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MINISTRY OF
INDUSTRY AND TRADE
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SOCIALIST REPUBLIC
OF VIET NAM
Independence - Freedom – Happiness
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No.: 03/2013/TT-BCT
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Ha Noi, February
08, 2013
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CIRCULAR
REGULATION
ON OPERATION OF COMPETITIVE GENERATION MARKET
Pursuant to Decree No. 95/2012/ND-CP of
November 12, 2012 of the Government defining the functions, tasks, powers and
organizational structure of the Ministry of Industry and Trade;
Pursuant to Electricity Law dated December
03, 2004;
Pursuant to Decision No. 26/2006/QD-TTg dated
January 26, 2006 by the Prime Minister on the approval roadmap, the conditions
of formation and development of the electricity market levels in Vietnam;
At the proposal of the Director of Department
of Electricity Regulation;
The Minister of Industry and Trade issues
Circular on operation of competitive generation market.
Chapter I
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Article 1. Scope of
regulation
This Circular provides for operation of the
competitive generation market (hereinafter referred to as electricity market) and
the responsibility of the units involved in the electricity market.
Article 2. Subject of
application
This Circular applies to units involved in
electricity market as follows:
1. Unique wholesaling unit
2. Generating unit
3. Electricity system and market operating
unit.
4. Power transmission unit.
5. Power metering data management unit.
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Article 3. Explanation
of term
In this Circular, the terms below are
construed as follows:
1. Price quotation is the offer to
sell electricity on the market of each set handed in to electricity system and
market operating unit and under the form of price quotation specified in this
Circular.
2. Scheduling price quotation is the
price quotation approved by the electricity system and market operating unit for
day and hour-ahead mobilization schedule.
3. Payment list is a calculation of
the payments for power plant in the electricity market made by the electricity
system and market operating unit for each trading day and each payment cycle.
4. Interference in electricity market
is the action to change the normal operation mode of the electricity market
that unit operation of the electricity system and electricity market must be
applied to handle the situations specified in Clause 1, Article 57 of this
Circular.
5. Group offer is the offering
mechanism when a representative unit carries out the offer for the whole group
of ladder hydropower plant.
6. Full load cost is the variable cost
of generating set when operating at full load mode, calculated in dong / kWh.
7. Transaction cycle is the cycle of
the calculation of electricity price in the electricity market over a period of
01 hour from the first minute of each hour.
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9. Announced capacity is the largest
available capacity of generating set announced according to the timetable
market by the offering unit or the electricity system and market operating unit
and generating unit having signed contract of auxiliary services supply.
10. Moderate capacity is the capacity
rate of the generating set actually mobilized in the transaction cycle power
system operation and actual deposit market in the transaction cycle by the
electricity system and market operating unit.
11. Capacity of hour-ahead mobilization
is the capacity rate of generating set expected to be mobilized for the first
hour in the schedule of hour-ahead mobilization.
12. Capacity of day-ahead mobilization
is the capacity rate of generating set expected to be mobilized for transaction
cycles in the schedule of day-ahead mobilization according to the biding
scheduling result.
13. Incrementally generated capacity
is the difference capacity between moderate capacity and arranged capacity in
the schedule of market price calculation of the generating set.
14. Payment capacity is the capacity
of the set in the schedule of hour capacity and is paid with market capacity
price.
15. Auxiliary services are the
services of frequency regulation, rotation backup, fast start backup, cold
backup, operation to be generated due to constraint of power system security,
voltage regulation and black start.
16. Incrementally generated power is the
power of generating set due to be mobilized corresponding to the Incrementally
generated capacity.
17. Price offering unit is the unit which
shall directly submit a quotation in the electricity market, including power generating
units or power plants that are registered for direct pricing offer and the
representative pricing offer unit for group of ladder hydropower plants.
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19. Generating unit is the unit
possessing one or a lot of power plants taking part in electricity market and
signing power sale and purchase contract
20. Generating unit of indirect
transaction is the generating unit having power plant and not entitled to
make pricing offer directly in the electricity market.
21. Generating unit of direct transaction
is the generating unit having power plant and entitled to make pricing offer
directly in the electricity market.
22. Power metering data management unit
is a unit providing, installing, managing operation of system of gathering,
processing and storing power metering data and information transmission line in
service of electricity market.
23. Power transmission unit is a power
unit licensed to operate in the area of power transmission and responsible for
management and operation of the national transmission grid.
24. Electricity system and market
operating unit is a unit directing and controlling the process of power generation,
power transmission and distribution in national electricity system and running
transactions on electricity market.
25. Market capacity price is the price
level for a unit of active capacity determined for each transaction cycle
applied to calculate payment of capacity to the generating units in the electricity
market.
26. Floor price of quotation is the
lowest price level which the offering unit is permitted for offer to a
generating set in day-ahead quotation.
27. Market power price is the price
level for a unit of power unit defined for each transaction cycle, used to
calculate payments for power generating units in the electricity market.
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29. Ceiling price of quotation is the
highest price level which the offering unit is permitted for offer to a
generating set in day-ahead quotation.
30. Ceiling price of electricity market
is the rate of highest market power price determined for each year.
31. Water value is the expected
marginal cost to calculate the amount of water stored in the reservoir used to generate
power in lieu of other sources of thermal power in the future, to be converted
to a unit of power.
32. Performance degradation coefficient
is the performance degradation index of the generating set over the operating
time.
33. Yearly or monthly average load factor
is the ratio between the total power output generated in 01 year or 01 month
and the product of total capacity output set with capacity with a total number
of calculation hours of yearly or monthly load capacity.
34. Electricity market information system
is the system of equipment and data base in service of management and exchange
of information on electricity market and is managed by the electricity system
and market operating unit
35. Power sale and purchase contract
is a a written agreement of power sale and purchase between the unique
wholesaling unit and generating or power trading units with foreign countries.
36. Power sale and purchase contract for
difference is the power sale and purchase agreement signed between unique
wholesaling unit with the generating unit of direct transaction under the form
issued by the Ministry of Industry and Trade.
37. Default interest rate is the interest
rate is calculated by non-term interest rate of Vietnam dong on the
interbank market at the time of payment.
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39. Non-binding schedule is the
orderly arrangement of mobilization of the generating sets according to the
method of minimizing power purchasing cost not taking into account the
technical constraints in the power system.
40. Capacity schedule is scheduled by
the electricity system and market operating unit after the operation to
determine the payment capacity in each transaction cycle.
41. Hour-ahead mobilization schedule
is the expected mobilization schedule of sets for power generation and supply
of auxiliary services to the transaction cycle ahead and three consecutive
transaction cycles made by the electricity system and market operating unit.
42. Day-ahead mobilization schedule is
the expected mobilization schedule of sets for power generation and supply of
auxiliary services to the transaction cycles of the transaction day ahead made
by the electricity system and market operating unit.
43. Schedule of market power price
calculation is the one made by the electricity system and market operating
unit after the current transaction day to determine market power price for each
transaction cycle.
44. Electricity market simulation model
is a system of simulation softwares mobilizing the generating sets and
calculating the market power price used by the electricity system and market
operating unit in the yearly, monthly and weekly operation planning.
45. Water value calculation model is a
system of hydro-thermal optimization softwares to calculate the water value
used by the electricity system and market operating unit in the yearly, monthly
and weekly operation planning.
46. Limited water level is the lowest
upstream water level of the hydroelectric reservoir at the end of each month of
the year or at the end of each week of the month calculated and announced by
the electricity system and market operating unit.
47. Year N is the current year of operation
of the electricity market, which is calculated according to calendar year.
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49. Transaction day is the day of the
electricity market transaction activities, from 0h00 to 24h00 daily.
50. BOT power plant is a power plant
invested in the form of Build-Operate-Transfer through contract between
investor and competent state agency.
51. Best new power plant is a thermal
power plant put into operation with the lowest average generation price
calculated for the year ahead and the price of electricity sale and purchase contract
agreed based on generation price range for standard power plant issued by the
Ministry of Industry and Trade. Best new power plant shall be selected annually
for use in the calculation of market capacity.
52. Multi-objective strategic hydropower
plant is the large hydropower plants having an important role in terms of society,
economy, national defense and security exclusively built and operated by the
state.
53. Group of ladder power plants is a
set of hydropower plants, in which the amount of water discharged from the
reservoir of higher ladder hydropower plant accounting for all or most of the water
volume flowing to reservoir of the lower hydropower plant and between these two
power plants there is no regulating reservoir greater than 01 week.
54. Mobilization scheduling software
is a software system that the electricity system and market operating unit uses
to prepare hour and day-ahead mobilization schedule for the generating sets in
the electricity market.
55. System sub-loading is the total
power output of the whole electrical system converted to the terminals of the
generating sets and imported power output in a transacton cycle minus the
output of the poewer plants with capacity of less than or equal to 30 MW not
participating in electricity market.
56. Metered output is the power to be
measured of the power plant at the location of measurement.
57. Hourly contract output is the
power output allocated from the monthly contract output for each transaction
cycle and paid under the sale and purchase contract for difference.
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59. Monthly contract output is the
power output allocated from yearly contract output for each month.
60. Yearly planning output is power
output of pwoer plant expected to be mobilized in the year ahead.
61. Monthly planning output is the
power output of power plant expected to be mobilized in months of a year.
62. Heat loss capacity is the amount
of consumed heat energy of the set or power plant to produce one power unit.
63. Binding generation payment is the
payment which the generating unit receives for the increased amount of power
generation.
64. Electricity market participants
are units engaged in transaction activities or providing services in the
electricity market as prescribed in Article 2 of this Circular.
65. Lack of capacity is a situation
when the total announced capacity of all the generating units is less than the
subloading demand of subloading of forecasting system in a transaction cycle.
66. Security information is the
confidential information as prescribed by law or by agreement between parties.
67. Market information is all data and
information related to the operation of the electricity market.
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69. Mobilization order is the result
of power range arrangement in the quotation on the principle of non-binding
scheduling.
70. Excessive capacity is the
situation when the total amount of capacity offered at the floor price of the generating
unit of direct transaction and capacity expected to be mobilized of the power plants
of generating units of indirect transactions and announced by the electricity
system and market operating unit in a transaction cycle larger than the
subloading of forecasting system.
71. Total calculation hours of yearly
loading coefficient is the total number of hours of the year N for the sets
put into commercial operation since year N-1 and earlier or the total number of
hours from the time of commercial operation of generating set until the end of
the year for generating sets put into commercial operation in year N, minus the
repair time of the generating set according to the approved plans in year N.
72. Total calculation hours of monthly
loading coefficient is the total number of hours of month M for sets put
into commercial operation since lmonth M-1 and earlier or the total number of
hours from the time of commercial operation of the generating set until the end
of month for generating sets put into operation in the month M, minus the
repair time of the generating unit according to the approved plan in month M.
73. Slow startup set is the one unable
to start and connect to grid in a time of less than 30 minutes.
Chapter II
REGISTRATION
FOR ELECTRICITY MARKET PARTICIPATION
Article 4. Responsibility
for electricity market participation
1. Power plant having electricity operation
license in the field of generation, with an installed capacity greater than 30
MW connected to the national electricity system, excluding power plants
specified in Clause 2 of this Article must participate in electricity market.
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a) BOT power plants;
b) Power plants using renewable energy not as
hydropower;
c) Power plants in the industrial zone only
sell a portion of the output to the national electricity system and do not
determine long-term electricity selling plan.
3. Prior to November 1 in year N-1, the unit
operating power system and electricity market shall make a list of power plants
with installed capacity larger than 30 MW not participating in the market, the
units indirectly participating in electricity market in year N and submit it to
the Department of electricity regulation for approval.
4. The power plants participating in
electricity market are responsible for investment and improvement of the
equipment system for the connection to the electricity market information
system, SCADA / EMS system and power metering system to meet the operation requirements
of the electricity market.
Article 5. Dossier of
electricity market participation registration
1. Generating units possessing power plants
specified in Clause 1, Article 4 of this Circular are responsible for
submission of dossier of electricity market participation registration for each
power plant.
2. The dossier comprises:
a) Registration for electricity market
participation specifying name, address of the generating unit and power plant.
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c) Acceptance documents to put into operation
equipment system for the connection to the electricity market information
system, SCADA / EMS system and power metering system;
d) Other necessary information as required by
the electricity system and market operating unit.
3. In case the generating unit has power
plant put into commercial operation but not registered to participate in the
electricity market for that power plant, within 60 days from the time the power
plant is granted electricity operation license for commercial operation, the
electricity system and market operating unit shall continue to schedule and
announce capacity mobilization diagram for this power plant and this plant is temporarily
paid the full actual output generated in the payment cycle at a price equal to
90% of the price in the power sale and purchase contract signed between the two
parties.The difference amount (10% remaining) shall be settled in the first
month's payment cycle when the plant directly participates in price offering in
the electricity market.
Article 6. Approval
of dossier of electricity market participation registration
1. Within 10 working days from the date of
receipt of valid dossier, the electricity system and market operating unit is
responsible for assessing and submitting it to Department of electricity
regulation for approval.
2. In case of invalid dossier, within 05
working days from the date of its receipt, the electricity system and market
operating unit must have a written request to the generating unit for
supplementation and completion of dossier.
