify and approve the participation in the
electricity market of the power plant.
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Article
9. Terminating the participation in the electricity market
1. A power plant shall have their
participation in the electricity market terminated in the following cases:
a) At the request of the power
generating unit in the following cases:
- The power plant of the power
generating unit stops operating or generating power in the national electricity
system;
- The power plant of the power
generating unit fails to sustain and restore the installed capacity > 30 MW.
b) The Electricity generation
license of the power plant is revoked or expired.
2. In the case specified in Point
a Clause 1 this Article, the power generating unit must send a written request
for terminating the participation in the electricity market to The Electricity
Regulatory Authority at least 30 days before the time they wish to stop participating
in the electricity market.
3. The System and market operator
must update the registration information and announce the termination of the
participation in the electricity market of power plants.
4. In case the power plant
commits violations before stopping participating in the electricity market, the
power generating unit that possess such power plant must comply with provisions
on inspection, verification, and handling of violations as prescribed in this
Circular.
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PRINCIPLES OF ELECTRICITY MARKET OPERATION
Article
10. Limits of quoted prices
1. The quoted prices of
generating stations on the competitive generation market are limited from the
floor price of the quotation to the ceiling price of the quotation
2. The ceiling price of the
quotation of a thermoelectric generating station is calculated annually,
adjusted monthly on the following bases:
a) Heat loss rate of the
generating station;
b) The factor of productivity
decline over time of the generating station;
c) Fuel price;
d) Start expenses
3. The floor price of a
thermoelectric generating station is 1 VND/kWh.
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Article
11. Water value
1. The water value use for making
operation plans for the coming year, coming month, coming week, and limiting
the quoted prices of hydroelectric generating stations in the electricity
market.
2. The System and market operator
must calculate and announce the water level in accordance with the market timetable
prescribed in this Annex 1 of this Circular..
Article
12. Full market price (FMP)
The full market price of a trading
cycle is the sum of:
1. System marginal price (SMP).
2. Capacity add-on (CAN).
Article
13. System marginal price (SMP)
1. SMP is the general price for
the whole system, used for calculate the electricity payments on the
electricity market for each trading cycle.
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3. SMP must not exceed the market
ceiling price calculated by the System and market operator and approved by The
Electricity Regulatory Authority every year.
4. The calculation of SMP is prescribed
in Article 63 and Article 65 of this Circular.
Article
14. Capacity add-on (CAN).
1. CAN of each trading cycle is
calculated by the System and market operator during making the operation plan
of the coming year, and is not changed during the year of application.
2. CAN is calculated so that the
best new power plant can recoup the variable and fixed expenses.
3. The calculation of CAN is
prescribed in Article 25 and Article 26 of this Circular.
Article
15. Contracts for difference
1. The power generating unit
trading directly and the Single buyer must sign contracts for difference made
under the form promulgated by the Ministry of Industry and Trade.
2. The annual contractual generation
output is calculated by the System and market operator based on the annual
planned output and the proportion of payment output according to the
contractual price as prescribed in Clause 5 this Article. The annual
contractual generation output is calculated by the System and market operator
during planning the operation of the coming year as prescribed in Article 27 of
this Circular.
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4. The hourly contractual generation
output is calculated by the System and market operator during planning the
operation of the coming month based on the distribution of annual contractual
output to the hours in that month as prescribed in Article 35 of this Circular.
5. The annual contractual generation
output is calculated by the System and market operator based on the annual
planned output and the proportion of payment output according to the
contractual price as prescribed in Clause 5 this Article.
a) Objectives:
- Step by step reduce generation output
paid at contractual price;
- Stabilize the revenue of power
generating units;
- Stabilize the average electricity
price, in compliance with the provisions on electricity retail pricing.
b) The proportion of generation output
paid at contractual price in the year when the electricity market starts to
operate must not exceed 95%, and must reduce in the succeeding years but must
not be lower than 60%.
Article
16. principles of payment in the electricity market
1. Power generating units are
paid at the contractual price or electricity market price.
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a) Contracts for difference for
power generating units that directly make transactions;
b) PPAs for multi-purpose
strategic hydroelectric plants;
c) Contracts for difference for
power generating units that provide ancillary services;
3. The payments at the market
price are only applicable to direct trading generators, and calculated based on
the following factors:
a) SMP.
b) CAN.
c) The mobilized power and
generation output.
4. The payments shall be made as
prescribed in Chapter VI of this Circular.
Chapter
IV
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SECTION
1. YEAR-AHEAD OPERATION PLAN
Article
17. Year-ahead operation plan
1. The System and market operator
must make year-ahead operation plans, including:
a) The selection of the best new
power plant;
b) Calculating CAN;
c) Calculating the water value
and limited water level of hydroelectric reservoirs;
d) Calculating the quotation
limits of thermoelectric generating stations;
dd) Determining the ceiling
market price.
e) Leading and cooperating with
the Single buyer in calculating the annual contractual output and planned generation
output, and the distribution of annual contractual output to the months in a
year of the direct trading generators.
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3. The System and market operator
must submit the year-ahead operation plan according to the timetable prescribed
in Annex 1 of this Circular to Vietnam Electricity for appraisal and to The
Electricity Regulatory Authority for approval. The dossier must include the
calculations prescribed, input data, and description.
Article
18. Classification of hydroelectric plants
1. The hydroelectric plants are classified
as follows:
a) Multi-purpose strategic
hydroelectric plants;
b) Groups of conventional
hydroelectric plants;
c) Other hydroelectric plants.
2. Every year, the System and
market operator must update the list of groups of conventional hydroelectric
plants.
3. The Electricity Regulatory
Authority must make and send the list of multi-purpose strategic hydroelectric
plants to the Ministry of Industry and Trade for sending to the Prime Minister
for approval.
Article
19. Estimating load for making year-ahead operation plan
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1. The total load of the system
and the loads of each region (the North, the Middle, the South) for the whole
year and each month in the year.
2. The load chart of typical days
of the North, the Middle, the South, and all the months in a year.
3. The maximum and minimum load
of the system in each month.
Article
20. Ancillary services for year-ahead operation plan
1. The System and market operator
must determine the demand for ancillary services of the year ahead as
prescribed in the Regulation on electricity transmission system promulgated by
the Ministry of Industry and Trade.
2. The System and market operator
must select power plants that provide ancillary services and sign the services
contract with the power generating unit under the form promulgated by the
Ministry of Industry and Trade.
Article
21. Classification of base load, intermediate load, and peak load stations of
year ahead
1. The System and market operator
must classify the base load, intermediate load, and peak load stations as
prescribed in the Classification procedures, and calculate the ceiling price of
the quotation of the thermoelectric plant.
2. The System and market operator
must use the market simulation model to calculate the annual average load
factor of the generating stations.
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a) Base load stations include the
generating stations of which the annual average load factor ≥ 60%;
b) Intermediate load stations
include the generating stations of which the annual average load factor is higher
than 20% and lower than 60%;
c) Peak load stations include the
generating stations of which the annual average load factor ≤ 25%.
Article
22. Determining quoted prices of thermoelectric generating stations
1. Calculating the ceiling price
of thermoelectric generating stations
a) Ceiling price of the quotation
of a thermoelectric generating station is calculated as follows:
In particular:
: ceiling price of the quotation of the
thermoelectric generating station (VND/kWh);
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f: coefficient of auxiliary
expenses, calculated by the ratio of total variable expenses on auxiliary fuel,
operation and maintenance to the expense on primary fuel;
PNL: the price of primary fuel of
the thermoelectric generating station (VND/BTU);
: heat loss rate of the thermoelectric
generating station (BTU/kWh).
b) The fuel price used to
calculate the ceiling price of the quotation is the estimated fuel price for
N-year provided for the System and market operator by the Single buyer. The
fuel price is calculated within the power plant boundary;
c) The heat loss rate of a
station is calculated based on the heat loss rate agreed in the PPAs or the
contract negotiation documents provided by the Single buyer, and adjusted based
on the productivity decline factor.
If a thermoelectric generating
station does not have the data about the heat loss rate in the PPA or contract
negotiation documents, the heat loss rate of such station shall equal the heat
loss rate of a standard power plant in the same group of generation technology
and installed capacity. The System and market operator must calculate the heat
loss rate of the standard power plant.