3. Within 05 working days from the date of
receipt of written report of the electricity system and market operating unit,
the Department of electricity regulation is responsible for issuing approval
decision and notifying the electricity system and market operating unit in
order to put the power plant into the list of electricity market participation.
4. Within 05 working days from the date when
the power plant is allowed to participate in electricity market, the generating
unit shall register with the electricity system and market operating unit on
the susbject offering price in electricity market (the generating unit or power
plant).
Article 7.
Information of electricity market participants
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2. The electricity system and market
operating unit shall store registration information and update changes on registration
information of electricity market participants.
3. The electricity market participants shall
notify the electricity system and market operating unit upon changes of
registered information.
4. The electricity system and market
operating unit shall publicize registration information of the electricity
market participants and the changed registration information.
Article 8. Suspension
and restoration of the right to participate in electricity market of power
plant.
1. The power plant is suspended the right to
participate in electricity market in the following cases:
a) Failing to fully implement the provisions
of Clause 4, Article 4 of this Circular;
b) Having one of the following acts:
- Failing to provide information or provide accurate
information to the planning for electricity market operation and mobilization
schedule of sets in the power system;
- Making agreement with the electricity
system and market operating unit or other generating units in the price
offering for mobilization schedule not as prescribed.
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- Other acts of violation causing serious
consequences on supply of electricity or finance to other units in the
electricity market.
2. The Department of electricity regulation
has a right to suspend the right to participate in electricity market of any
power plant having acts of violation prescribed in Clause 1 of this Article.
The order and procedures to suspend the right to participate in electricity
market are specified in Article 112 of this Circular.
3. During the time the power plant is
suspended its right to participate in electricity market:
a) The generating unit or power plant are not
entitled to make price offering in electricity market but must comply with othe
provisions of this Circular.
b) The electricity system and market
operating unit shall schedule and publicize the capacity mobilization diagram
for the power plant suspended its right to participate in electricity market.
The plant shall be temporarily paid all output generated in the payment circle
at a price equal to 90% of the price in the power sale and purchase contract
signed between the two parties.The difference amount (10% remaining) shall be
settled in the first month's payment cycle when the plant is restored its right
to participate in electricity market.
4. The suspended power plant shall be
restored the right to participate in electricity market when meeting the
following conditions:
a) Upon expiration of suspension of the right
to participate in electricity market is over;
b) Having completed obligations specified in
the decision on suspension of the right to participate in electricity market.
5. When fully meeting conditions specified in
Clause 4 of this Article, the power plant shall send written request for
restoration of the right to participate in electricity market together with
evidencing documents to the electricity system and market operating unit which
shall check and make report to the Department of electricity regulation to
permit the power plant to participate in electricity market.
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Article 9. Termination
of electricity market participation
1. The power plant shall terminate its
electricity market participation in the following cases:
a) At the proposal of the generating unit
possessing the power plant in the following cases:
- The generating unit’s power plant has
stopped operating or generating into the national electricity system;
- The generating unit’s power plant does not
maintain and is not able to restore its installed capacity greater than 30MW.
b) The power plant’s electricity operation
license in the field of power generation is revoked or expired.
2. In case specified at Point a, Clause 1 of
this Article, the generating unit possessing power plant shall submit dossier
to request termination of electricity market participation to the electricity
system and market operating unit for appraisal and submission to Department of
electricity regulation for consideration within a time limit of at least 30
days before the time to terminate its electricity market participation.
3. The electricity system and market
operating unit shall update dossier of registration information storage and
publicize information on termination of electricity market participation of the
power plant.
4. In case the power plant has acts of
violation before the time to terminate the electricity market participation,
the generating unit possessing power plant shall continue to implement
provisions concerning inspection and handling of violation as specified in this
Circular.
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PRINCIPLES
OF ELECTRICITY MARKET OPERATION
Article 10. Limit of
offering price
1. The offering price of units in electricity
market is limited from the floor price of quotation to the ceiling price of
quotation.
2. The rate of ceiling price of quotation of thermoelectric
set is determined annually and adjusted monthly and calculated based on on the
following factors
a) Heat loss capacity of generating set;
b) Performance degradation coefficient over
the operating time of generating set.
c) Fuel price;
d) Additional cost coefficient;
e) Variable price under power sale and
purchase contract.
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4. Limit of offering price of hydropower sets
is determined by water value weekly and speccified in Article 39 of this
Circular.
Article 11. Water
value
1. Water value is used to make operating plan
for year, month and week ahead and determine the limit of offering price of
hydropower set in electricity market.
2..The electricity system and market
operating unit shall calculate and publicize water value according to market timetable
specified in Appendix I of this Circular.
Article 12. Total
market price
Total market price for transaction cycle is
calculated by the total of the two following components:
1. Market power price.
2. Market capacity price.
Article 13. Market
power price
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2. Market power price shall be calculated by
the electricity system and market operating unit after the time of operation
based on the method of non-binding schedule.
3. Market power price shall not exceed the
rate of market ceiling price calculated by the electricity system and market
operating unit and annually approved by Department of electricity regulation.
4. The determination of market power price is
specified in Article 65 and 67 of this Circular.
Article 14. Market
capacity price
1. Market capacity price for each transaction
cycle is calculated by the electricity system and market operating unit during
year-ahead operation planning.
2. Market capacity price is calculated on the
principle to ensure the best new power plant recovers adequately fixed and
variable costs.
3. The determination of market capacity price
is specified in Article 25 and 26 of this Circular.
Article 15. Power
sale and purchase contract for difference
1. The generating unit of direct transaction and
the unique wholesaling unit shall sign the power sale and purchase contract for
difference under the form issued by the Ministry of Industry and Trade.
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3. Monthly contract output is determined by
the electricity system and market operating unit in the year-ahead operation
planning process based on the allocation of yearly contract output in the months
in accordance with Article 28 of this Circular.
4. Hourly contract output is determined by
the electricity system and market operating unit in the month-ahead operation
planning process based on the allocation of monthly contract output in the
hours in month in accordance with Article 28 of this Circular.
5. Department of electricity regulation shall
determine and publicize the rate of payment output at contract price of
generating units annually according to each technological type on the principle
as follows:
a) Harmonization assurance of objectives:
- Gradually reduction of rate of payment
power output at contract price;
- Stability of revenue of generating unit;
- Stability of average generation price in
accordance with regulation on preparation of electricity retail price list.
b) The rate of payment power output at
contract price is specified separately for types of hydropower and thermal
power technology. This rate is not higher than 95% and not lower than 60%.
Article 16. Principle
of payment in electricity market
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2. The payment at market price only applies
to generating unit of direct transaction and is calculated based on the
following factors:
a) Market power price;
b) Market capacity price;
c) Power output and mobilization capacity.
3. Payment to generating units of direct
transaction is made in accordance with provisions in Chapter VI of this
Circular.
4. Generating units of indirect transaction
are paid in accordance with provisions in power sale and purchase contract.
Chapter IV
ELECTRICITY
MARKET OPERATION PLAN
Section 1. YEAR-AHEAD
OPERATION PLAN
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1. The electricity system and market
operating unit shall make year-ahead operation plan including the following
contents:
a) Choosing the best new power plant;
b) Calculating market capacity price;
c) Calculating water value and optimal water
level of hydropower reservoir;
d) Calculating price limit of quotation of thermoelectric
set;
e) Determining market ceiling price;
g) Assuming the prime responsibility and
coordinating with the unique wholesaling unit to calculate planning output,
yearly contract output and allocate the yearly contract output to months in
year of generating unit of direct transaction.
2. The electricity system and market
operating unit shall use the market simulation model to calculate the contents
specified at Points a, b, c, d and e, Clause 1 of this Article. The input
parameters used in the market simulation of the thermoelectric sets is the
variable cost of the generating set defined in Clause 3 of this Article, the
hydrological characteristics and technical specifications of hydroelectric
power plants.
3. The variable cost of the thermoelectric
set is defined as follows:
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In which:
VC: Variable cost of the thermal generating
set (dong/kWh);
f: Additional cost coefficient, is calculated
by the ratio of the sum of the start-up costs, fuel costs, auxiliary materials
and variable operation and maintenance costs for generation compared to the
cost of main fuel;
PNL: Price of main fuel of thermoelectric
set (dong/kCal or dong/BTU);
HR: Heat loss capacity of thermoelectric set
(BTU/kWh or kCal/kWh);
- Fuel price in year N is the fuel price published
for year N by competent state agencies or in the long-term primary fuel sale
and purchase contract. In case of both types of fuel prices, use the fuel price
published by the competent State agencies for year N. In the absence of both
types of fuel prices, the fuel price in year N is calculated by the average of
the actual fuel price used for payment of the last 12 months prior to the
planned operation in year N;
- Heat loss capacity of thermoelectric set
(HR) is determined by the heat loss capacity agreed in contract or in dossier of
power sale and purchase contract negotiation provided by the unique of
wholesaling unit and adjusted by the performance degradation coefficient. In
case in the contract or dossier of contract negotiation, there is only
characteristic of loss capacity at loading levels, the heat loss of generating
sets is determined at loading level in proportion to the average power output
generated of many years of power plant specified in power sale and purchase
contract.
In case the thermoelectric set does not have
data of heat loss capacity in the contract or in dossier of power sale and
purchase contract negotiation, the heat loss capacity of that power plant is
determined by the heat loss capacity of standard power plant in the same group
by generating technology and installed capacity. The electricity system and
market operating unit shall calculate the heat loss capacity of standard power
plant.
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In case the thermal power plant does not have
data of performance degradation coefficient in the contract or in dossier of
power sale and purchase contract negotiation, apply the performance degradation
coefficient of standard power plant in the same group with that power plant
determined by the electricity system and market operating unit.
- Additional cost coefficient (f) of thermoelectric
set determined by the unique wholesaling unit based on the data in the contract
or in dossier of power sale and purchase contract negotiation and provided to
the electricity system and market operating unit. In case the aditional cost
coefficient of the thermal generating set is not included in the contract or in
dossier of power sale and purchase contract negotiation, the additional cost
coefficient of that thermal generating set is determined by the method of
determination of power price; order, procedures for construction, issuance of
generation price range and approval of power sale and purchase contract.
b) In case there is no heat loss capacity
data in dossier of power sale and purchase contract negotiation and there is no
standard power plant in the same appropriate group, the variable cost of the set
is determined by the variable price in the contract updating factors affecting
the variable price in year N by the method agreed in the contract.
4. The electricity system and market
operating unit shall submit the year-ahead operating plan to Vietnam
Electricity Group for appraisal and to Department of electricity regulation for
approval according to market schedule specified in Annex 1 of this Circular.
The submitted dossier includes calculation result, input data and calculation
explanation.
5. In case the coal and gas price for
generation has a big change compared with the time of approving year-ahead
operation plan, Department of electricity regulation shall consider and require
the electricity system and market operating unit to update data and
re-calculate the operation plan for remaining months in the year for submission
to Vietnam Electricity Group for appraisal and to Department of electricity
regulation for approval
Article 18. Classification
of hydropower plants
1. The hydropower plants in electricity
market are classified as follows:
a) Multi-objective strategic hydropower plant;
b) Group of ladder hydropower plants;
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d) Group of hydropower plants with regulating
reservoir from 02 days to 01 week;
dd) Group of hydropower plants with
regulating reservoir of less than 02 days.
2. Annually, the electricity system and
market operating unit shall update list of hydropower plants specified in
Clause 1 of this Article.
3. Based on the proposal of Vietnam
Electricity Group, Department of electricity regulation shall make a list of multi-objective
strategic hydropower plant so that the Ministry of Industry and Trade submits
it to the Prime Minister for approval.
Article 19. Subloading
forecasting for year-ahead operation planning.
The electricity system and market operating
unit shall forecast the subloading in service of year-ahead operation planning.
1. Total system subloading demand and
subloading of the North, Central and South respectively for the whole year and
for each month of the year.
2. Subloading diagram of typical days of the North,
Central, South, and the whole system of months in a year.
3. Maximum and minimum capacity of system
subloading in each month.
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1. The electricity system and market
operating unit shall determine demand of types of auxiliary for year ahead as
prescribed in Regulation on transmission electricity system.
2. The electricity system and market
operating unit shall select power plant to supply auxiliary services and sign
contract of auxiliary services supply with generating unit under the form
issued by the Ministry of Industry and Trade.
Article 21. Classification
of year-ahead base load, intermediate load and peak load set.
1. The electricity system and market
operating unit shall classify the base load, intermediate load and peak load
set as specified in the classification process of generating set and
calculation of ceiling price of quotation of thermal power plant.
2. The electricity system and market
operating unit shall use the market simulation model to determine the annual
average load factor of generating sets.