If there is no data about the
heat loss rate in the PPA or contract negotiation documents and no standard
power plant in the same class, the System and market operator shall calculate
the heat loss rate based on the previous operation data provided by the power
generating unit.
d) The productivity decline
factor of a station is calculated based on the productivity decline factor in
the PPA or the contract negotiation documents provided by the Single buyer.
If a thermoelectric generating
station does not have the data about the productivity decline factor in the PPA
or contract negotiation documents, the productivity decline factor of a
standard power plant in the same group determined by the System and market
operator shall apply;
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2. The floor price of
thermoelectric generating stations is prescribed in Clause 3 Article 10 of this
Circular.
3. The System and market operator
must announce the approved quotation limits of the thermoelectric generating
stations in accordance with the market timetable prescribed in Annex 1 of this
Circular.
Article
23. Quotation limits of BOT power plants
1. The ceiling price of the quotation
of a BOT power plant equals the electricity price in the PPA of the BOT plant
2. The floor price of the
quotation of a BOT power plant = 1 VND/kWh.
Article
24. Selecting the best new power plant
1. The best new power plant in
N-year is a power plant that participates in the electricity market and satisfy
the following criteria:
a) Starting to operate
commercially and generate all the installed power in N-1 year;
b) Being a base load power plant,
classified by the criteria in Clause 3 Article 21 of this Circular;
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d) The average overall
electricity generation price for 1 kWh is lowest
2. The Single buyer must make the
list of power plants that satisfy the criteria in Point a and Point c Clause 1
this Article, and provide the data of their PPAs to the System and market
operator to determine the best new power plant. The data includes:
a) The variable price of N-year;
b) The fix price of N-year;
c) The agreed generation output
for calculating the contractual price.
3. If there is no power plant
satisfy the criteria prescribed in Point a, b and c Clause 1 this Article, the System
and market operator shall use the selected the best new power plant in N-1 year
and request the Single buyer to update and provide the data prescribed in
Clause 2 this Article to calculate for the N-year.
4. The System and market operator
must calculate the average overall generation expense on 1 kWh for the power
plants that satisfy the criteria prescribed in Point a, b and c Clause 1 this
Article using the following formula:
: average overall electricity generation
expense on 1 kWh in N-year of the power plant (VND/kWh);
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: variable price for N-year according to the contracts
for difference of the power plant (VND/kWh);
: the agreed generation output for
calculating the contractual price for N-year of the power plant (kWh);
: estimated generation output in N-year of
the power plant determined from the market simulation model using the method of
restricted scheduling (kWh).
5. The chosen best new power
plant in N-year is the power plant of which the average overall electricity
generation expense on 1 kWh is lowest according to the calculation in Clause 4
this Article.
Article
25. Principle of calculating CAN
1. Ensure that the best new power
plant can completely recoup the generation expense when participating in the
electricity market.
2. Do not apply CAN to the off-peak
hour at night: 0:00 – 4:00, 22:00 – 24:00.
3. CAN is proportional with the
estimated system load of a trading cycle.
Article
26. Order for calculating CAN
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1. a) The selection of the best
new power plant;
a) the estimated revenue on the
market of the best new power plant is calculated as follows:
In particular:
RTTĐ: estimated revenue according
to SMP of the best new power plant in N-year (VND);
i: ith trading cycle
in N-year;
I: total trading cycles in
N-year;
SMPi: estimated SMP of the ith
trading cycle in N-year calculated from the electricity market simulation model
using the method of unrestricted scheduling (VND/kWh);
: estimated generation output in N-year of
the best new power plant in the ith trading cycle determined from
the market simulation model using the method of restricted scheduling (kWh).
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In particular:
TCBNE: annual
generation expense of the best new power plant in N-year (VND);
PBNE: average overall
electricity generation expense on 1 kWh of the best new power plant calculated
in Clause 4 Article 24 of this Circular (VND/kWh);
: estimated generation output in N-year of
the best new power plant in the ith trading cycle determined from
the market simulation model using the method of restricted scheduling (kWh).
i: ith trading cycle
in N-year;
I: total trading cycles in
N-year.
b) Calculate the annual shortage
of expense of the best new power plant using the following formula:
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AS: annual shortage of expense of
the best new power plant in N-year (VND);
TCBNE: annual total
generation expense of the best new power plant in N-year calculated in Point b
this Clause (VND);
: estimated revenue according to SMP of the
best new power plant in N-year calculated in Point a this Clause (VND).
2. Calculating monthly lacking
expense:
Monthly lacking expense of the
best new power plant is calculated by distributing the annual shortage of
expense to the months in N-year using the following formula:
In particular:
t: t-month in N-year;
MS: shortage of expense of t-month
of the best new power plant (VND);
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: peak load in t (MW).
3. Calculating CAN in a trading
cycle.
a) The annual average usable
power of the best new power plant is calculated as follows:
In particular:
QBNE: average usable
power in N–year of the best new power plant (kW);
I: total number of trading cycles
in N-year, except off-peak hours at night;
i: the trading cycle that the
best new power plant is planned to be mobilized except off-peak hours at night;
: estimated mobilized power of the best new
power plant in the ith trading cycle of the N-year determined from
the market simulation model using the method of restricted scheduling (kW).
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In particular:
I: total number of trading cycles
in t-month , except off-peak hours at night;
i: ith trading cycle
in t-month, except off-peak hours at night;
: CAN of the ith trading cycle (VND/kW);
QBNE: average usable
power in N–year of the best new power plant (kW);
MS: lacking expense of t-month of
the best new power plant (VND);
: estimated system load of the ith
trading cycle according to the estimated load chart of a typical day in t-month
prescribed in Article 19 of this Circular (MW);
: estimated minimum system load of t-month (MW).
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Annual contractual output of a
power plant is calculated while making the year-ahead operation plan,
including the following steps:
1. Using the market simulation
model to estimate the generation output of the power plant using the method of
restricted scheduling.
2. Calculating the annual planned
output of the power plant using the following formula:
if 
if 
if 
In particular:
: planned generation output in N-year of the
power plant (kWh);
: estimated generation output in N-year of
the power plant determined from the market simulation model using the method of
restricted scheduling converted into the measuring position (kWh).
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A,b: coefficient of annual
generation output adjustment. a = 0.9; b = 1.1
3. Calculate the annual
contractual output of the power plant using the following formula:
In particular:
Qc: contractual output in N-year
(kWh);
: planned output in N-year of the power plant
(kWh);
: proportion of payment output at contractual
price applicable to N-year (%).
Article
28. Calculating monthly contractual output
Monthly contractual output of a
power plant is calculated while making the year-ahead operation plan, including
the following steps:
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2. Calculate the monthly
contractual output using the following formula:
In particular:
: contractual output in t-month of the power
plant (kWh);
Qc : annual contractual output of
the power plant (kWh);
: estimated generation output in t-month of
the power plant determined from the market simulation model using the method of
restricted scheduling (kWh).
Article
29. Responsibility to calculate and conclude annual and monthly contractual
output
1. The System and market operator
must:
a) Calculate the annual and
monthly contractual output of power generating units as prescribed in Article
27 and Article 28 of this Circular;
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2. The Single buyer and direct
trading generators must:
a) Provide data for the System
and market operator to calculate the annual and monthly contractual output;
b) Check and cooperate with the System
and market operator to handle the errors in the calculations;
c) Supplement the annex of annual
and monthly contractual output in the contracts for difference according to the
calculations.
Article
30. Determining the ceiling market price.
1. The System and market operator
must calculate the plans for ceiling market prices, include ceiling market
price, estimated average generation price in N-year and the fluctuation of
average generation price compared to that in N-1 year. There must be at least 3
plans for the ceiling market prices.
2. The ceiling market price in
N-year must not exceed 115% of the ceiling price of the quotation of the most
expensive intermediate-load thermoelectric generating station.
3. Calculate the annual average
generation price using the following formula:
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j: jth power plant of
the direct trading generator;
J: total number of power plants
of the direct trading generator;
PPDTB: the average
generation price of the whole system in N-year (VND/kWh);
: average full market price in N-year
prescribed in Clause 4 this Article (VND/kWh);
: total generation output in N-year of the
whole system (kWh);
: total generation output in N-year of direct
trading generators (kWh);
: total generation output in the Contract for
difference in N-year of the jth power plant (kWh);
: price in the contract for difference in
N-year of the jth power plant (kWh);
: total expense on purchasing electricity
from BOT power plants in N-year (VND);
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CDVPT: total expense
on purchasing ancillary services in N-year (VND).