3. Based on the annual average load factor
from simulation result, the sets are classified into 03 (three) groups as
follows:
a) Group of base load sets including
generating sets with annual average load factor greater or equal to 60%;
b) Group of intermediate load sets including
generating sets with annual average load factor greater than 25% or less than
60%;
c) Group of peak load sets including
generating sets with annual average load factor greater or equal to 25%;
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1. In case of determination of heat loss
value:
a) Ceiling price of quotation of thermoelectric
set is determined by the following formula:
In which:
: Ceiling price of quotation of thermoelectric
set (dong/kWh);
f: Additional cost coefficient, is calculated
by the ratio of the sum of the start-up costs, fuel costs, auxiliary materials
and variable operation and maintenance costs for generation compared to the
cost of main fuel;
KDC: Ceiling price adjustment
coefficient by the classification result of thermoelectric set. For base load thermoelectric
set KDC = 2%; intermediate load thermoelectric set KDC =
5%; peak load thermoelectric set KDC = 20%;
PNL: Main fuel price of thermoelectric
set (dong/kCal or dong/BTU);
HR: Heat loss capacity at average loading
level of thermoelectric set (BTU/kWh or kCal/kWh);
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2. In case there is no data of heaf loss
capacity in contract or in dossier of power sale and purchase contract negotiation
and there is no standard in the same appropriate group:
a) Ceiling price of quotation of thermoelectric
set is determined by the following formula:
In which:
: Ceiling price of quotation of thermoelectric
set (dong/kWh)
KDC: Ceiling price adjustment
coefficient by the classification result of thermoelectric set. For base load thermoelectric
set KDC = 2%; intermediate load thermoelectric set KDC =
5%; peak load thermoelectric set KDC = 20%;
: Variable price for year N under power sale
and purchase contract for difference of power plant (dong/kWh).
b) Variable price used to calculate ceiling
price of quotation is the expected variable price for year N provided by the
unique wholesaling unit to the electricity system and market operating unit.
3. Floor price of thermoelectric set are
specified in Clause 3, Article 10 of this Circular.
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Article 23. Determination
of market ceiling price
1. The electricity system and market
operating unit shall calculate market ceiling price options. There are at least
03 (three) options:
2. Market ceiling price for year N is
determined on the principle:
a) Not less than variable cost of base and
intermediate load thermoelectric sets directly offering price in electricity
market.
b) Not greater than 115% of the highest
ceiling price of quotation in base and intermediate load thermoelectric sets
directly offering price in electricity market.
Article 24. Selection
of best new power plant
1. The best new power plant for year N is the
power plant participating in electricity market fully meets the following
criteria:
a) Starting commercial operation and
generating the entire installed capacity in the year N-1;
b) Being a base load power plant classified
by criteria in Clause 3, Article 21 of this Circular;
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d) Having the lowest average total generation
cost for 01 kWh
2. The unique wholesaling unit shall make
list of power plants meeting criteria at Point a and c, Clause 1 of this
Article and provide data of power sale and purchase contracts of these power
plants to the the electricity system and market operating unit to determine the
best new power plant. The data includes:
a) Variable price for year N;
b) Fixed price for year N;
c) Agreed power output to calculate contract price.
3. In case there is no power plant meeting
criteria specified at Points a, b and c, Clause 1 of this Article, the
electricity system and market operating unit shall use list of selected new
plants for year N-1 and require the unique wholesaling unit to update, and
provide data again as specified in Clause 2 of this Article for calculation and
selection of the best new power plant for year N.
4. The electricity system and market
operating unit shall calculate the average total generation cost for 01 kWh of
power plants meeting criteria specified at Points a, b and c, Clause 1 of this
Article by the following formula:
: Average total generation cost for 01 kWh of
power plant (dong/kWh);
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: Variable price for year N under power sale
and purchase contract for difference of power plant (dong/kWh);
: Agreed power output to calculate contract
price for year N of power plant (kWh);
: Expected power output in year N of power
plant determined from the market simulation model by the method of binding
schedule (kWh).
5. List of the best new power plants arranged
in order of average total generation cost for 01 kWh from low to high. The best
new power plant selected for year N is the power plant with the lowest average
total generation cost for 01 kWh according to calculation result in Clause 3 of
this Article
Article 25. Principle
to determine market capacity price.
1. Ensuring the best new power plant fully
recovers generation cost upon participation in electricity market.
2. Not applying market capacity price during
night off-peak hours which are from 0h00 to 4h00 and from 22h00 to 24h00.
3. Market capacity price is proportional to
the subloading of forecasting system for the transaction cycle.
Article 26. Order to
determine market capacity price
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1. Determining Yearly deficient cost of the
best new power plant.
a) Determining expected revenue in the market
of the best new power plant in year N by the following formula:
In which:
RTTD: Expected revenue through
market power price of the best new power plant in year N (dong);
i: Transaction cycle i in year N
I: Total transaction cycles in year N
SMPi: Expected market power price
of transaction cycle i in year N determined from the electricity market
simulation model by the method of non-binding schedule (dong/kWh);
: Expected output of the best new power plant
in transaction cycle i in year N determined from the electricity market
simulation model by the method of binding schedule (kWh);
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In which:
TCBNE: Yearly generation cost of
the best new power plant in year N (dong);
PBNE: Average total generation
cost for 01 kWh of the best new power plant defined in Clause 4, Article 23 of
this Circular (dong/kWh);
: Expected output of the best new power plant
in transaction cycle i in year N determined from the electricity market
simulation model by the method of binding schedule (kWh);
i: Transaction cycle i in year N;
I: Total transaction cycles in year N.
c) Yearly deficient cost of the best new
power plant is determined by the following formula:
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AS: Yearly deficient cost of the best new
power plant in year N (dong);
TCBNE: Total yearly generation
cost of the best new power plant in year N defined at Point b of this Clause
(dong);
: Expected revenue through the market power
price of the best new power plant in year N defined at Point a of this Clause
(dong);
d) In case when calculating the yearly
deficient cost with negative value by the lowest market ceiling price plan, the
electricity system and market operating unit shall make report to the
Department of electricity regulation to select the next best new power plant in
the list of new specified in Article 24 of this Circular and recalculate or
review the list of power plant participating in electricity market in order to
determine the ceiling price reasonably.
2. Determining monthly deficient cost
The monthly deficient cost of the best new
power plant is determined by allocation of yearly deficient cost to months in
year N by the following formula:
In which:
t: Month t in year N;
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AS: Yearly deficient cost of the best new
power plant in year N (dong);
: Peak load capacity in month t (MW).
3. Determining market capacity price for
transaction cycle.
a) Determining the yearly average available
capacity of the best new power plant by the following formula:
In which:
QBNE: Average available capacity
in year N of the best new power plant (kW);
I: Total transaction cycles in year N minus
night off-peak hours;
i: Transaction cycle in which the best new
power plant expected to be mobilized minus night off-peak hours;
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b) Determining market capacity price for each
year-ahead transaction cycle by the following formula:
In which:
I: Total transaction cycles in month t,
excluding night off-peak hours;
i: Transaction cycle I trong month t;
excluding night off-peak hours;
: Market capacity price of transaction cycle
i (dong/kW);
QBNE: Average available capacity
in year N of the best new power plant (kW);
MS: Deficient cost of month t of the best new
power plant (dong);
: Subloading of forecasting system of
transaction cycle i according to subloading diagram of forecasting typical day
of month t specified in Article 19 of this Circular (MW);
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Article 27. Determination
of yearly contract output
Yearly contract output of power plant is
determined in the process of year-ahead operation planning including the
following steps:
1. Planning the year-ahead operation by the
method of binding schedule. The input parameter used in planning year-ahead
power system operation is the total price of thermal power plants, hydrological
characteristics and technical specifications of thermal power plants
2. Calculating the yearly planning output of
power plant by the following formula:
if 
if 
if 
In which:
: Planning output in year N of power plant (kWh);
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GO: Power output generated on average in many
years of power plant specified in power sale and purchase contract (kWh);
a, b: Yearly output adjustment coefficient is
determined in accordance with regulation on the method of determination of
generation price; order and procedures of construction and issuance of
generation price range and approval of power sale and purchase contract.
3. Calculating the yearly contract output of
power plant by the following formular:
In which:
Qc: Yearly contract output in year N (kWh);
: Yearly contract output in year N of power
plant (kWh);
: Rate of output paid under contract price
for year N (%). The rate of this output is specified in Clause 5, Article 15 of
this Circular.
Article 28. Determination
of monthly contract output
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1. Using the market simulation model by the
method of binding schedule to determine the monthly expected output of power
plant.
2. Determining the monthly contract output by
the following formula:
In which:
: Contract output of month t of power plant
(kWh);
Qc : Yearly contract output of power plant
(kWh);
: Expected output in month t of the power
plant determined from the market simulation model by the method of binding
schedule (kWh).
Article 29. Responsibilities
for determination and signing monthly and yearly contract output.
1. The electricity system and market
operating unit shall:
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b) Send result of contract output calculation
to the unique and generating unit of direct transaction for checking.
2. The unique wholesaling unit and generating
unit of direct transaction shall:
a) Provide data to the electricity system and
market operating unit to calculate monthly and yearly contract output;
b) Check and coordinate with the electricity
system and market operating unit to handle discrepancy in the results of
calculation;
c) Supplementing appendix and amendment of
appendix of monthly and yearly contract output contract to the power sale and
purchase contract for difference according to the result of calculation.
Article 30. Determination
of price of expected average generation price for year N.
1. The electricity system and market
operating unit shall calculate the expected average generation price for year N
and the rate of change of the expected average generation price compared to the
year N-1.
2. The yearly average generation price is calculated
by the following formula:
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j: Power plant j of the generating unit of
direct transaction;
J: Total power plant of the generating units
of direct transaction ;
PPDTB: Average generation price of
entire system in year N (dong/kWh);
: Average total market price in year N
specified in Clause 4 of this Article (dong/kWh);
: Total power output in year N of entire
system (kWh);
: Total power output in year N of generating
units of direct transaction (kWh);
: Total power output in the power sale and
purchase contract for difference in year N of the power plant j (kWh);
: Price of power sale and purchase contract
for difference in year N of the power plant j (kWh);
: Total cost of power purchase from BOT power
plants in year N (dong);
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CDVPT: Total cost of auxiliary services
purchase in year N (dong).
3. Average total market price is determined
by the following formula:
In which:
i: Transaction cycle i in year N;
I: Total transaction cycle in year N;
: Average total market price in year N (dong/kWh);
: Expected output generated in market of all
power plants participating in market in transaction cycle i determined from the
binding market simulation model (kWh);
: Expected market power price of transaction
cycle i determined from the non-binding market simulation model (dong/kWh);
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Section 2.
MONTH-AHEAD OPERATION PLAN
Article 31. Subloading
forecasting for month-ahead operation planning.
The electricity system and market operating
unit shall forecast the subloading in service of month-ahead operation planning
by the method specified in Regulation on transmission electricity system
1. Total system subloading demand and
subloading of the North, Central and South for entire month and each week of
the month.
2. Subloading diagram of typical days of the
North, Central, South, and the whole system for weeks in a month.
Article 32. Water
value calculation
The electricity system and market operating
unit shall calculate water value for weeks in the next month. The result of
calculation is used to plan month-ahead operation including:
1. Expected output of multi-objective strategic
hydropower plants.
2. Water value of hydropower plant in group
of ladder hydropower plants.
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4. Limited water level of weeks in a month of
reservoirs.
Article 33. Classification
of month-ahead base, intermediate and peak load set
1. The electricity system and market
operating unit shall classify the month-ahead base, intermediate and peak load
set under the process of set classification and calculation of monthly ceiling
price of quotationof thermal power plant.
2. The electricity system and market
operating unit shall use the market simulation model to determine the monthly
average load coefficient of generating sets in the next month.
3. Based on the monthly average load coefficient
from the simulation result, the sets are classified into 03 (three) groups as
follows:
a) Group of base load sets including
generating sets with monthly average load coefficient greater or equal to 70%;
b) Group of intermediate load sets including
generating sets with monthly average load coefficient greater than 25% or less
than 70%;
c) Group of peak load sets including
generating sets with monthly average load coefficient less than or equal to
25%;
Article 34. Adjustment
of ceiling price of thermoelectric set
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a) Fuel price of thermal power plant in the
next month in case the ceiling price of quotation is method specified in
Article 22 of this Circular.
Month-ahead fuel price is the price published
by the competent agency and applied for the next month. In case there is no
data on fuel price published by the competent agency, the month-ahead fuel
price is the fuel price according to the payment dossier of the last month
prior to the time of month-ahead planning. The unique wholesaling unit shall
update information on fuel price of thermal power plants for the next month and
provide it to the electricity system and market operating unit and also notify
generating units;
b) Variable price of thermal power plants in
case the ceiling price of quotation is determined under Clause 2, Article 22 of
this Circular.
The unique wholesaling unit shall update
changes on variable price of thermal power plants and provide it to the
electricity system and market operating unit;
c) Result of classification of thermal power
plant for the next month specified in Article 33 of this Circular.
2. The electricity system and market
operating unit shall publish the ceiling price of quotation of thermoelectric
set in the next month according to market schedule specified in Appendix I of
this Circular.
Article 35. Adjustment
of monthly contract output.
1. The monthly contract output shall be
adjusted in case the repair and maintenance schedule of the plant of month M is
changed compared to yearly operation plan as required of the electricity system
and market operating unit to ensure electricity system security, not due to
causes of the plant. The adjustment of monthly contract output in this case is
on the following principle: the change of output Qc between months in
proportion to the time of repair to ensure the invariable adjusted total Qc of
months in a year.
In case the plant is changed its repair and
maintenance schedule at the end of year, the output Qc in proportion to
reparing time of this month.
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Article 36. Determination
of hourly contract output
The electricity system and market operating
unit shall determine the hourly contract output in the next month for the power
plant by the following steps:
1. Using the market simulation model to
determine the expected hourly output in month of the plant by the method of
binding schedule.