4. The average full market price
is calculated as follows:
In particular:
i: ith trading cycle
in N-year;
I: total number of trading cycles
in N-year;
: average full market price in N-year
(VND/kWh);
: estimated generation output of all power
plants that participate in the market in the ith trading cycle determined
from the market simulation model with restricted transmission (kWh);
: estimated SMP of the ith trading
cycle determined from the electricity market simulation model without
restricted transmission (VND/kWh);
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SECTION
2. MONTH-AHEAD OPERATION PLAN
Article
31. Estimating load for making month-ahead operation plan
The System and market operator
must estimate the load to make the month-ahead operation plan using the method
prescribed in the Regulation on electricity transmission system promulgated by
the Ministry of Industry and Trade. The load estimate for making month-ahead
operation plan includes:
1. The total load of the system
and the loads of each region (the North, the Middle, the South) for the whole
month and each week in the year.
2. The load chart of typical days
of the North, the Middle, the South, and all the weeks in a month.
Article
32. Calculating water value
The System and market operator
must calculate the water value for the weeks in the month ahead. The water
value is used to make the month-ahead operation plan, including:
1. Estimated output of multi-purpose
strategic hydroelectric plants.
2. Water value of groups of
conventional hydroelectric plants.
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4. The limited water level of
hydroelectric reservoirs of the weeks in a month.
Article
33. Classification of base load, intermediate load, and peak load generating
stations of month ahead
1. The System and market operator
must classify the base load, intermediate load, and peak load stations in the
month ahead as prescribed in the Classification procedures, and calculate the monthly
ceiling price of the quotation of the thermoelectric plant.
2. The System and market operator
must use the market simulation model to calculate the monthly average load
factor of the generating stations in the month ahead.
3. Based on the monthly average
load factor from the simulation results, the stations are classified as 3
following groups:
a) The base load stations
including the generating stations of which the monthly average load factor ≥
70%;
b) The intermediate load stations
including the generating stations of which the monthly average load factor is
higher than 25% and lower than 70%;
c) The peak load stations
including the generating stations of which the monthly average load factor ≤
25%.
Article
34. Adjusting the ceiling price of the quotation of thermoelectric generating
stations
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2. The System and market operator
must announce the ceiling price of the quotation of the thermoelectric
generating stations in the month ahead according to the market timetable
prescribed in Annex 1 of this Circular.
Article
35. Calculating hourly contractual output
The System and market operator must
calculate the hourly contractual output in the month ahead for the power plant
as follows:
1. Using the market simulation
model to estimate the generation output of each hour in the month of the power
plant.
2. Calculate the hourly
contractual output using the following formula:
In particular:
i: the ith trading
cycle in the month;
I: total number of cycles in the
month;
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: estimated generation output of the power
plant in the ith trading cycle calculated from the market simulation
model using the method of restricted scheduling (kWh).
: monthly contractual output of the power
plant determined as prescribed in Article 28 of this Circular (kWh);
3. The System and market operator
must send the calculations of the hourly contractual output to the Single buyer
and direct trading generators in accordance with the market timetable
prescribed in Annex 1 of this Circular.
4. The Single buyer and direct
trading generators must certify the hourly contractual output calculated by the
System and market operator.
SECTION
3. WEEK-AHEAD OPERATION PLAN
Article
36. Week-ahead water value
1. The System and market operator
must update the data of load estimate, hydrography, and the relevant data to
calculate the week-ahead water value.
2. The System and market operator
must update the information and recalculate the week-ahead water value and
announce the following results:
a) Estimated hourly output and
water value of multi-purpose strategic hydroelectric plants;
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c) Water value of other
hydroelectric plants.
d) The weekly limited water level
of hydroelectric reservoirs.
Article
37. Quotation limits of power plants
The quotation limits of a
hydroelectric plant are calculated based on the week-ahead water value of that
plant, and announced as prescribed in Clause 2 Article 36 of this Circular. In
particular:
1. If the water value > 0
VND/kWh:
a) The ceiling price of the
hydroelectric plant = 110% of the water value;
b) The floor price of the
hydroelectric plant = 80% of the water value.
2. If the water value ≤ 0
VND/kWh, the ceiling price and floor price of the hydroelectric plant = 0
VND/kWh.
Chapter V
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SECTION
1. ELECTRICITY MARKET OPERATION OF DAY AHEAD
Article
38. Information for electricity market operation of day ahead
Before 9:00 of the D-1 day, the System
and market operator must determine and announce the following information:
1. The D-day load estimate chart
of the whole system and each region (the North, the Middle, the South).
2. The estimated exported and
imported generation output in each trading cycle of the D-day. The exported and
imported generation output supplied by the Single buyer as prescribed in
Article 58 and Article 59 of this Circular.
3. The short-term system security
assessment for D-day as prescribed in the Regulation on electricity
transmission system promulgated by the Ministry of Industry and Trade.
Article
39. Quotation
A quotation must comply with the
following principles:
1. Having at lest 5 couples of
prices (VND/kWh) and power (MW) for each station in each trading cycle of
D-day.
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3. The minimum pricing step is 3
MW.
4. The specifications of the
station, include:
a) The announced power of the
station on D-day;
b) The minimum stable power of
the station;
c) The speed of increasing and
decreasing the maximum power of the station.
5. The announced power of the
station in the D-day quotation must not be lower than that in the D-2 day in
accordance with the short-term electricity system security assessment
procedures prescribed in the Regulation on electricity transmission system,
except for inevitable technical breakdowns.
6. The first range of powers in
the quotation must equal the minimum stable power of the station. The last range
in the quotation must equal the announced power.
7. The unit of quoted prices is
VND/kWh, the smallest decimal is 0.1.
8. The quoted prices must be in
the range from the floor price to the ceiling price of the station inversely
proportional to the offered powers.
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Article
40. Quotations of groups of conventional hydroelectric plants;
1. Groups of conventional
hydroelectric plants must provide a joint quotation and comply with the
quotation limits prescribed in Article 37 of this Circular.
2. The power plants in a group of
conventional hydroelectric plants must make an agreement on appointing a
representative unit to provide quotations. The representative unit that
provides quotation must submit a written registration enclosed with the written
agreement among the power plants in the group of conventional hydroelectric
plants to the System and market operator.
3. If the representative unit of
a group of conventional hydroelectric plants is not registered, the System and
market operator must provide quotations on their behalf, in accordance with
their water value.
4. The representative unit that
provides quotations must comply with the provisions on quoting applicable to
all power plants in groups of conventional hydroelectric plants.
5. The water value of a group of
conventional hydroelectric plants is the water value of the biggest
hydroelectric reservoir on that level. The System and market operator must
determine the hydroelectric reservoirs used in the calculation of water value
for a group of conventional hydroelectric plants, and classify the
hydroelectric plants prescribed in Article 18 of this Circular.
6. In case there is a multi-purpose
strategic hydroelectric plant in a group of conventional hydroelectric plants:
a) The System and market operator
must announce the hourly generation output in the week ahead of each power
plant in the group of conventional hydroelectric plants as prescribed in Clause
2 Article 36 of this Circular;
b) When the announced output of
the multi-purpose strategic hydroelectric plant in the group is changed as
prescribed in Article 51 of this Circular, the System and market operator must
adjust the announced output of the power plants at the lower levels
accordingly.
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1. Other hydroelectric plants
that have regulation reservoirs more than 01 week must provide quotations and
comply with the quotation limits prescribed in Article 37 of this Circular.
2. Other hydroelectric plants
that have regulation reservoirs less than 01 week must announce the hourly
generation output of D-day to the System and market operator before 10:00 on
the D-1 day to make the mobilization schedule.
3. The Single buyer must provide
quotation on behalf of BOT power plant.
Article
42. Quotation submission
1. Before 10:00 of D-1 day,
quoting units must submit the quotation of D-day.
2. Quoting units shall submit the
quotation via the market information system. If the market information system
is not available, quoting units must reach an agreement with the System and
market operator on other methods of quotation submission in the following
order:
a) By email to the email address provided
by the System and market operator;
b) By fax to the fax number provided
by the System and market operator;
c) Direct submission at the System
and market operator.
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1. 30 minutes before the end of
the quoting period, the System and market operator must check the validity of
the quotations received from the quoting units as prescribed in Article 39 of
this Circular. If a quoting unit sends multiples quotations, only the last one
received shall be considered.
2. If a quotation is not valid,
the System and market operator must promptly notify the sender and request them
to submit another quotation before the end of the quoting period.
3. Right after being notified by
the System and market operator of the invalid quotation, the quoting unit must
amend and submit it again before the end of the quoting period.
Article
44. Scheduled quotations
1. After the end of the quoting
period, the System and market operator must check the validity of the last
quotations received as prescribed in Article 39 of this Circular. The last
valid quotation received shall be used as a scheduled quotations for making the
day-ahead mobilizing schedule.
2. If the System and market
operator doest not receive the quotation, or the last quotation is not valid,
the System and market operator shall use the default quotation of that power
generating unit as a scheduled quotations.
3. The default quotation of power
plants is determined as follows:
a) For thermoelectric plants, the
default quotation is the nearest valid quotation or quotation of a similar
generating station determined by the System and market operator;
b) For hydroelectric plants and
groups of conventional hydroelectric plants, the default quotation is the
quotation which the quoted price equals the announced weekly water value.
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The System and market operator
must use the data below to make day-ahead mobilization schedules:
1. The D-day load chart of the
whole system and each region (the North, the Middle, the South).
2. The scheduled quotations from
quoting units.
3. The announced output of
hydroelectric plants prescribed in Clause 2 Article 36, Clause 6 Article 40,
and Clause 2 Article 41 of this Circular.
4. The imported and exported
generation output prescribed in Article 58 and Article 59 of this Circular.
5. The power of power plants that
provide ancillary services.
6. Requirements for spinning
reserve and frequency control power.
7. The transmission grid repair
and maintenance schedule and the generating station approved by the System and
market operator.
8. The short-term system security
assessment for D-day as prescribed in the Regulation on electricity
transmission system promulgated by the Ministry of Industry and Trade.
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Article
46. Making day-ahead mobilization schedules
The System and market operator is
responsible for making day-ahead mobilization schedules. A day-ahead
mobilization schedule includes:
1. The unrestricted mobilization
schedule, including:
a) The SMP in each day-ahead trading
cycle;
b) The mobilization order of
generating stations in each day-ahead trading cycle.
2. The restricted mobilization
schedule, including:
a) The planned mobilization chart
of each generating station in each day-ahead trading cycle.
b) The starting and stopping
schedule, and the anticipated connection status of each station on the day
ahead;
c) The method of operation and
wire connection diagram of the electricity system in each day-ahead trading
cycle;
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Article
47. Announcing day-ahead mobilization schedules
Before 15:00 every day, the System
and market operator must announce the information in the day-ahead mobilization
schedule. In particular:
1. The anticipated mobilized
power (including frequency control and spinning reserve) of the stations in
each day-ahead trading cycle.
2. The SMP in each day-ahead trading
cycle.
3. The list of stations anticipated
to increase or decrease the generation power in each day-ahead trading cycle..
4. Warnings about shortage of
power on day ahead (if any), including:
a) The anticipated trading cycle of
power shortage;
b) Minimum power;
c) The violated restrictions on
system security.
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a) The anticipated trading cycle
of power excess;
b) The stations planned to stop
generating.
Article
48. Connecting generating stations
1. For slow-starting stations,
the power generating unit must be ready to connect them in accordance with the
day-ahead mobilization schedule announced by the System and market operator. If
the starting period of the station exceeds 24 hours, the power generating unit
must be ready to connect it based on the short-term system security assessment
announced by the System and market operator.
2. For non-slow-starting
stations, the power generating unit must be ready to connect them in accordance
with the hour-ahead mobilization schedule announced by the System and market
operator.
Article
49. Handling measures for warnings about power shortage
1. Adjusting quotations
a) Quoting units may adjust and
submit the quotation for day ahead or for the remaining trading cycles in D-day
to the System and market operator at least 60 minutes before the operation time
of which the quoted price is changed;
b) The adjusted quotation must
not reduce the offered power nor changing the quoted prices compared to the
day-ahead quotation of that quoting unit;
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2. Adjusting the announced power
of multi-purpose strategic hydroelectric plants
The System and market operator may
adjust the announced output of the multi-purpose strategic hydroelectric plants
as prescribed in Clause 2 Article 51 of this Circular.
SECTION
2. ELECTRICITY MARKET OPERATION OF HOUR AHEAD
Article
50. Data for making hour-ahead mobilization schedules
The System and market operator
must use the data below to make hour-ahead mobilization schedules:
1. The load chart of the whole
system and each region (the North, the Middle, the South) estimated for hour
ahead and the succeeding 03 hours.
2. The scheduled quotations of quoting
units.
3. The connection plan of the
slow-starting stations according to the announced day-ahead mobilization
schedules.
4. Announced output of multi-purpose
strategic hydroelectric plants.
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6. The readiness of the
transmission grid and generating stations from the SCADA system or provided by transmission
network operators and power generating units.
7. Other restrictions on system
security.
Article
51. Adjusting the announced output of multi-purpose strategic hydroelectric
plants
1. Before making hour-ahead
mobilization schedules, the System and market operator may adjust the hourly
generation output of multi-purpose strategic hydroelectric plants announced as
prescribed in Clause 2 Article 36 of this Circular in the following cases:
a) Having unusual hydrographical
fluctuation;
b) Having warnings about power
shortage according to day-ahead mobilization schedules;
c) Having decisions from
competent State management agencies on regulating the reservoirs of multi-purpose
strategic hydroelectric plants for the purpose of irrigation and flooding
prevention.
2. The range of regulating the
hourly output of multi-purpose strategic hydroelectric plants in the cases
prescribed in Point a and Point v Clause 1 this Article is annually prescribed
by The Electricity Regulatory Authority at the request of the System and market
operator based on the electricity market and electricity system operation in
the preceding year. In the first year of electricity market operation, the
range of regulation is ± 5%.
Article
52. Making hour-ahead mobilization schedules
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2. Making hour-ahead mobilization
schedules during power shortage
a) The System and market operator
shall schedule the mobilization of the stations in the following order:.
- According to the scheduled
quotation;
- The multi-purpose strategic
hydroelectric plants according to adjusted output;
- The stations that provide
services of fast-start reserve and cold start reserve according to day-ahead
mobilization schedules;
- The stations that provide
services of reliability must-run;
- Spinning reserve power;
- Reducing the frequency control
reserve power to the allowed minimum level.
The System and market operator
shall check and estimate the amount of power that needs to be discarded to
ensure system security.
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Before 15:00 every day, the System
and market operator must adjust hour-ahead mobilization schedules in the
following order:
a) Stop the stations that voluntarily
stop generating;.
b) Minimize the generation output
of the spinning reserve stations;
c) Minimize the generation output
of the frequency control stations;
d) Stop the non-slow-starting
stations from highest to lowest prices according to the quotation;
d) Gradually reduce the
generation output of slow-starting stations lowest stable generation output;
e) Stop the slow-starting
stations in the following orders:
- The shortest startup time;
- The lower starting expense. The
startup expense agreed by the Single buyer and power generating units, and
provided to the System and market operator;.
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Article
53. Announcing hour-ahead mobilization schedules
The System and market operator
must announce the hour-ahead mobilization schedule before the operation 15
minutes, including:
1. The estimated load of the
whole system and each region (the North, the Middle, the South).
2. The mobilization schedule of
generating stations of hour ahead and the succeeding 3 hours made as prescribed
in Article 52 of this Circular.
3. The measures of the System and
market operator for power shortage and power excess.
4. The information about the adjustment
of announced power of multi-purpose strategic hydroelectric plants as
prescribed in Article 51 of this Circular.
5. The schedule of discarding
load (if any).
Section
3. REAL-TIME OPERATION
Article
54. Regulate real-time electricity system
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2. Power generating units must
comply with the dispatch instruction from the System and market operator.
Article
55. Electricity market intervention
1. Cases of electricity market
intervention
The System and market operator
may intervene the electricity market in the following cases:
a) The system runs in the
emergency mode prescribed in the Regulation on electricity transmission system
promulgated by the Ministry of Industry and Trade;
b) The hour-ahead mobilization
schedule is not made before the operation 15 minutes.