2. Determining the hourly contract output by
the following formula:
In which:
i: ith Transaction cycle in month;
I: Total cycles in month;
: Contract output of the power plant in transaction cycle i (kWh);
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: Monthly contract output of the power plant
is determined in Article 28 of this Circular (kWh).
3. In case the contract output of the power
plant in transaction
cycle i is greater than the highest generated output of the power plant, the
contract output in that transaction cycle is adjusted by the highest generated
output of the power plant;
4. In case the contract output of the thermal
power plant in transaction
cycle i is greater than 0 (zero) MW and less than the lowest stable generation
capacity (Pmin) of the power plant, the contract output in that transaction
cycle shall be adjusted by the lowest stable generation capacity of the power
plant which is determined by the lowest stable generation capacity of 01 (one)
set of the power plant scheduled for mobilization in electricity market model
of that cycle.
In case the contract output of hydropower
plants is less than the lowest
stable generation capacity, it is likely to be adjusted by 0 (zero) MW or the
lowest stable generation capacity.
5. The electricity system and market
operating unit shall allocate the different total output due to adjustment of
hourly contract output specified in Clause 3 and 4 of this Article in different
hours in month on the principle to ensure invariable monthly contract output
and comply with provisions in the process of year, month and month ahead
operation planning.
6. The electricity system and market
operating unit shall send the result of calculation of hourly contract output to
the unique wholesaling unit and the generating unit of direct transaction
according to electricity market timetable specified in Appendix I of this
Circular.
7. The unique wholesaling unit and the
generating unit of direct transaction shall sign to confirm the monthly
contract output adjusted under Article 35 and hourly contract output according
to the result of calculation of electricity system and market operating unit.
Section 3. YEAR-AHEAD
OPERATION PLAN
Article 37. Week-ahead
water value
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2. The electricity system and market
operating unit shall update and recalculate the week-ahead water value and
publish the following results:
a) Water value and expected weekly output of
the multi-objective strategic hydropower plant;
b) Water value of groups of ladder hydropower
plants and hydropower plants with regulating reservoirs over 01 week;
c) Expected weekly output of hydropower
plants with regulating reservoirs of less than 02 days;
d) Limited water level of hydroelectric
reservoirs with regulating capacity over 01 week.
Article 38. Determination
of contract output of hydropower plants with regulating reservoirs from 02 days
to 01 week.
1. The electricity system and market
operating unit shall calculate and publish the weekly contract output and
allocate the weekly contract output for each transaction cycle in a week of
hydropower plants with regulating reservoirs from 02 days to 01 week according
to provisions in the process of year, month and month ahead operation planning.
2. The electricity system and market
operating unit shall send the weekly contract output of hydropower plants with
regulating reservoirs from 02 days to 01 week to the unique whosaling unit and
generating units. These two units shall sign to confirm the weekly contract
output of the plant as a basis for electricity payment.
Article 39. Limit of
offering price of hydropower plant
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a) Floor price of quotation is 0 (zero)
dong/kWh;
b) Ceiling price of quotation is equal to the
highest value of:
- Water value of that plant;
- Average price of ceiling prices of
quotation of thermoelectric sets participating in electricity market in monthly
operation planning;
c) Every month, the electricity system and
market operating unit shall publish the average price of ceiling prices of
quotation of month-ahead thermoelectric sets for hydropower plants at the same
time of publication of ceiling price of quotation of month-ahead thermoelectric
sets.
2. Limit of offering price of hydropower
plant with regulating reservoir from 02 days to 01 week is determined as
follows:
a) Floor price of quotation is 0 (zero)
dong/kWh;
b) Ceiling price of quotation is equal to the
highest value of:
- Highest water value of hydropower plants
participating in the market;
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c) Every week, the electricity system and
market operating unit shall publish the highest water value of hydropower
plants participating in week-ahead market to the hydropower plants with
regulating reservoirs from 02 days to 01 week.
Chapter V
ELECTRICITY
MARKET OPERATION
Section 1. DAY-AHEAD
ELECTRICITY MARKET OPERATION
Article 40. Information
for day-ahead electricity market operation
Before 10h00 on day D-1, the electricity
system and market operating unit shall determine, calculate and publish the
following information:
1. Subloading forecasting diagram of day D of
the entire system and of the North, Central and South.
2. The expected output of the multi-objective
strategic hydropower plant and the plants indirectly participating in the
market, BOT plants in each day-ahead transaction cycle.
3. Day-ahead total expected gas output of gas
thermal power plants sing the same source of gas.
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5. Results of security assessment of
short-term system for day D as prescribed in Regulation on transmission
electricity system.
Article 41. Price
quotation
Price quotation must comply with the
following principles:
1. Having 05 (five) pairs of offering price
(dong/kWh) and capacity (MW) for the set in each transaction cycle of day D.
2. Capacity in the price quotation is the
capacity at the terminal of generating set.
3. Offering capacity of subsequent offering
range must not be lower than capacity of preceding offering range.
4. Having information on technical parameters
of the set including:
a) Published capacity of the set for the day
D;
b) Lowest stable generation capacity of the
set.
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d) Technical binding upon simultaneous
operation of the sets.
5. The published capacity of the set in the
quotation of day D shall not be lower than the rate of published capacity in
day D-2 according to the process of security assessment of short term
electricity system specified in the Regulation on transmission electricity
system except for the case of unforeseen technical problems. The plant shall
update the published capacity upon occurrence of problems leading to reduction
of available capacity.
6. In normal condition, the first range of
offering capacity in the price quotation of thermoelectric sets must be equal
to the lowest stable generation capacity of the set. The last range of offering
capacity must be equal to the published capacity. For thermoelectric plants
during startup and stopping are allow to update the hourly quotation with
capacity lower than the lowest stable generation capacity.
7. The hydropower plants may offer the first
ranges of capacity in each hour equal to 0 (zero) MW but the last range of
offering capacity must be equal to the published capacity.
9. Unit of offering price is dong/kWh, with
the smallest number of decimal as 0.1.
Offering price is between the floor price and
the ceiling price of the set and shall not decrease in the increasing way of
the offering capacity.
The form of price quotation is specified in
Appendix III of this Circular.
Article 42. Price
offering for group of ladder hydropower plants
1. The group of ladder hydropower plants
shall make price offering under a general price quotation for the entire group
and comply the limit of offering price specified in Article 38 of this
Circular.
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3. In case of failing to register the
representative unit for price offering for the group of ladder hydropower
plants, the electricity system and market operating unit shall make price
offering on behalf of the plants in this group in accordance with water value
of the group.
4. The representative unit for price offering
shall comply with regulations on price offering for all power plants in the group
of ladder hydropower plants.
5. In case the power plant in the group of
ladder hydropower plants propose the price offering, based on the proposal of
the power plant in the group of ladder hydropower plants and the binding
optimization of water use of the entire group, the Department of electricity
regulation shall consider and decide on price offering of this hydropower
plant.
6. The water value of the group of ladder
hydropower plants is the water value of the largest hydoelectric lake in that
ladder. The electricity system and market operating unit shall determine the
hydoelectric lake used to calculate water value for group of ladder hydropower
plants together with the classification of hydropower plants specified in
Article 18 of this Circular.
7. In case the group of ladder hydropower
plants has the multi-objective strategic hydropower plant:
a) The electricity system and market
operating unit shall publish the hourly generation output in the next week of
each hydropower plant in the group of ladder hydropower plants specified in
Clause 2, Article 37 of this Circular;
b) When the published output of the
multi-objective strategic hydropower plant in the group is adjusted specified
in Article 53 of this Circular, the electricity system and market operating
unit shall adjust the published output of power plants at lower ladder
accordingly.
Article 43. Price
offering of other hydropower plants
1. Other hydropower plants with regulating
reservoirs from 02 days or more make price offering and comply with the limit
of offering price specified in Article 39 of this Circular.
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a) Offering price is 0 d/kWh for all offering
ranges;
b) Offering range is equal to the expected generation
capacity of the set in the transaction cycle.
Article 44. Submission
of price quotation
1. Before 11:30 on day D-1, the price
offering unit shall submit a price quotation on day D.
2. The price offering units shall submit the
price quotation through the market information system. In case of problems so
the market information system cannot be used, the price offering unit shall
agree with the electricity system and market operating unit on other methods for
the submission of price quotation in order of priority as follows:
a) By E-mail to the mail address of the
electricity system and market operating unit;
b) By Fax through the fax number specified by
the electricity system and market operating unit;
c) Submission of quotation directly at the
electricity system and market operating unit.
Article 45. Checking
validity of price quotation
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2. In case the price quotation is not valid,
the electricity system and market operating unit shall notify the submitting
unit immediately and require this unit to re-submit the final price quotation prior
to the end of price offering.
3. After receiving notification of the
electricity system and market operating unit of the invalid price quotation,
the price offering unit shall modify and re-submit it prior to the end of price
offering.
Article 46. Scheduling
price quotation
1. After the end of price offering, the
electricity system and market operating unit shall check the validity of price
quotations last received specified in Article 41 of this Circular. The valid
final price quotation shall be used as the scheduling price quotation for
day-ahead mobilization scheduling.
2. In case the electricity system and market
operating unit does not receive the price quotation or the final price
quotation of price offering unit is invalid, the electricity system and market
operating unit shall use the default price quotation of that generating unit as
the scheduling price quotation.
3. The default price quotation of power
plants is determined as follows:
a) For thermal power plants, the default
price quotation is the last valid price quotation. In case the last valid price
quotation is not appropriate with the actual state of operation of the set, the
default price quotation is the one in proportion to the current state and the
fuel used in the set of default price quotation used for that month of the set.
The price offering unit shall develop the set of default price quotation used
for the next month of the thermoelectric set in proportion to the state of
operation and fuel of the set and submit it to the electricity system and
market operating unit before the 25th date of each month.
b) For hydropower plants and group of ladder
hydropower plants, the default price quotation is the one with the offering
price equal to the published weekly water value.
Article 47. Data used
for day-ahead mobilization scheduling
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1. Daily subloading diagram of the entire
system and the North, Central and South.
2. Schedlung price quotations of the price
offering units.
3. Published capacity of the hydropower
plants specified in Clause 2, Article 37, Clause 7, Article 42 and Clause 2,
Article 43 of this Circular.
4. Power output imported and exported
specified in Article 60 and Article 61 of this Circular.
5. Capacity of the sets of power plants
providing auxiliary services.
6. Requirement on rotation backup capacity
and frequency regulation.
7. Repair and maintenance of transmission
power grid and generating sets approved by the electricity system and market
operating unit.
8. Testing schedule of generating set.
9. Mobilization diagram of power plants which
are suspended their right to participate in electricity market specified in
Clause 3, Article 8 of this Circular.
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11. Results of security assessment of
short-term system for day D as prescribed in Regulation on transmission
electricity system.
12. Updated information about the
availability of the transmission grid and the generating sets from the SCADA
system or provided by the electricity system and market operating unit.
Article 48. Day-ahead
mobilization schedule
The electricity system and market operating
unit shall make day-ahead mobilization schedule:
1. Non-binding schedule including:
a) Expected market power price in each
day-ahead transaction cycle;
b) Mobilization order of generating sets in
each day-ahead transaction cycle.
2. Binding schedule including:
a) Expected mobilization diagram of each set
in each day-ahead transaction cycle, marginal price of each region in each
day-ahead transaction cycle.
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c) Method of operation, expected wire
connection diagram of the power system in each day-ahead transaction cycle.
d) Warning information (if any)
3. Day-ahead schedule in case of excessive
capacity.
The electricity system and market operating
unit shall calculate the stopping and re-startup of sets in case of excessive
capacity on the principle as follows:
a) Stopping the sets with the price of
electricity sale and purchase contract in the order from high to low;
b) Stopping the sets with the startup cost
from low to high;
c) Upon re-startup in the order of set with
the price of electricity sale and purchase contract in the order from low to
high;
d) Calculating the stoppage time of sets to
meet the requirements of the system and restricting the up and down operation of
the sets many times.
Article 49. Publication
of day-ahead schedule
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1. Expected mobilization capacity including
capacity of frequency regulation and rotation backup of the sets in each
day-ahead transaction cycle. The marginal price of each region in each
day-ahead transaction cycle.
2. Expected market power price for each
day-ahead transaction cycle.
3. List of sets expectedly increasing or
decreasing capacity in each day-ahead transaction cycle.
4. Information about warning of day-ahead
capacity shortage (if any), including:
a) Transaction cycles with expected capacity
shortage;
b) Amount of power shortage;
c) Security binding of violated system;
5. Information about warning of day-ahead
excessive capacity (if any) including:
a) Transaction cycles of expected excessive
capacity;
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Article 50. Grid
connection to generating set
1. For low startup set, the generating unit
shall prepare everything to connect the grid of this set according to day-ahead
schedule published by the electricity system and market operating unit. In case
the startup time of the set is larger than 24 hours, the generating unit shall
connect the grid of this set based on the results of security assessment of
short-term system published by the electricity system and market operating
unit.
2. For the set of non-slow startup, the
generating unit shall prepare everything to connect the grid of this set
according to day-ahead schedule published by the electricity system and market
operating unit.
3. During the process of grid connection of
thermoelectric sets, the generating unit shall update hourly capacity in the
hourly quotation 60 minutes in advance in service of operation and payment
calculation.