2. Measures of electricity market
intervention
The System and market operator
shall schedule the mobilization of the stations in the following order:
a) According to the valid
quotations from quoting unit in that trading cycle;
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- Apply the floor price to the
contractual output;
- Apply the ceiling price of the
quotation to the remaining output.
c) If the measures prescribed in
Point a and Point b this Clause cannot be taken, the System and market operator
must mobilize the stations to meet the objectives in the following order:
- Ensure the balance of output
and load;
- Satisfy the requirements for
frequency control reserve;
- Satisfy the requirements for spinning
reserve;
- Satisfy the requirements for
voltage quality.
3. Disclosing information about
electricity market intervention
a) When intervening the
electricity market, the System and market operator must disclose the following
information:
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- The trading cycles planned to
intervene.
b) within 24 hours as form the
end of the electricity market intervention, the System and market operator must
announce the following information:
- Reasons for electricity market
intervention
- The intervened trading cycles;
- The measures taken by the System
and market operator to intervene the electricity market.
Article
56. Suspending the electricity market
1. The electricity market shall
be suspended in one of the following cases:
a) States of emergency related to
natural disaster or National defense and security;
b) The System and market operator
requests the suspension in the following cases:
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- The security and continuity of
electricity market operation is not ensured.
c) The electricity market
operation does not achieve the set targets.
2. The Electricity Regulatory
Authority must consider and make decisions on suspending the electricity market
in the cases prescribed in Clause 1 aquatic products Article and notify it to
the System and market operator.
3. The System and market operator
must notify the participants in the electricity market of the decisions on
suspending the electricity market made by the Electricity Regulatory Authority.
4. Operating the electricity
system during the electricity market suspension:
a) The System and market operator
must regulate and operate the electricity system in accordance with the
following principles:
- Ensure that the system is
operated safely, stably, and reliably with lowest electricity purchase price
for the whole system;
- Fulfill the agreements on the
output in the electricity export and import contracts, PPAs of BOT power plant,
and PPAs with committed output of other power plants;
b) The power generating units, Transmission
network operators, and other relevant units must comply with the dispatch
instruction of the System and market operator.
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1. The electricity market shall
be restored when the following conditions are satisfied:
a) The causes for suspending the
electricity market are settled;
b) The System and market operator
certifies the restoration of the electricity market operation.
2. The Electricity Regulatory
Authority must consider and make decisions on restoring the electricity market
and notify it to the System and market operator.
3. The System and market operator
must notify the participants in the electricity market of the decisions on
restoring the electricity market made by the Electricity Regulatory Authority.
SECTION
4. EXPORTING, IMPORTING ELECTRICITY IN ELECTRICITY MARKET OPERATION
Article
58. Handling exported electricity when scheduling mobilization
1. Before 16:00 on D-2 day, the Single
buyer must notify the System and market operator of the estimated exported
generation output in each trading cycle of D-day.
2. The exported generation output
is calculated similarly to the load at the export location and used for
estimating the system load serving the making of day-ahead and hour-ahead
mobilization schedules.
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1. Before 16:00 on D-2 day, the Single
buyer must notify the System and market operator of the imported electricity in
each trading cycle of D-day.
2. The imported electricity is
calculated similarly to the generator at the import location with the quoted
price at 0 VND/kWh when making day-ahead and hour-ahead mobilization schedules.
Article
60. Payment for exported and imported electricity
Exported and imported electricity
is paid under the PPA signed by the Single buyer.
Chapter
VI
CALCULATING SMP AND PAYMENT IN THE ELECTRICITY MARKET
Section
1. ELECTRICITY MEASUREMENT DATA
Article
61. Provision of measurement data
1. Before 15:00 on D+1 day, MDMSP
must provide the electricity measurement data of each trading cycle of D-day to
the System and market operator.
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Article
62. Keeping measurement data
The System and market operator
must keep the electricity measurement data and relevant documents in at least 5
years.
Section
2. CALCULATING SMP AND PAID POWER
Article
63. Calculating SMP
1. After D-day, the System and
market operator must schedule the calculation of SMP for each trading cycle of
D-day in the following order:
a) Calculate the system load in
the trading cycle by converting the measurable output to the terminal of
generating stations;
b) Arrange the ranges of power in
the scheduled quotations from power generating units and the announced output
of multi-purpose strategic hydroelectric plants using the method of
unrestricted scheduling until the total power meets the system load.
2. SMP equals the quoted price
of the last range of power in the schedule of SMP calculation. In case the
quoted price of the last range of power in the schedule of SMP calculation is
higher than the ceiling market price, SMP shall equal the ceiling market price.
3. Before 9:00 on D+2 day, the System
and market operator must announce the SMP of each trading cycle of D-day.
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1. After D-day, the System and
market operator must make the power schedule for each trading cycle of D-day in
the following order:
a) The adjusted load in a trading
cycle equals the system load plus:
- a) The spinning reserve power
for the trading cycle;
- a) The frequency control power
for the trading cycle;
- The proportion of encouraged
power (at 3% of the system load of a trading cycle).
b) Arrange the ranges of power in
the scheduled quotations from power generating units and the announced output
of multi-purpose strategic hydroelectric plants using the method of
unrestricted scheduling until the total power meets the adjust load. The power
of frequency control and spinning reserve for the trading cycle of the station
is arranged with the quoted price at 0 VND/kWh.
2. The paid power of the station
in the trading cycle equals the power of that station in the power schedule.
3. Before 9:00 on D+2 day, the System
and market operator must announce the paid power of each station in the trading
cycles of D-day.
Article
65. Calculating SMP and paid power when intervening the electricity market
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a) The System and market operator
must use valid quotations to calculate SMP as prescribed in Article 63, and the
paid power as prescribed in Article 64 of this Circular;
b) In case the station does not
provide valid quotations, the System and market operator shall apply the floor
price to the hourly contractual output, and apply the ceiling price of the
quotation to non-contractual output to make SMP calculation schedule and the
power schedule for that trading cycle.
2. In case the market
intervention lasts longer than 24 hours, the System and market operator is not
responsible for calculating SMP and paid power for the intervened period.
Section
3. MAKING PAYMENTS TO DIRECT TRADING GENERATORS
Article
66. The generation output serving the electricity market payment
1. The System and market operator
must calculate the proportions of generation output or power plants in the trading
cycles serving the electricity market payment, including:
a) The generation output paid at
quoted prices for thermoelectric plants quoting prices higher than the ceiling
market price (Qbp);
b) Extra output (Qcon);
c) The generation output paid at
the SMP (Qsmp).
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a) Determining the stations with
higher quoted prices than the ceiling market price
b) The generation output paid at
quoted prices at each measuring location determined in Point a this Clause is
calculated as follows:
if 
if
In particular:
i: the ith trading
cycle;
j: the jth measurement
position of the thermoelectric plant, specified in Point a this Clause;
: the generation output paid at the quoted
price at the measuring position in the ith trading cycle (kWh);
: the measurable generation output at the
measuring position in the ith trading cycle (kWh);
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: the generation output corresponding to the
power with quoted at prices higher than the ceiling market price and arranged
in the market price calculation schedule in the ith trading cycle of
the stations connected to the measuring position j, and converted to that
measuring position (kWh).
c) The generation output paid at
the quoted price is calculated as follows:
In particular:
j: the jth measurement
position of the thermoelectric plant, specified in Point a this Clause;
J: The total number of measuring
positions of power plant with the station quoted at a higher price that ceiling
market price and scheduled to calculate the market price;
: the generation output paid at the quoted
price of the power plant in the ith trading cycle (kWh);
: the generation output paid at the quoted
price at the jth measuring position in the ith trading
cycle (kWh);
3. The extra generation output of
the power plant in the ith trading cycle is determined in the
following order:
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b) Calculating the extra
generation output in a trading cycle at the terminal of the station as follows:
- If the station is not
restricted to generate under an hour-ahead mobilization schedule and generate
extra power under dispatch instruction in a trading cycle:
- In case the station is
restricted to generate under a hour-ahead mobilization schedule:
In particular:
: extra generation output of the station at
the terminal in the ith trading cycle (kWh);
: Generation power of the station according
to the dispatch instruction of the System and market operator in the ith trading
cycle (kW);
: Generation power of the station according
to the dispatch instruction of the System and market operator in the ith
trading cycle (kW);
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: the period of extra generation according to
the dispatch instruction in the ith trading cycle (minute).
c) Calculating the extra
generation output in the trading cycle of the station, 
, by converting the output from the terminal of the station
to the measuring position.
d) Calculate the extra generation
output of the power plant in the ith trading cycle using the
following formula:
In particular:
: extra generation output of the station at
the terminal in the ith trading cycle (kWh);
g: the station that generates
extra power in the ith trading cycle;
G: total number of stations that
generate extra power of the power plant in the ith trading cycle;
: extra generation of the gth
station in the ith trading cycle (kWh);
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In particular:
: the generation output paid at SMP of the
power plant in the ith trading cycle (kWh);
: the measurable generation output of the
power plant in the ith trading cycle (kWh);
: the generation output paid at the quoted
price in the ith trading cycle for thermoelectric plants quoting
prices higher than the ceiling market price(kWh);
: extra generation output of the power plant
in the ith trading cycle (kWh).
Article
67. Market electricity payment
1. The System and market operator
must calculate the total payment for market electricity of the power plant in
the payment cycle using the following formula:
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Rg: total market electricity
payment in the payment cycle (VND);
Rsmp: payment for the generation
output paid at SMP in the trading cycle (VND);
Rbp: payment for the generation
output paid at the quoted price for thermoelectric plants quoting prices higher
than the ceiling market price in the payment cycle (VND);
: payment for the extra generation in the
payment cycle (VND).
2. The payment for the generation
paid at SMP of the power plant in the trading cycle is calculated in the
following order:
a) Calculate for each trading
cycle using the following formula:
In particular:
: payment for the generation paid at SMP of
the power plant in the ith trading cycle in the payment cycle (VND);
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: the generation paid at the SMP in the ith
trading cycle in the payment cycle (kWh);
b) Calculate for a payment cycle
using the following formula:
In particular:
: payment for the generation paid at SMP of
the power plant in the payment cycle (VND);
i: the ith trading
cycle in the payment cycle;
l: number of trading cycles in
the payment cycle;
: payment for the generation paid at SMP of
the power plant in the ith trading cycle (VND);
3. The payment for the generation
paid at the quoted price for thermoelectric plants quoting prices higher than
the ceiling market price in the payment cycle is determined in the following
order:
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ĐT: (028) 3930 3279 DĐ: 0906 22 99 66
- If the measurable generation
output of the power plant is higher or equals the generation paid at the
contractual price:
In particular:
: payment for the generation paid at the
price higher than the ceiling price of the power plant in the ith trading
cycle (VND);
j: the jth quoting
range in the quotations from the stations of the thermoelectric plants quoting
prices higher than the ceiling market price and are arranged in the SMP
calculation schedule
j: total number of quoting ranges
in the quotations from the thermoelectric plant quoting prices higher than the
ceiling market price and are arranged in the SMP calculation schedule;
: the quoted price corresponding to the jth
quoting range in the quotation of the stations of the gth thermoelectric
plant in the ith trading cycle (VND/kWh);
: the highest quoted price in the quoting
ranges arrange in the SMP calculation schedule of the thermoelectric plant in
the ith trading cycle (VND/kWh);
: Total quoted power at the price in the quotation of the
thermoelectric plant mobilized in the trading cycle and converted to the
measuring position (kWh);
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- If the measurable generation
output of the power plant is smaller than the generation paid at the
contractual price:
In particular:
: payment for the generation paid at the
price higher than the ceiling price of the power plant in the ith trading
cycle (VND);
SMPi : SMP in the ith trading
cycle (VND/kWh);
: total generation output quoted at a higher
price than the ceiling market price of the power plant in the ith trading
cycle (kWh);
b) Calculate for a payment cycle
using the following formula:
In particular:
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ĐT: (028) 3930 3279 DĐ: 0906 22 99 66
I: ith trading cycle
when the power plant is mobilized at a higher price than the ceiling price;
I: number of trading cycles when
the power plant is mobilized at a higher price than the ceiling price;
: payment for the generation quoted at the
price higher than the ceiling price of the power plant in the ith trading
cycle (VND);
4. The payment for extra
generation of the power plant in the trading cycle is determined in the
following order:
a) Calculate for each trading
cycle using the following formula:
In particular:
: payment for the extra generation in the ith
trading cycle (VND).
g: the station that generates
extra power in the ith trading cycle;
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: extra generation of the gth
station in the ith trading cycle (kWh).
: the quoted price corresponding to the extra
power range the gth stations in the ith trading cycle
(VND/kWh);
b) Calculate for a payment cycle
using the following formula:
In particular:
: payment for the extra generation in the
payment cycle (VND).
i: the ith trading
cycle of the payment cycle when the thermoelectric plant must generate extra
power according to the dispatch instruction;
l: total number of trading cycles
when the thermoelectric plant must generate extra power according to the
dispatch instruction;
: payment for the extra generation in the ith
trading cycle (VND).
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ĐT: (028) 3930 3279 DĐ: 0906 22 99 66
The System and market operator
must calculate the total payment for market power of the power plant in the
payment cycle in the following order:
1. Calculate for each trading
cycle using the following formula:
In particular:
: payment for power to the power plant in the
ith trading cycle (VND);
g: the generating station of the
power plant that is paid at CAN; (VND);
G: total number of generating
stations of that are paid at CAN; (VND);
: CAN in the ith trading cycle
(VND/kW);
: the paid power of the gth station
in the ith trading cycle (kW);
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ĐT: (028) 3930 3279 DĐ: 0906 22 99 66
In particular:
: payment for power to the power plant in the
payment cycle (VND);
i: the ith trading
cycle in the payment cycle;
l: total number of trading cycles
in the payment cycle;
: payment for power to the power plant in the
ith trading cycle (VND);
Article
69. Payment under contracts for difference
Based on the SMP and CAN
announced by the System and market operator, power generating units must
calculate the payment under contract for difference in the payment cycle in the
following order:
1. Calculate for each trading
cycle using the following formula:
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ĐT: (028) 3930 3279 DĐ: 0906 22 99 66
In particular:
: the difference of payment in the ith trading
cycle (VND);
: the generation paid at the contractual
price in the ith trading cycle (kWh);
Pc: price of contract for
difference (VND/kWh);
SMPi : SMP in the ith trading
cycle (VND/kWh);
CANi: CAN in the ith trading
cycle (VND/kWh).
2. Calculate for a payment cycle
using the following formula:
In particular:
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i: the ith trading
cycle in the payment cycle;
l: number of trading cycles in
the payment cycle;
: the difference of payment in the ith
trading cycle (VND);
Article
70. Payments during electricity market intervention
If the market intervention is
shorter than 24 hours, power generating units shall receive the payments in
Article 67, Article 68, and Article 69 with the SMP and paid power specified in
Article 65 of this Circular.
If the market intervention ≥ 24
hours, power generating units shall be paid at the contractual price for all measurable
generation.
Article
71. Payment during electricity market suspension
During the electricity market
suspension, power generating units shall be paid at the contractual price for
all measurable generation.
Section
4. PAYMENT FOR ANCILLARY SERVICES AND OTHER PAYMENTS
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1. The System and market operator
must calculate payment for the opportunity cost to power generating units that
provide spinning reserve services in the payment cycle in for following order:
a) Calculate for each trading
cycle using the following formula:
In particular:
: payment for the opportunity cost to the
power generating units in the ith trading cycle (VND).
g: the station that provide
spinning reserve services of the power generating units in the ith trading
cycle;
G: total number of stations that
provide spinning reserve services of the power generating units in the ith
trading cycle;
: dispatched power of spinning reserve
services of the gth station in the ith trading cycle
according to the hour-ahead mobilization schedule (kWh);
: opportunity cost in the ith trading
cycle of the gth station (VND/kWh); The opportunity cost is
calculated as follows:
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In particular:
SMPi : SMP in the ith
trading cycle on D-day (VND/kWh);
: highest quoted price in the quoted prices
corresponding to the ranges of power of spinning reserve services (VND/kWh).
Calculate for a payment cycle
using the following formula:
In particular:
: payment for the opportunity cost in the
trading cycle (VND).
i: the ith trading
cycle in the payment cycle when the power generating unit provides spinning
reserve services;
l: total number of trading cycles
in the payment cycle when the power generating unit provides spinning reserve
services;
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2. The opportunity cost is only
paid to thermoelectric generating stations that provide spinning reserve
services.