Article 51. Measures
of handling upon warning of capacity shortage.
1. Modification of price quotation
a) Price offering unit is permitted for
modification and submits the day-head price quotation or for the remaining
transaction cycles in day D to the electricity system and market operating unit
60 minutes prior to operation time with the change of price quotation.
b) The modified price quotation must not
decrease its offering capacity and change offering price compared with
day-ahead quotation of that price offering unit;
c) The electricity system and market
operating unit shall the validity of modified price quotations and use them as
scheduling price quotation to make hour-ahead mobilization schedule and
calculate electricity market price.
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3. The electricity system and market
operating unit is permitted to modify the published capacity of
multi-subjective strategic hydropower plants specified in Clause 2, Article 53
of this Circular.
Section 3. OPERATION
OF HOUR-AHEAD ELECTRICITY MARKET.
Article 52. Data of
hour-ahead mobilization schedule
The electricity system and market operating
unit shall use the following data for hour-ahead mobilization schedule
1. Subloading diagram of the entire system
and the North, Central and South forecasting an hour ahead and subsequent 03
hours.
2. Grid connection of low startup set
according to the published day-ahead schedule.
3. The scheduling price quotations of the
price offering units with the update of hourly quotations of low startup sets
in the process of grid connection. The hourly quotation of the sets during the
stoppage of set and the sets publishing capacity increase in case of power
shortage.
4. Published output of the multi-objective
strategic hydropower plants.
5. Capacity of frequency regulation, rotation
backup, quick startup backup, cold backup and operation to be generated due to
the hour-ahead security binding of electricity system
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7. Other system security bindings.
8. Testing schedule of generating set.
Article 53. Adjustment
of published output of the multi-objective strategic hydropower plant
1. Before hour-ahead mobilization schedule,
the electricity system and market operating unit is permitted for adjustment of
hourly output of the multi-objective strategic hydropower plant published as
specified in Clause 2, Article 40 of this Circular in the following cases:
a) There are abnormal fluctuations in
hydrology;
b) There are warnings of capacity shortage according
to day-ahead schedule;
c) There is a decision of the competent state
agencies on regulation of reservoir of the multi-objective strategic hydropower
plant in service of purpose of flood control and irrigation.
2. Scope of adjustment of hourly output of
the multi-objective strategic hydropower plant in cases specified at Point a,
b, Clause 1 of this Article is ±5% of the total installed capacity of the
multi-objective strategic hydropower plant in the power system excluding the
capacity for frequency regulation and rotation backup.
Article 54. Hour-ahead
schedule
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2. Making hour-ahead mobilization schedule in
case of shortage of capacity.
a) The electricity system and market
operating unit shall make mobilization schedule in the order as follows:
- According to the scheduling price quotation;
- The multi-objective strategic hydropower
plant according to the adjusted capacity;
- The sets providing quick startup backup
services, the sets providing cold backup services according to day-ahead
mobilization schedule
- The sets providing operational services to
be generated due to security binding of electricity system.
- Rotation backup capacity;
- Reduction of backup capacity of frequency
regulation to a permissible lowest level.
b) The electricity system and market
operating unit shall check and determine the expected amount of capacity to be
discharged to ensure the system security.
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The electricity system and market operating
unit shall adjust the hour-ahead schedule through measures in the order as
follows:
a) Stopping the sets which voluntarily stop
generation.
b) Gradually decreasing generation capacity
of low startup sets to the lowest stable generation capacity;
c) Minimally decreasing generation capacity
of the set providing the rotation backup service.
d) Minimally decreasing generation capacity
of the set providing the frequency regulation service.
e) Stopping the sets of low startup in the
order as follows:
- Having the shortest startup time;
- Having power sale and purchase contract
price from high to low;
- Having startup cost from low to high. This
cost is agreed between the unique wholesaling unit with the electricity system
and market operating unit;
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Article 55. Publication
of hour-ahead schedule
The electricity system and market operating
unit shall publish the hour-ahead schedule 15 minutes prior to the operation
hour including the following contents:
1. The hour-ahead subloading forecasting of
entire system and the North, Central and South;
2. Mobilization schedule of generating sets,
marginal price in the North, Central and South in hour ahead and 03 subsequent
hours scheduled specified in Article 54 of this Circular.
3. Handling measures of the electricity
system and market operating unit in case of shortage or excess of capacity.
4. Information about adjustment of published
capacity of the multi-objective strategic hydropower plant specified in Article
53 of this Circular.
5. Expected subloading discharge schedule.
Section 3. REAL TIME
OPERATION
Article 56. Regulation
of real time power system
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2. The generating unit shall comply with the
order of regulation of the electricity system and market operating unit.
3. The generating unit possessing hydropower
plant must comply with regulations on the weekly limited water level specified
in Article 37 of this Circular. In case the reservoir of hydropower plant
violates the weekly limited water level:
a) The electricity system and market
operating unit shall warn the violation of the weekly limited water level of
the plant which must adjust the offering price in the subsequent days to ensure
no violation of the next weekly limited water level.
b) In case the reservoir of the plant
violates the weekly limited water level for 02 consecutive weeks, the plant
shall not make price offering itself and the electricity system and market
operating unit is allowed to interfere into the mobilization schedule. These
power plants shall base on the result of calculation of water value to ensure
requirements on power system security and bring the water level of the
reservoir to the weekly limited water level.
In case the water level of the reservoir is
completely violated due to mobilization on the basis of price quotation of the
plant, not due to mobilization to ensure requirements on power system security,
then during the time of interference, these plants are paid only with a price
equal to 90% of power sale and purchase contract price but no more than 02
weeks from the time of interference.
c) After 02 weeks from the time the electricity
system and market operating unit made interference, the water level of reservoir
still violates the weekly limited water level due to hydrological conditions or
plant mobilization to ensure requirements on power system security, the
electricity system and market operating unit is allowed to further interfere
into mobilization schedule of power plants. During this time, the power plant
is paid at the power sale and purchase contract price.
d) When ensuring no violation of weekly
limited water level, the hydropower plant may continue participation in price
offering in the subsequent week;
e) Before 10h00 on Monday, the electricity
system and market operating unit shall make report on mobilization schedule
since Tuesday to the generating unit and the unique wholesaling unit in the
following cases:
- The plant violates water level of reservoir
and the plant is interfered with mobilization schedule;
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Article 57. Interference
in electricity market
1. Cases of interference in electricity
market
The electricity system and market operating
unit is allowed to interfere into the electricity market in the following
cases:
a) The system is being operated in emergency
mode specified in the Regulation on transmission power system;
b) The hour-ahead mobilization schedule
cannot be put off 15 minutes prior to operation hour.
2. In case of interference in the electricity
market, the electricity system and market operating unit shall mobilize the
sets to ensure the objectives in the order of priority as follows:
a) Ensuring balance of generation and
subloading capacity;
b) Meeting requirements on backup;
c) Meeting requirements on rotation backup;
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3. Publication of information on interference
in electricity market.
a) Upon interference in electricity market,
the electricity system and market operating unit must publish the following
contents:
- Reasons for interference in electricity
market;
- Transation cycles expectedly interfering in
the electricity market.
b) Within 24 hours after the end of
interference in the electricity market, the electricity system and market
operating unit shall publish the following contents:
- Reasons for interference in electricity
market;
- Transation cycles expectedly interfering in
the electricity market.
- Measures applied by the electricity system
and market operating unit to interfere in the electricity market.
Article 58. Stoppage
of electricity market
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a) Due to emergency situations of natural
disasters or protection of national defence and security;
b) Due to proposal for stoppage of electricity
market from the electricity system and market operating unit in case:
- Power system operates in extreme emergence
mode specified in Regulation on transmission electricity system.
- Failing to ensure safe and continuous
operation of electricity market.
c) Other cases on the requirements of the
competent authorities.
2. Department of electricity regulation shall
consider and decide on stoppage of electricity market in cases specified at
Point a anf b, Clause 1 of this Article and notify the electricity system and
market operating unit.
3. The electricity system and market
operating unit shall notify electricity market participants of the decision on
stoppage of electricity market of the Department of electricity regulation.
4. Power system operation during the time of
stoppage of electricity market:
a) The electricity system and market
operating unit shall regulate and operate the power system on the following
principles:
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- Ensuring implementation of agreements on
output in power import and export contracts, power sale and purchase contracts
of BOT power plants and power sale and purchase contracts with the output
commitment of other power plants;
b) Generating units, power transmission units
and other units concerned shall comply with the order of regulation of the
electricity system and market operating unit.
Article 59. Restoration
of electricity market
1. The electricity market shall be restored
its operation when meeting the following conditions:
a) Causes leading to the stoppage of
electricity market have been remedied;
b) The electricity system and market
operating unit has confirmed the ability to re-operate of the electricity market.
2. The Department of electricity regulation
shall consider and decide on restoration of electricity market and notify the
electricity system and market operating unit;
3. The electricity system and market
operating unit shall notify the electricity market participants of the decision
on restoration of electricity market of the Department of electricity
regulation.
Section 4. POWER
EXPORT AND IMPORT IN ELECTRICITY MARKET OPERATION.
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1. Before 10h00 on day D-1, the electricity
system and market operating unit shall publish the expected exported power
output in each transaction cycle of day D.
2..The exported power output is calculated as
subloading at the exporting point and is used to calculate the forecasting of
system subloading in service of day and hour -ahead mobilization schedule.
Article 61. Handling
of imported power in mobilization schedule
1. Before 10h00 on day D-1, the electricity
system and market operating unit shall publish the expected imported power
output in each transaction cycle of day D.
2. The imported power output in mobilization
schedule is calculated as the power to be generated with the diagram published
in advance in day ahead.
Article 62. Payment
for the exported and imported power
The imported power is paid under the power
sale and purchase contract signed between parties.
Chapter VI
CALCULATION
MARKET POWER PRICE AND PAYMENT IN ELECTRICITY MARKET
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Article 63. Supply of
metering data
1. Before 15h00 on day D+1, the power
metering data management unit shall provide the electricity system and market
operating unit and the unique wholesaling unit with the power metering data of
each transaction cycle of day D.
2. Bedore the 8th working day after the end
of payment cycle, the power metering data management unit shall provide the
electricity system and market operating unit with the power metering data in
the payment cycle specified in the Regulation on power metering in a
competitive generation market.
Article 64. Storage
of metering data
The electricity system and market operating
unit is responsible for storage of power metering data and relevant dossier in
a time limit of at least 05 years.
Section 2.
CALCULATION OF MARKET ELECTRICITY PRICE AND PAYMENT CAPACITY
Article 65. Determination
of market power price
1. After transaction day Article, the
electricity system and market operating unit shall schedule the calculation of
market power price for each transaction cycle of day Article in the following
order:
a) Calculating the system subloading in the
transaction cycle by converting the metered output to the terminal of
generating set;
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- Fixedly arranging under the background of
power system subloading diagram the actually generated output of the generating
units of direct transaction of electricity market, imported power, BOT power
plant, testing sets and power plant belonging to industrial park only selling a
portion of its output to the national electricity system, the sets separated
from the electricity market;
- Arranging power ranges in the scheduling
price quotation of generating units of direct transaction.
2. Market power price is equal to the
offering price of the final power range scheduled to meet the rate of system
subloading in the schedule of calculation of market power price. In case the
offering price of the final power range in the schedule of calculation of
market power price is higher than the ceiling price, the market power price is
calculated by the market ceiling price.
3. Before 9h00 on day D+2, the electricity
system and market operating unit shall publish the market power price of each
transaction cycle in day D.
Article 66. Determination
of payment capacity
1. Principles to determine the payment
capacity for each transaction cycle:
a) The sets generating in each cycle in the
market are scheduled to receive the market capacity price for that cycle
excluding low startup sets which have stopped for backup or due to problems
b) The payment capacity of the set is at
least equal to the power output of the set at the terminal of generating set in
the transaction cycle.
c) In case the total capacity of the sets has
the same offering price, equally divide the portion of capacity received with
the market capacity price at that offering range for each set.
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a) Calculating the adjusted subloading in the
transaction cycle by the system subloading adding the following components:
- Capacity of rotation backup for transaction
cycle;
- Capacity of frequency regulation for
transaction cycle;
- Component of incentive capacity and
capacity of added generating sets are calculated by 3% total generation output
of the generating units of direct transaction in electricity market in the
transaction cycle.
b) Performing the capacity schedule by the
method of non-binding schedule to meet the rate of adjusted subloading
determined at Point a of this Clause in the following order:
- Fixedly arranging under the background of
power system subloading diagram the actually generated output of the generating
units of direct transaction of electricity market, imported power, BOT power
plant, testing sets and power plant belonging to industrial park only selling a
portion of its output to the national electricity system, the sets separated
from the electricity market;
- Arranging capacity of frequency regulation,
rotation backup and Incrementally generated capacity of generating sets for the
transaction cycle of the set at a price equal to 0 (zero) / kWh;
- Arranging ranges of capacity in the
scheduling price quotation of the generating units of direct transaction
excluding excluding low startup sets which have stopped for backup or due to
problems.
3. The amount of payment capacity of the set
in the transaction cycle is calculated by the amount of capacity of that set in
the capacity schedule.
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Article 67. Determination
of market power price and payment capacity upon interference in electricity
market.