Article
73. Payments for spinning reserve, fast-start reserve, cold start reserve, and
reliability must-run services
Units that provide services of
spinning reserve, fast-start reserve, cold start reserve, and reliability
must-run shall be paid under the contracts to provide ancillary services signed
with the System and market operator.
Article
74. Payment to multi-purpose strategic hydroelectric plants
The payment to multi-purpose
strategic hydroelectric plants are made under the PPAs signed with the Single
Buyer.
Article
75. Other payments
1. Power generating units having
stations that generate reactive power serving the voltage regulation shall be
paid for the electricity taken from the grid to generate reactive power:
a) Based on the SMP, applicable
to stations that provide quotations on the electricity market;
a) Based on PPAs, applicable to
stations that do not provide quotations on the electricity market.
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3. In case the monthly generation
measurement provided by MDMSP as prescribed in Clause 2 Article 61 does not match
the total generation measurement of the days in that month provided by MDMSP as
prescribed in Clause 1 Article 61 of this Circular, the difference of
generation shall be paid at the price in the PPA signed by the Single Buyer and
the power generating unit.
Section
5. PAYMENT ORDER AND PROCEDURES
Article
76. Data serving the electricity market payment
Before 9:00 on D+2 day, the
System and market operator must summarize and provide the data serving the
payment to each power plant to the Single Buyer and power generating units as
prescribed in this Annex 6 of Circular.
Article
77. The statement of payment of the trading day.
1. Before D+4 day, the System and
market operator must make and send the preliminary statement of electricity
market payment on that trading day under the form provided in this Annex 4 of Circular
to the Single Buyer and power generating units.
2. Before D+6 day, direct trading
generators and the Single Buyer must notify the errors in the preliminary statement
of electricity market payment (if any) to the System and market operator.
3. On D+6 day, the System and
market operator must make and send the complete statement of electricity market
payment on D-day to the Single Buyer and power generating units.
Article
78. The statement of electricity market payment for the payment cycle
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2. Within 10 working days as from
the last trading day of the payment cycle, the System and market operator must
make and issue the statement of electricity market payment for the payment
cycle.
3. The statement of electricity
market payment for the payment cycle includes the statements of payment for
each trading day and the summary table made under the form provided in this Annex
5 of Circular, and the written certification specifying the counter number and
the generation.
Article
79. Electricity payment documents
1. Direct trading generators
shall make and send the invoices of electricity market payments to the Single
Buyer based on the statement of electricity market payment for the payment
cycle.
2. The power generating unit
shall make and send the invoices of contract payments to the Single Buyer under
the PPAs signed by the Single Buyer and the power generating unit.
3. Before 20th every
month, the power generating unit must make and send payment invoices to the
Single Buyer. The invoices include the electricity market payments and contract
payments in the payment cycle.
Article
80. Invoices of payments for auxiliary service contracts
Power generating units must make
invoices of ancillary services payments according to auxiliary service
contracts between power generating units and the System and market operator.
Article
81. Invoice adjustment
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2. Power generating units must
add the adjusted payment to the invoice of the next payment cycle.
Article
82. Making payment
1. On the last day of the month
at the latest, the Single Buyer and the System and market operator must make payment
under the invoices from power generating units.
2. Power generating units and the
Single Buyer must reach an agreement on the method of payment in the
electricity market in conformity with this Circular and relevant provisions.
Article
83. Handling errors of payment
If the payment is excessive or
insufficient compared to the invoice, the relevant units shall handle such
errors in accordance with the PPA or the auxiliary service contract.
Chapter
VII
SOFTWARE SERVING THE ELECTRICITY MARKET OPERATION
Article
84. Software serving the electricity market operation
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a) Market simulation model;
b) Water value calculation model;
c) Mobilization and dispatch
scheduling program;
d) Programs serving payment
calculation;
dd) Other software programs
serving the electricity market operation.
2. The System and market operator
must develop and use the software serving the electricity market operation.
Article
85. Requirements for software serving the electricity market operation
1. Ensure the accuracy,
reliability, confidentiality, and satisfy the standards formulated by the
System and market operator.
2. Have technical and operational
guides.
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1. The software service the
electricity market operation must be develop to support the calculation and
trading prescribed in this Circular, and the operation process of the
electricity market.
2. The System and market operator
must:
a) Formulate the standards of software
serving the electricity market operation;
b) Appraise and check the
adherence to the standards prescribed in Point a this Clause before applying;
c) Announce the list of algorithm
and order of using the software serving the electricity market operation.
Article
87. Software audit
1. The software serving the
market must be audited in the following cases:
a) Before the official operation
of the electricity market;
b) Before putting new software
into use;
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d) Periodic audit
2. The software audit shall be
carried out by independent audit units. The System and market operator must
choose independent audit units and obtain the approval from the Electricity
Regulatory Authority.
Chapter
VIII
THE ELECTRICITY MARKET INFORMATION SYSTEM AND PROVISIONS ON
INFORMATION DISCLOSURE.
Section
1. THE ELECTRICITY MARKET INFORMATION SYSTEM
Article
88. The structure of the electricity market information system
The electricity market
information system comprises the following components:
1. The system of hardware and
software serving the management and exchange of the electricity market
information.
2. The database and storage
system.
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Article
89. The management and operation of the electricity market information system
1. The System and market operator
must develop, manage, and operate the electricity market information system.
2. The participants in the
electricity market must invest in the devices within their management in order
to satisfy the technical requirements set by the System and market operator, ensuring
the connection with the electricity market information system.
3. MDMSP must develop, manage,
and operate the connection network between the electricity market information
system of the System and market operator and the devices of participants in the
electricity market.
4. The System and market operator
only operates or changes the electricity market information system after it is
completely appraised and approved by the Electricity Regulatory Authority.
5. The System and market operator
must equip backup devices for the market information system in order to
collect, transmit, and disclose information when the primary the electricity
market information system malfunctions or fails to operate.
Section
2. MANAGING AND DISCLOSING ELECTRICITY MARKET INFORMATION
Article
90. Providing and disclosing electricity market information
1. Power generating units, the
Single Buyer, transmission network operators, and MDMSP must provide the System
and market operator with the information and data serving the making of
operation plans, mobilization schedules, and payment calculation as prescribed
in this Circular via the website of the electricity market information system.
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3. The range of accessing
information is provided in accordance with the functions of the units as
prescribed in the Process of operating the electricity market information
system and information disclosure.
4. The System and market operator
must public announce the following information on public websites:
a) Information about participants
in the electricity market;
b) Data about the system load;
c) The market price statistics;
d) Other information prescribed
in the Process of operating the electricity market information system and
information disclosure.
Article
91. Responsibility to ensure the accuracy of electricity market information
1. Participants in the market
must ensure the accuracy and sufficiency of electricity market information.
2. If the provided information is
not accurate and complete, the participants in the market must rectify and
provide the accurate one to relevant units.
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1. The System and market operator
must not reveal the information provided by participants in the electricity
market, including:
a) Information about PPAs;
b) The quotations from power
generating units before the end of the trading day;
c) Other information ultra vires.
2. Participants in the
electricity market must not reveal the information apart from one authorized to
provide and announce.
Article
93. Exemption from information security
1. Providing information at the
request of the Electricity Regulatory Authority or competent agencies as
prescribed by law.
2. The information summarized,
analyzed from the information announced on the electricity market at variance
with Article 92 of this Circular, not being provided by participants in the
electricity market.
Article
94. Storing electricity market information
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Section
3. ELECTRICITY MARKET OPERATION REPORTS
Article
95. Disclosing information about electricity market operation
The System and market operator
must periodically make and disclose the information about the electricity
market operation prescribed in the Process of operating the electricity market
information system. In particular:
1. Before 15:00 every day, make
and announce the report on the electricity market operation of the previous
day.
2. Before Tuesday every week,
make and announce the report on the electricity market operation of the
previous week.
3. Before 10th every
month, make and announce the report on the electricity market operation of the
previous month.
4. Before January 31st
every year, make and announce the report on the electricity market operation of
the previous year.
Article
96. Electricity market operation reporting regime
1. Before 10th every
month, the System and market operator must send the report on the electricity
market and electricity system operation of the previous month to the
Electricity Regulatory Authority under the form provided by the Electricity
Regulatory Authority.
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3. Within 24 hours as from stopping
intervening in the electricity market, the System and market operator must
report the electricity market intervention to the Electricity Regulatory
Authority.
4. The System and market operator
must make and send irregular reports on the operation of the electricity system
and the electricity market at the request from the Electricity Regulatory
Authority..
Article
97. Audit of the electricity market data and adherence
1. Periodic audit
Before January 31st every year,
the System and market operator must organize and complete the audit of the
electricity market data and adherence of the previous year. The annual audit
includes:
a) Auditing the data and
calculations of the System and market operator in the electricity market,
including:
- The data serving the
electricity market calculation;
- The calculation steps;
- The calculation results.
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2. Irregular audit
The Electricity Regulatory
Authority is entitled to request the System and market operator to organize
irregular audit in the following cases:
a) Detecting unusual signs in
electricity market operation;
b) At the request of participants
in the electricity market. In particular:
- The participant in the
electricity market shall send a written request to the Electricity Regulatory
Authority, specifying the contents and reasons for audit;
- Within 30 days as from
receiving the written request, the Electricity Regulatory Authority must
consider and make decisions on approving or disapproving the request for audit,
specifying the contents and range of audit, or the explanation for the
disapproval.
3. The System and market operator
must appoint a competent independent audit unit to audit the electricity market
and obtain the approval from the Electricity Regulatory Authority.
4. Participants in the
electricity market must be cooperative during the electricity market audit.
5. The expense on audit:
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b) Is paid by the unit that
request the audit in the case prescribed in Point b Clause 2 this Article.
6. Within 10 days after the
audit, the System and market operator must send reports to the Electricity
Regulatory Authority and relevant units.
Chapter
IX
SETTLING DISPUTES AND HANDLING VIOLATIONS
Section
1. SETTLING DISPUTES
Article
98. Order for settling disputes in the electricity market
1. The disputes arising in the
electricity market shall be settle in accordance with the Regulation on the
procedures for settling disputes in the electricity market promulgated by the
Ministry of Industry and Trade.
2. Before settling disputes, the
parties must negotiate to seek reconciliation within 60 days in one of the
following forms;
a) Voluntary reconciliation;
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Article
99. Responsibility of the parties during the conciliation
1. Reaching agreements on the
form of conciliation, the time and location of negotiation.
2. Providing sufficient and
accurate information and documents related to the dispute.
3. Giving legal proof to protect
the lawful rights and interests.
4. Participating in the
negotiation in an amicable and cooperative manner.
5. During the conciliation, if
the dispute denotes violations of electricity market regulations, the party
that detects must notify the other party to stop conciliating and send reports
to the Electricity Regulatory Authority.
Article
100. Notification of disputes and preparation of negotiation
1. When disputes arise, the
complainer must send written notification to the complained of the dispute, and
the request for dispute settlement, and send 1 copy to the Electricity
Regulatory Authority as a report.
2. Within 15 days as from receiving
the notification, the parties must reach an agreement on the form of
conciliation, the dispute to be settle, the time and place of negotiation. For
conciliation via an intermediary, the parties must reach an agreement on the
selection of the intermediary. The parties may change the intermediary before
the anticipated time of conciliation.
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1. Voluntary reconciliation
The parties must discuss and
reach an agreement on the dispute settlement.
2. Conciliation via an
intermediary
a) The parties must select an
intermediary and make an agreement on the responsibility of the intermediary;
b) The parties must provide the
contents of the dispute, the information and documents related to the dispute,
and the requirements of both parties to the intermediary.
c) The parties may or may not
concur with the solution given by the intermediary; and may request the intermediary
to amend and supplement such solution, or make an agreement on new solutions.
Article
102. Conciliation records
1. After the conciliation or the
conciliation period expires, the disputing parties must make the conciliation
record, including:
a) The time and place of
conciliation;
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c) Summary of the dispute;
d) Requirements of the parties;
dd) The agreed contents;
e) The disagreed contents and
explanation for disagreement.
2. Within 05 days as from making
the conciliation record, the parties must send the Electricity Regulatory
Authority 01 copy as a report.
Article
103. Settling disputes at the Electricity Regulatory Authority
1. The parties may present the
case to the Electricity Regulatory Authority for settling in the following
cases:
a) The conciliation fails after
the conciliation period prescribed in Clause 2 Article 98 of this Circular, or
one party does not participate in the conciliation.
b) One party fails to implement
the agreements in the conciliation record.
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Section
2. HANDLING VIOLATIONS
Article
104. Detecting and reporting violations
1. The detected acts of
violations in the electricity market must be reported to the Electricity
Regulatory Authority in writing.
2. The violation report includes:
a) Name and address of the unit
that reports;
b) Name and address of the unit
that commits the violations;
c) The violations;
d) The day and time of committing
violations;
dd) The reason for violation
detection.
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1. The Electricity Regulatory
Authority must verify the violation within 05 days as from being reported.
2. While verifying the violation,
the Electricity Regulatory Authority is entitled to:
a) Request the reported unit and
reporting unit to provide necessary information and documents serving the
verification;
b) Request the reported unit to
explain;
c) Request examination and obtain
opinions from experts or relevant agencies;
d) Summon the reported unit and the
unit affected by the violation to obtain opinions about the settlement and
remedy of the violation.
3. During the verification, the
Electricity Regulatory Authority must secure the information and documents in
accordance with the provisions on information security prescribed in this
Circular.
Article
106. Making violation records.
1. Within 30 days as from the
verification, the Electricity Regulatory Authority must finish, verify, and
make records on the violations of provisions on electricity market operation. The
complicated cases that need more time to verify, the verification period may be
extended but must not exceed 60 days as from the commencement of the verification.
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3. If the verification shows that
the reported unit does not commit violations of the provisions on electricity
market operation, the Electricity Regulatory Authority shall stop the
inspection and notify the reporting organization or individual.
Article
107. Forms of handling violations
1. The violating unit must incur
one of the penalties for each violation in accordance with the provisions on
handling violations of electricity.
2. For power plant committing
violations prescribed in Clause 1 Article 8 of this Circular, apart from the
penalties prescribed in Clause 1 this Article, they also have their
participation in the electricity market suspended. The suspension period
depends on the nature and extent of the violations, but must not exceed 6
months.
Article
108. Order and procedures for suspending the electricity market participation
1. For power plants committing
violations prescribed in Clause 1 Article 8 of this Circular, within 05 days as
from making the violation record, the Electricity Regulatory Authority shall
consider and make send the decision on suspending the participation in the
electricity market of the power plant that commits violations to the violating
power plant and the System and market operator.
2. Within 01 day as from
receiving the decision on suspending the participation in the electricity
market, the System and market operator must announce the suspension.
3. If the power plant fails to
rectify the violation when the period in Clause 2 Article 107 of this Circular
expires, the Electricity Regulatory Authority is entitled to suspend the
participation in the electricity market. The extension must not exceed 6 months
as from the suspension expires.
Chapter X
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Article
109. Implementation organization
1. The Electricity Regulatory
Authority must disseminate, guide, inspect, and supervise the implementation of
this Circular.
2. Vietnam Electricity must guide
the System and market operator to:
a) Establish and send the
technical process to The Electricity Regulatory Authority for promulgation
within 06 months as from this Circular takes effect, including:
- The process of making
year-ahead, month-ahead, and week-ahead schedules;
- The process of choosing best
new plant and calculating CAN;
- The process of electricity
market simulation;
- The process of water value
calculation;
- The process of classifying
stations and calculating the ceiling price of the quotation of thermoelectric
plants;
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- The process of operating the
market information system and information disclosure.
b) Invest in, construct, install,
and upgrade the electricity market information system and the software serving
the electricity market appropriate for the requirements prescribed in this
Circular.
3. The participants in the
electricity market must complete the information devices appropriate for the
electricity market information system prescribed in this Circular.
4. The power generating units
participating in the electricity market must Power purchase agreement (PPA)
under the form promulgated by the Ministry of Industry and Trade applicable to
competitive generation market
5. Relevant units must report the
difficulties arising during the course of implementation to the Electricity
Regulatory Authority for considering and requesting the Ministry of Industry
and Trade to amend and supplement this Circular.
Article
110. Effects
1. This Circular takes effect on
June 25, 2010.
2. The director of The
Electricity Regulatory Authority, The Chief of the Ministry Office, the Chief
Ministerial Inspector, Directors of relevant Departments affiliated to
Ministries, relevant units, and electricity market members are responsible for
implementing this Circular./.
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FOR THE
MINISTER
DEPUTY MINISTER
Do Huu Hao