1. In case the time to interfere in market is
less than 24 hours:
a) The electricity system and market
operating unit shall use the valid price quotation to determine the market
power price as specified in Article 65 and the amount of payment capacity as
specified in Article 66 of this Circular;
b) In case the set has no valid price
quotation, the electricity system and market operating unit shall use the
ceiling price for the portion of hourly contract output and ceiling price of
quotation for the output outside the contract to schedule the calculation of
market power price and capacity schedule for that transaction cycle.
2. In case the time to interfere in the
market is greater or equal to 24 hours, the electricity system and market
operating unit shall not calculate the market power price and payment capacity
for the period the market is interfered.
Section 3. MAKING
PAYMENT TO GENERATING UNIT OF DIRECT TRANSACTION
Article 68. Power
output in service of payment in electricity market
1. The electricity system and market
operating unit shall calculate the components of power output of the power
plant in the transaction cycle in service of payment in the electricity market
including:
a) Power output paid by the offering price
for thermal power plant with the offering price higher than the market ceiling
price (Qbp);
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c) Different power output compared with the
output mobilized by the order of regulation (Qdu);
d) Power output paid at market power price
(Qsmp).
2. Power output paid at offering price for
thermal power plant with the offering price higher than the market ceiling
price in the transaction cycle determined as follows:
a) Determining the sets with the offering
price higher than the market ceiling price scheduled for market price
calculation for transaction cycle i and metering position of that set.
b) Calculating the payment power output at
the offering price at each metering position specified at Point a of this
Clause by the following formula:
if 
if
In which:
i: ith transaction cycle;
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: Payment power output at the offering price at
metering position j in the transaction cycle i (kWh);
: Power output metered at the metering
position j in the transaction cycle i (kWh);
: Power output in proportion to the capacity
amount with the offering price lower than or equal to the market ceiling price
in the transaction cycle i of the sets connected to the metering position j and
converted to that metering position (kWh);
: Power output in proportion to the capacity
amount with the offering price higher than the market ceiling price and
arranged in the schedule of calculation of market price in the transaction
cycle i of the sets connected to the metering position j and converted to that
metering position (kWh);
Calculating the payment power output at the
offering price for the power plant by the following formula:
In which:
j: Metering point j of thermal power plant
specified at point a of this Clause;
J: Total metering points of the power plant
with the set offering higher than the ceiling market price and scheduled for
calculation of market price;
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: Power output paid at offering price at the
metering point j in the transaction cycle i (kWh);
3. The incrementally generated power output
of the power plant in transaction cycle is determined in the following order:
a) Calculating the incrementally generated
power output in the transaction cycle at the terminal of the set by the
following formua:
In which:
: Incrementally generated power output of the
set calculated at the terminal in transaction cycle i (kWh);
i: ith transaction cycle;
J: Number of times to change the order of
regulation due to the binding in transaction cycle i;
: J th point of time in the transaction cycle
i, the electricity system and market operating unit has the order of regulation
to change capacity of generating set due to the binding (minute). In case at
this point of time the capacity of generating set is lower than 
then is determined as the point of time the set
reaches the capacity;
: Point of time the set reaches the capacity
due to receiving order of regulation at the point of time 
(minute) of the electricity system
and market operating unit; In case at this point of time, the capacity of the
generating set is lower than then is determined as the point of time the set
reaches the capacity;
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: Capacity by the order of regulation from
the electricity system and market operating unit to the generating set at the
point of time 
. In
case this capacity is less than , then this capacity is calculated by;
: Capacity the set reaches at the point of
time . In case this
capacity is less than
then this capacity is calculated by ;
The period from the point of time the order
of regulation capacity
to point of time 
the generating set
reaches capacity 
is
determined as follows:
a: Speed of load increase or decrease of the
set registered in the scheduling price quotation (MW/minute).
b) Determining the incrementally generated
power output in the transaction cycle of the set 
, by converting the output 
from the terminal position of the
set to the metering position.
c) Calculating the incrementally generated
power output of the power plant in the transaction cycle i by the following
formula:
In which:
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g: Added generating set of the power plant in
the transaction cycle i;
G: Total added generating sets of the power
plant in the transaction cycle i;
: Increased output of the set g in the
transaction cycle i (kWh).
4. Different power output compared with the
output mobilized by the order of regulation (Qdu) of the power plant in the
transaction cycle determined in the following order;
a) Determinating output mobilized by the
order of regulation.
The output mobilized by the order of
regulation of generating unit is the output at the terminal of the generating
set calculated based on the order of regulation to mobilize the set of the
electricity system and market operating unit based on the capacity by the order
of regulation and the speed of load increase and decrease of the generating
set. The output mobilized by the order of mobilization is determined by the
following formula:
In which:
i: Transaction cycle i;
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: J th point of time in the transaction cycle
i, the electricity system and market operating unit has the order of regulation
to change capacity of generating set (minute);
: Point of time the set reaches the capacity
due to receiving order of regulation at the point of time (minute) of the electricity system
and market operating unit;
: Output mobilized by the order of regulation
calculated at the terminal of the generating set determined for transaction cycle
i;
: Capacity by the order of regulation from
the electricity system and market operating unit to the generating set at the
point of time .
: Capacity the set reaches at the point of
time .
The period from the point of time the order
of regulation capacity
to point of time the generating set
reaches capacity is
determined as follows:
a: Speed of load increase and decrease of the
set registered in the scheduling price quotation lịch (MW/minute);
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c) Different power output compared with the
output mobilized by the order of regulation determined by the following
formula:
In which:
: Different power output compared with the
output mobilized by the order of regulation calculated at the terminal of the
generating set determined for transaction cycle i;
: Metered power output of the power plant in
the transaction cycle i (kWh);
: Output mobilized by the order of regulation
converted to the metering position for transaction cycle i.
d) In case the set during the startup or
stopping, this output Qdu is equal to zero
(Qdui = 0). If this set has technical binding
affecting the generation capacity of the other sets of the plant, these
affected sets shall not calculate the output Qdu
(Qdui = 0).
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5. Power output paid at the market power
price of the power plant in the transaction cycle i determined by the following
formula:
In case the different power output compared
to the output mobilized by the positive order of regulation (
> 0):
In case the different power output compared
to the output mobilized by the negative order of regulation (< 0):
In which:
: Power output paid at market power price of
the power plant in the transaction cycle i (kWh);
: Metered power output of the power plant in
the transaction cycle i (kWh);
: Power output paid at the offering price in
the transaction cycle i for thermal power plant having offering price higher
than the market ceiling price (kWh);
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: Different power output compared to the
output mobilized by the order of regulation in the transaction cycle i.
Article 69. Adjustment
of power output in service of payment in electricity market.
1. The electricity system and market
operating unit shall calculate and re-adjust the components of power output in
service of payment in the market in transaction cycles specified in Clause 1,
Article 68 of this Circular based on the output components as follows:
a) Power output of hourly contract of power
plant in the transaction cycle i() is determined as specified in Article 36 of
this Circular.
b) Power output paid at the market power
price (Qsmpi) of the power plant in the transaction cycle i determined as
specified in Clause 5, Article 68 of this Circular;
c) Metered power output of the power plant in
the transaction cycle i().
2. The components of power output in service
of payment in the market are adjusted in the following cases:
a) In case in the transaction cycle i, the
metered power output of the power plant is less than or equal to the power
output of hourly contract (≤ );
b) In case in the transaction cycle i, the
metered power output of the power plant is greater than the power output of
hourly contract (>
) and the power
output paid at the market power price of the power plant is less than the
hourly contract output (< ).
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a) In case specified at Point a, Clause 2 of
this Article, the incrementally generated power output (Qconi) and the power
output paid at the offering price for the plant having offering price higher
than the market ceiling price (Qbpi) adjusted in this transaction cycle is zero
(Qconi = 0; Qbpi = 0);
b) In case specified at Point a, Clause 2 of
this Article, the power output in service of payment in electricity market is
adjusted on the principle to ensure no change of metered power output in this
transaction cycle and under regulation in the process of mobilization schedule
of generating sets, real time operation and payment calculation in electricity market.
Article 70. Payment
of market power
1. The electricity system and market
operating unit shall calculate the total of payments of market power of the
power plant in the payment cycle by the following formula:
In which:
Rg: Total of payments of market power in the
payment cycle (dong);
Rsmp: Payment for the portion of output to be
paid at market power price in the payment cycle (dong);
Rbp: Payment for the output to be paid at the
offering price for thermal power plants having offering price higher than the
market ceiling price in the payment cycle (dong);
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Rdu: Payment for the different power output
compared with the output mobilized by the order of regulation in the payment
cycle (dong);
2. Payment for the output to be paid at the
market power price of the power plant in the payment cycle determined by the
following order:
a) Calculating each transaction cycle by the
following formula:
In which:
: Payment for the output to be paid at the
market power price of the power plant in the payment cycle i in the payment
cycle (dong);
SMPi : Market power price of
transaction cycle i in the payment cycle (dong/kWh);
: Power output paid at the market power price
of the transaction cycle i in the payment cycle (kWh);
b) Calculating the payment cycle by the
following formula:
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In which:
: Payment for the output to be paid at the
market power price of the power plant in the payment cycle (dong);
i: Ith transaction cycle in the payment cycle;
I: Total transaction cycles of the payment
cycle;
: Payment for the output to be paid at the
market power price of the power plant in the payment cycle i in the payment
cycle (dong);
3. Payment for the output to be paid at the
offering price for thermal power plant having the offering price higher than
the market ceiling price in the payment cycle determined by the following
order:
a) Calculating each transaction cycle by the
following formula:
In which:
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j: Jth offering range in the price offering
of the sets of the thermal power plant having the offering price higher than
the market ceiling price and arranged in the schedule of calculation of market
power price.
J: Total offering ranges in the price
quotation of the thermal power plant having the offering price higher than the
market ceiling price and arranged in the schedule of calculation of market
power price.
: Offering price in proportion to the offering
range j in the quotation of the sets of the thermal power plant g in
transaction cycle i (dong/kWh);
: The highest rate of offering in the ranges
arranged in the schedule of calculation of market power price of thermal power
plant in the transaction cycle i (dong/kWh);
: Total capacity offered at a price in the quotation of
thermal power plant mobilized in transaction cycle i and converted to the
metering position (kWh);
: Total power output having offering price
higher than market ceiling price of thermal power plant in transaction cycle i
(kWh).
b) Calculating each payment cycle by the
following formula:
In which:
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i: Transaction cycle i in which the power
plant is mobilized at the offering price higher than ceiling price;
I: Total transaction cycles in which the
power plant is mobilized at the offering price higher than ceiling price;
: Payment for the power offered higher than
the ceiling price of the power plant in the transaction cycle i (dong);
4. Payment for incrementally generated power
output of the power plant in the transaction cycle determined by the following
order:
Calculating each transaction cycle by the
following formula:
In which:
: Payment for incrementally generated power
output in the transaction cycle i (dong);
g: Added generating sets of power plant in
the transaction cycle i;
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: Incrementally generated power of the set g
in the transaction cycle i (kWh);
: Highest offering price in proportion to the
incrementally generated capacity range of the set g in the transaction cycle i
(dong/kWh).
Calculating each payment cycle by the
following formula:
In which:
Rcon: Payment for the incrementally generated
power output in the payment cycle (dong);
i:ith transaction cycle of the payment cycle
in which the thermal power plant must increase generation by the order of
regulation;
I: Total transaction cycles of the payment
cycle in which the thermal power plant must increase generation by the order of
regulation;
Rconi : Payment for the incrementally
generated power output in the transaction cycle i (dong).
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6. Payment for the different power output compared
with the output mobilized by the order of regulation of the power plant in the
transaction cycle.
Calculating each transaction cycle by the
following formula:
In case the power output incrementally
generated compared with the order of regulation:
In which:
: Payment for the different power output
compared with the order of regulation in the transaction cycle i (dong);
g: Added generating set compared with the
order of regulation of the power plant in the transaction cycle i.
G: Total added generating set compared with
the order of regulation of the power plant in the transaction cycle i;
: Incrementally generated power compared with
the order of regulation of the set g in the transaction cycle i;
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In case the generated power output decreases
compared with the order of regulation:
In which:
: Payment for the different power output
compared with the order of regulation in the transaction cycle i (dong);
g: Generating set reduced compared with the
order of regulation in the transaction cycle i;
G: Total generating set reduced compared with
the order of regulation in the transaction cycle i;
: Generated power output decreases compared
with the order of regulation of the set g in the transaction cycle i(kWh);
SMPi : Market power price in the transaction
cycle i (dong/kWh);
Pbpi,max: Offering price of the most
expensive set paid in the transaction cycle i.
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In which:
: Payment for the different power output
compared with the order or regulation in the payment cycle (dong);
i: ith transaction cycle of the payment cycle
in which the thermal power plant of different generation compared with the
order of regulation;
I: Total transaction cycles of the payment
cycle in which the thermal power plant of different generation compared with
the order of regulation;
: Payment for the different power output
compared with the output mobilized by the order of regulation in the
transaction cycle i (dong)
Article 71. Payment
of market capacity
The electricity system and market operating
unit shall calculate the payment of market capacity for the power plant in the
payment cycle in the order as follows:
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In which:
: Payment of capacity to the power plant in
the transaction cycle i (dong);
g: Set of power plant is paid at capacity
price.
G: Total sets of the power plant are paid at
capacity price.
: Market capacity price in the transaction
cycle i (dong/kW)
: Amount of payment capacity of the set g in
the transaction cycle i (kW)
2. Calculating each payment cycle by the
following formula:
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Rcan: Payment of capacity to the power plant
in the payment cycle (dong);
i: ith transaction cycle in the payment cycle;
I: Total transaction cycles in the payment
cycle;
Rcani : Payment of capacity to the power
plant in the transaction cycle i (dong).
Article 72. Payment
under power sale and purchase contract for difference
Based on the market power price and market
capacity price published by the electricity system and market operating unit,
the generating unit shall calculate the payment under the power sale and
purchase contract for difference in the payment cycle in the order as follows:
Calculating each transaction cycle by the
following formula:
In which:
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: Power output paid under contract price in
the transaction cycle i (kWh);
Pc: Difference power sale and purchase
contract price (dong/kWh). For hydropower plants, this contract price excludes
water resource tax and fees of forestry environment;
SMPi: Market power price in
transaction cycle i (dong/kWh);
CANi: Market capacity price in
transaction cycle i (dong/kWh);
Calculating each payment cycle by the
following formula:
In which:
Rc: Difference payment in the payment cycle
(dong);
i: ith transaction cycle of the payment cycle;
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: Difference payment in the transaction cycle
i (dong).
Article 73. Payment
made upon interference in electricity market
1. In case the market interference time is
less than 24 hours, the generating unit receives the payments specified in
Article 69, 71 and 72 at the market power price and amount of payment capacity
specified in Article 67 of this Circular.
2. In case the market interference time is
greater than or equal to 24 hours, the generating unit is paid under contract
price for the entire metered power output
Article 74. Payment
made upon stoppage of electricity market
During the time of stoppage of electricity
market, the generating unit is paid under contract price for entire metered
power output.
Section 4. PAYMENT OF
AUXILIARY SERVICES AND OTHER PAYMENTS
Article 75. Payment of
opportunity cost for rotation backup service
1. The electricity system and market
operating unit shall calculate the payment of opportunity cost for the
generating unit providing the rotation backup service in the payment cycle in
the order as follows:
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In which:
Rspni : Payment of opportunity cost for the
generating unit in the transaction cycle i (dong);
g: Set providing rotation backup service of
the generating unit in the transaction cycle i;
G: Total sets providing rotation backup
service of the generating unit in the transaction cycle i;
: Scheduling capacity providing rotation
backup service of the set g in the transaction cycle i according to hour-ahead
mobilization schedule (kWh);
: Opportunity cost in the transaction cycle i
of the set g (dong/kWh). The opportunity cost is calculated as follows
In which:
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: Highest offering price among rates of offering
price in proportion to capacity ranges providing the rotation backup service
(dong/kWh).
b) Calculating each payment cycle by the
following formula:
In which:
: Payment of opportunity cost in the payment
cycle (dong);
i: ith transaction cycle in the payment cycle
in which the generating unit provides the rotation backup;
I: Total transaction cycles in the payment
cycle in which the generating unit provides the rotation backup;
Rspni :Payment of opportunity cost
in the transaction cycle i (dong).
2. Opportunity cost only paid for
thermoelectric sets providing the rotation backup;
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The Units providing quick startup backup
service, cold backup service, operational services to be generated due to
security binding of electricity system shall be paid under auxiliary service
supply contract signed between the electricity system and market operating unit
and the generating unit under the form issued by the Ministry of Industry and
Trade.
Article 77. Payment
for multi-objective strategic hydropower plant
Payment for multi-objective strategic
hydropower plant is made under under the power sale and purchase contract
signed with the unique wholesaling unit.
Article 78. Payment
for hydropower plants with regulating reservoir of less than 02 days.
The electricity system and market operating
unit shall calculate the payment of revenue for plants with regulating
reservoir of less than 02 days by the following formula:
a) Calculating each transaction cycle by the
following formula:
Rgi = Pc × (Qhci × α)
+ (CANi + SMPi) × (Qhci ×(1 - α)) + Rdui
In which:
Rgi: Payment for plants with regulating
reservoir of less than 02 days in the transaction cycle i (dong);
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Qhci : Adjusted power output in the
transaction cycle i(kWh) is determined as follows:
- In case Qdui > 0, Qhci = Qmi - Qdui;
- In case Qdui ≤ 0, Qhci = Qmi.
Qmi: Power output at the point of delivery in
the transaction cycle i (kWh);
Qdui: Different power output compared with the
order of regulation (kWh) in the transaction cycle i.
Rdui: Payment made for the different power
output compared with the output mobilized by the order of regulation in the
transaction cycle i.
SMPi: Market power price in the transaction
cycle i (dong/kWh);
CANi: Market capacity price in the
transaction cycle i (dong/kWh);
α: Rate of power output paid under contract
price for hydropower plants published by the Department of electricity
regulation
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In which:
: Payment made for the plant with regulating
reservoir of less than 02 days (dong);
i: ith transaction cycle of the payment cycle;
I: Total transaction cycles of the payment
cycle;
Rgi : Payment made for the plant with
regulating reservoir of less than 02 days in the transaction cycle i (dong);
Article 79. Other
payments
1. The generating unit which has generating
set or receives reactive capacity in the mode of synchronous compensation
running is paid for the amount of active power received from the grid as
specified in the power sale and purchase contract.
2. The thermalelectric set forced to be
stopped as specified at Point d, Clause 3, d 54 of this Circular is paid with
the startup cost at the rate of cost agreed between the unique wholesaling unit
and generating unit. The electricity system and market operating unit shall
publish the sets in this case.
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4. In case the gas turbine thermoelectric
sets have the same steam tail with the single cycle operation time, operated
with mixed fuel or not the main fuel on the requirement of the electricity
system and market operating unit to ensure electricity system security, the
payment for those transaction cycles shall not be implemented as specified in
section 3, Chapter VI of this Circular. The payment for the gas turbine plant
in this cycle is made at the power price in the power sale and purchase contract
signed with the unique wholesaling unit in proportion to the set configure upon
single cycle operation, operation with mixed fuel or not with main fuel.
5. In case the power plant has generating set
separated from the national power system and connected to the grid purchased
from foreign country, the entire generation output of the power plant in the
transaction day shall be paid under the power sale and purchase contract price.
6. In case the set must reduce its capacity
but the cause is not due to the fault of the plant which does not ensure the
hourly contract output, the hourly contract output applicable to the payment in
the electricity market of the plant is adjusted by the actually generated
output of the plant in that transaction cycle. In case the set has to re-start
up and then is paid its startup cost at the rate of cost agreed between the
unique wholesaling unit and generating unit.
7. In case the plant has a testing generating
set.
a) In case the testing set has technical
binding and affects the generation capacity of the other sets of the plant
during the testing process, the entire plant shall be separated from the
electricity market in the testing running. All generation output of the plant
to the grid in the testing cycles shall be paid as prescribed in the power sale
and purchase contract signed with the unique wholesaling unit in proportion to
the set configure and type of fuel used.
b) In case the testing set does not have
technical binding and affects the generation capacity of the other sets of the
plant during the testing process, that testing set shall be separated from the
electricity market. All generation output of the testing set to the grid in the
testing cycles shall be paid as prescribed in the power sale and purchase
contract signed with the unique wholesaling unit in proportion to the set
configure and type of fuel used. The other sets still participate in the
electricity market and are paid as specified in section 3, Chapter VI of this
Circular.
8. In case the gas turbine power plant must
stop and re-start up as required by the power system during the time the set operates
the single cycle with the mixed fuel or not with main fuel, the plant shall be
paid with this startup cost as agreed between the generating unit and the
unique wholesaling unit.
9. In case the set has a stoppage plan which
has been approved but has to generate capacity as required by the electricity
system and market operating unit to ensure the power system security, that
entire plant shall be separated from the electricity market during the time of
capacity generation as required by the electricity system and market operating
unit. All generation output of the plant to the grid during this time shall be
paid at the price in the power sale and purchase contract signed with the
unique wholesaling unit.
Section 5. PAYMENT
ORDER AND PROCEDURE
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Before 9h00 on day D+2, the electricity
system and market operating unit shall review and provide the unique
wholesaling unit and generating units with the data in service of the
calculation of payment to each power plant specified in Appendix VI of this
Circular.
Article 81. Payment list
of electricity market for transaction day
1. Before day D+4, the electricity system and
market operating unit shall prepare and send the unique wholesaling unit and
generating units the preliminary payment list of electricity market payment for
that transaction day under the form specified in Appendix IV of this Circular.
2. Before day D+6, the generating unit of
direct transaction and the unique wholesaling unit shall certify the payment list
of electricity market specified on the website of electricity market and notify
the electricity system and market operating unit of the mistakes in the
preliminary payment list of electricity market (if any).
3. On day D+6, the electricity system and
market operating unit shall prepare and send the completed list of electricity
market payment for day D to the unique wholesaling unit and generating units.
Article 82. Payment list
of electricity market for the payment cycle.
1. The electricity system and market
operating unit shall review payment data for all transaction days in the
payment cycle and check and compare with the record of power output review
provided by the power metering data management unit.
2. Within 10 working days after the last
transaction day of the payment cycle, the electricity system and market
operating unit shall prepare and issue the payment list of power market for the
payment cycle.
3. The payment list of power market for the
payment cycle includes the list of payment for each transaction day and the
summary under the form specified in the Appendix V of this Circular and the
written certification of meter index and power output.
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1. The generating unit of direct transaction shall
prepare and send the payment voucher of electricty market to the unique
wholesaling unit based on the payment list of electricity market for the payment
cycle.
2. The generating unit shall prepare and send
payment voucher of contract to the unique wholesaling unit as prescribed in the
power sale and purchase contract signed between the unique wholesaling unit and
the generating unit.
3. Before the 20th day of each month, the
generating unit shall prepare and send payment voucher to the unique
wholesaling unit. The payment voucher includes the payments of electricity
market and contract payment in the payment cycle.
Article 84. Payment
dossier for auxiliary service supply contract
The generating unit shall prepare the payment
dossier of auxiliary service under the auxiliary service supply contract between
the generating unit and the electricity system and market operating unit;
Article 85. Adjustment
of voucher
1. In case there are errors on the voucher,
the generating unit or the unique wholesaling unit has the right to request the
adjustment of the voucher within 01 month from the date of issuance. The
parties concerned shall coordinate to determine and agree on the adjusted
payments.
2. The generating unit shall supplement the
adjusted payment in the voucher of the subsequent payment cycle.
Article 86. Payment
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2. The generating unit and the unique
wholesaling unit shall make agreement on the payment method in the electricity
market in accordance with the provisions in this Circular and the relevant
regulations;
3. In case the payment is due but the
electricity system and market operating unit has not issued the monthly payment
list, the unique wholesaling unit and the generating unit shall temporarily
make payment for the entire output actually generated in the payment cycle at
the price of the power sale and purchase contract signed between the two
parties and finalize the difference of electricity bill in the subsequent
months.
Article 87. Handling
errors in payment
In case of excessive or inadequate payment
compared with the voucher, the units concerned shall handle these errors as
prescribed in the power sale and purchase contract or auxiliary service supply
contract.
Chapter VII
SOFTWARE
FOR OPERATION OF ELECTRICITY MARKET
Article 88. Software
for operation of electricity market
1. Software for operation of electricity
market includes:
a) Market simulation model;
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c) Mobilization scheduling software and
regulation;
d) Software in service of calculation of
payment;
e) Other softwares in service of market
operation
2. The electricity system and market
operating unit shal develop and operate softwares in service of electricity
market .
Article 89. Requirements
on the software for operation of electricity market
1. Ensuring the precision, reliability,
security, and meeting the standards set by the electricity system and market
operating unit.
2. Having attached technical guidelines and
operating procedures
Article 90. Development
of softwares for the operation of the electricity market
1. The softwares for market operation must be
developed to support the implementation of calculation and transaction specified
in this Circular and operational process of electricity market.
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a) Building standards for the softwares for
the operation of electricity market.
b) Appraising and checking the response ability
of the software for standards specified at Point a of this Clause before
application;
c) Publishing list and algorithms and process
using software for the operation of the electricity market.
Article 91. Software
auditing
1. The softwares serving the market must be
audited in the following cases:
a) Before the power market is officially put
into operation;
b) Before the new softwares are put into use;
c) After adjustment and upgrade affecting the
calculation;
d) Periodical audit
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3. The electricity system and market
operating unit shall publish the auditing result to the electricity market
participants.
Chapter VIII
ELECTRICITY
MARKET INFORMATION SYSTEM AND REGULATION ON INFORMATION PUBLICATION
Section 1. ELECTRICITY
MARKET INFORMATION SYSTEM
Article 92. Structure
of electricity market information system
The electricity market information system
includes the following basic components:
1. Software and hardware system in service of
management and exchange of electricity market information.
2. System of database and storage
3. Electronic portal for electricity market,
including the internal website and public website.
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1. The electricity system and market
operating unit shall build, manage and operate the electricity market
information system.
2. The electricity market participants shall
invest in equipment in the scope of management to meet technical requirements
regulated by the electricity system and market operating unit to ensure the
connection to the electricity market information system.
3. The power metering data management unit
shall develop, manage and operate the transmission network connecting between
the electricity market information system of the electricity system and market
operating unit and equipment of the electricity market participants.
4. The electricity system and market
operating unit only operates or changes the current electricity market
information system after complete acceptance and is approved by the Department
of electricity regulation.
The electricity system and market operating
unit shall be equipped with backup equipment for the electricity market
information system to ensure the collection, transmission and publication of
the main market information in case the electricity market information system
has problems or can not be operated.
Section 2. MANAGEMENT
AND PUBLICATION OF ELECTRICITY MARKET INFORMATION
Article 94. Supply
and publication of electricity market information
1. The generating unit, the unique
wholesaling unit, the power transmission unit and the power metering data
management unit shall provide the electricity system and market operating unit
with information, data in service of operation planning mobilization schedule
and calculation of payment specified in this Circular through electronic portal
of electricity market information system.
2. The electricity system and market
operating unit shall supply and publish information, data and reports on
electricity market operation to the electricity market participants specified
in this Circular through electronic portal of electricity market information
system.
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4. The electricity system and market
operating unit shall publish on the public websites the following information:
a) Information about the electricity market
participants;
b) Data of system subloading;
c) Statistical data on the market price;
d) Other information specified in the Process
of management and operation of information technology systems of electricity
market operation and publication of electricity market.
Article 95. Responsibilities
for assurance of accuracy of electricity market information
1. The market participants shall ensure the
accuracy and completeness of the electricity market information at the time of
supply.
2. In case the information supplied and
published is not correct and complete, the market participants shall correct
and provide correct information again to the unit concerned.
Article 96. Security
of electricity market information
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a) Information on power sale and purchase
contract;
b) Quotation price of the generating unit
before the end of transaction day;
c) Other information beyond the competence
2. The electricity market participants must
not disclose information beyond the scope of authorization of supply and
publication.
Article 97. Cases of
exemption from information security
1. Supply of information as required by the
Department of electricity regulation or competent agency as prescribed by law.
2. Information summarized and analyzed from
information published on electricity market, not by electricity market
participants not in accordance with Article 96 of this Circular.
Article 98. Storage
of electricity market information
The electricity system and market operating
unit is responsible for storing all activities of information exchange through
the electricity market information system. The duration for information storage
is at least 05 years.
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Article 99. Publication
of information on electricity market operation
The electricity system and market operating
unit shall periodically prepare and publish information on electricity market
operation specified in the Process of electricity market information system
operation as follows:
1. Before 15h00 daily, preparing and
publishing report on electricity market operation of the previous day.
2. Before Tuesday weekly, preparing and
publishing report on electricity market operation of the previous week.
3. Before the 10th date monthly, preparing
and publishing report on electricity market operation of the previous month.
4. Before the January 31st date annually,
preparing and publishing report on electricity market operation of the previous
year.
Article 100. Regime
of report on electricity market operation.
1. Before the 10th date monthly, the
electricity system and market operating unit shall send the Department of
electricity regulation a report on electricity system and market operation of
the previous month under the form specified by Department of electricity
regulation.
2. Before the October 31st date annually, the
electricity system and market operating unit shall send the Department of
electricity regulation a report on electricity system and market operation of
the previous year under the form specified by Department of electricity
regulation.
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4. The electricity system and market
operating unit shall make an irregular report on the electricity maket and
system operation as required by the Department of electricity regulation.
Article 101. Data
audit and compliance in electricity market
1. Periodic audit
Before March 31st date annually, the
electricity system and market operating unit shall organize the implementation
and completion of data audit and compliance in electricity market of the
previous year. The content of annual audit includes:
a) Data audit, process of calculation of the
electricity system and market operating unit in the electricity market,
including:
- Data for the process of calculation in the
electricity market;
- Step of calculation;
- Result of calculation.
b) Compliance audit of the electricity system
and market operating unit for the order and procedures specified in this
Circular.
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The Department of electricity regulation has
the right to require the electricity system and market operating unit to
implement the irregular audit according to the contents and scope of audit
specifically in the following cases:
a) Upon detection of abnormal signs in
electricity market operation;
b) At the request of the electricity market
participants. The order of implementation is as follows:
- The electricity market participants shall
send written request to the Department of electricity regulation specifying the
content and reason for auditing request.
- Within 30 days after receiving the written
request, the Department of electricity regulation shall consider and have
written approval or disapproval for the auditing request specifying the
contents and scope of audit or reason for disapproval.
3. The electricity system and market
operating unit shall recommend a qualified independent audit unit to implement
contents of electricity market audit for submission to the Departmen of
electricity regulationfor approval.
4. Electricity market participants shall
fully coordinate during electricity market audit
5. Audit cost
a) To be paid by the electricity system and
market operating unit in cases of audit specified in Clause 1 and Point a,
Clause 2 of this Article.
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6. Within 10 days after the end of audit, the
electricity system and market operating unit shall send report on audit to the
Department of electricity regulation and units concerned.
Chapter IX
SETTLEMENT
OF DISPUTE AND HANDLING OF VIOLATION
Section 1. SETTLEMENT
OF DISPUTE
Article 102. Order to
settle disputes in electricity market.
1. Disputes arising in electricity market
shall be settled by Regulation on order, procedures for settlement of dispute
in electricity market.
2. Before settlement of dispute specified in
Clause 1 of this Article, the parties shall negotiate to settle disputes by
themselves within 60 days in one of the following forms:
a) Negotiation;
b) Reconciliation through intermediary. The
parties may invite qualified experts or request the Department of Eelectricity
regulation to appoint officials for reconciliation.
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1. Making agreement on the form of settlement
of dispute by themselves, the time and location for negotiation.
2. Providing complete, honest, correct and
necessary information and documents related to the content of dispute.
3. Giving legitimate evidence to protect the
lawful rights and interests.
4. Participating in negotiation with the
spirit of goodwill and cooperation.
5. During settlement of dispute, if detecting
the dispute with violation signs of regulation on electricity market, the
detecting party shall notify the other party to stop the self settlement of
dispute and make report to the Department of electricity regulation.
Article 104. Notification
of dispute and preparation for negotiation
1. When dispute arises, the requesting party
shall notify in writing to the requested party of disputes and require
settlement of that dispute and send 01 (one) copy to the Department of electricity
regulation for report.
2. Within 15 days after receipt of
notification, the parties shall make agreement on the form of settlement of
dispute, the contents to be settled, the time and location of negotiation. In
case of choosing the form of reconciliation through intermediary, the parties
shall agree on selection of intermediary for reconciliation. The parties have
the right to change the intermediary before the expected time of reconciliation
agreed.
Article 105. Organization
of self settlement of dispute
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The parties shall exchange and make agreement
on the contents needing settlement.
2. Reconciliation
a) The parties shall select intermediary and
agree upon the intermediary’s responsibilities.
b) The parties shall provide the intermediary
with the contents of dispute, information and documents related to the dispute
and requirement on settlement of each party;
c) The parties may agree upon the
intermediary’s settlement; require the intermediary to modify and supplement
the settlement or make agreement by themselves for a new settlement.
Article 106. Record
of self settlement of dispute
1. After the end of self settlement of
dispute or the expiration of self settlement of dispute, the parties shall make
record of self settlement of dispute including the following contents:
a) Time and location of settlement of dispute;
b) Name and address of the parties involved
in settlement of dispute;
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d) Requesting contents of the parties;
dd) Contents agreed upon by the parties;
e) Contents not agreed upon by the parties
and the reason for that.
2. Within 05 days after the record is made,
the parties shall send 01 (one) copy to the Department of electricity
regulation for report.
Article 107. Settlement
of dispute at the Department of electricity regulation
1. The parties have the right to submit the
case to the Department of electricity regulation for settlement of dispute in
the following cases:
a) Upon expiration of self settlement of
dispute specified in Clause 2, Article 102 of this Circular but the dispute is
not successfully settled or the dispute cannot be settled due to the absence of
one party in the self settlement of dispute.
b) One party does not implement the contents
agreed upon in the Record of self settlement of dispute.
2. After receiving valid dossier for
settlement of dispute as prescribed, the Department of electricity regulation
shall settle dispute in the order and procedures prescribed in Regulation on
order, procedures for settlement of dispute in electricity market.
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Article 108. Violation
detection and report
1. The acts of violation in the electricity
market if detected must be reported in writing to the Department of electricity
regulation.
2. Content of report on acts of violation:
a) Date, month and year of report;
b) Name, address of organization and
individual that makes report;
c) Name, address of organization and
individual that carries out acts with signs of violation;
d) Description of acts with signs of
violation;
dd) Time, location of acts with signs of
violation;
e) Reason for knowing the acts with signs of
violation;
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1. Within 05 days after the receipt of the
case concerning acts with signs of violation, the Department of electricity regulation
shall handle the case and must notify in writing in case of non-handling.
2. After handling of the case, the Department
of electricity regulation shall investigate acts with signs of violation.
During the investigation, the Department of electricity regulation has the
right:
a) To require the unit with signs of violation
and the units concerned to provide necessary information and documents in
service of investigation.
b) To require the unit with signs of
violation to make report;
c) To ask for appraisal and gather opinions
from experts or agencies and units concerned.
d) To summon the unit with signs of violation
and the units affected by acts of violation to gather opinions about the
solution and remedy of acts of violation.
3. During investigation, the Department of
electricity regulation shall maintain confifentiality of information and
documents provided in accordance with the provision on information security in
this Circular.
Article 110. Making
record of legal violation
1. Within 30 working days from the day of
investigation, the Department of electricity regulation shall end the
investigation and make record of legal violation for acts of violation of
regulation on electricity market operation. If the case has many complex
details, the duration of investigation can be prolonged but not exceeding 45
working days from the day of investigation.
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In case the result of investigation shows
that the acts reported did not violate the regulation on electricity market operation,
the Department of electricity regulation shall stop the investigation and
notify the organization and individual making report.
Article 111. Forms of
violation sanction
1. The violating unit must bear one of the
form and degree of sanction for each act of violation in accordance with
regulation on sanction of legal violation in the electricity area.
2. For the power plant having acts of
violation specified in Clause 1, Article 8 of this Circualr, in addition to be
sanctioned as prescribed in Clause 1 of this Article, the right to participate
in electricity market shall be suspended.
Article 112. Order
and procedures for suspension of the right to participate in electricity market
1. In case the power plant has acts of
violation specified in Clause 1, Article 8 of this Circular, within 05 working
days after the Record of legal violation is made, the Department of electricity
regulation shall consider and make a decision on suspension of the right to
participate in electricity market of the power plant which has acts of
violation and and send it to the vioating plant and the electricity system and
market operating unit.
2. Within 01 day after the receipt of
Decision on suspension of the right to participate in electricity market, the
electricity system and market operating unit shall publish the suspension for
the violating plant.
3. Upon expiration as specified in Clause 2,
Article 111 of this Circular, if the plant has not remedied its violation, the
Department of electricity regulation shall has the right to extend the
suspension.
Chapter X
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Article 113. Implementation
organization
1. Department of electricity regulation shall:
a) Disseminating, inspecting and monitoring
the implementation of this Circular;
b) Make guidance or request the Ministerial
leadership to guide the implementation arising or problems in the
implementation of this Circular.
2. Vietnam Electricty Group shall direct the
electricity system and market operating unit and the units concerned:
a) To review and adjust the technical
processes for submission to the Department of electricity regulation for
promulgation within 01 month from the effective day of this Circular,
including:
- Process of week, month and year-ahead
operation plan;
- Process of selection of the best new plant
and calculation of market capacity price;
- Process of electricity market simulation;
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- Process of classification of set and
calculation of ceiling price of quotation of the thermal power plant;
- Process of schedule mobilizing the
generating sets, the real time operation and calculation of payment in the
electricity market.
- Process of management and operation of
information technology systems of electricity market operation and publication
of electricity market.
b) To develop technical processes for
submission to the Department of electricity regulation for issuance within 02
months from the effective day of this Circular, including:
- Process of comparison of payment data between
the electricity system and market operating unit, the generating units and the
unique wholesaling unit.
- Process of calculation of the limited water
level of hydroelectric reservoir and the security power of hydropower plant;
- Process of electricity market participation
registration;
- Process of optimizing the use of gas fuel
resource in service of day-ahead mobilization schedule.
- Process of coordination to certify events
in service of payment in the electricity market.
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3. The unit participating in electricity
market shall complete equipment and information in accordance with the
electricity market information system specified in this Circular.
4. The unit participating in electricity
market shall sign power sale and purchase contract under the form issued by the
Ministry of Industry and Trade for the electricity market.
5. In the course of implementation of this Circular,
if there is any problem, new content arising, the units concerned shall make a
report to the Department of electricity regulation for study, proposal and
submission to the Ministry of Industry and Trade for amendment and
supplementation of this Circular accordingly. The units concerned shall
implement the guidelines specified at Point b, Clause 1 of this Article to the
point of time of issuance of the Circular amended and supplemented
Article 114. Effect
1. This Circular takes effect on March 25, 2013
and supersedes Circular No. 18/2010/TT-BCT dated May 10, 2010 of the Minister
of Industry and Trade stipulating the operation of competitive generation market
and Circular 45/2011/TT-BCT dated December 30, 2011, amending and supplementing
a number of Article of Circular No. 18/2010/TT-BCT 10 dated May 10, 2010 of the
Minister of Industry and Trade stipulating the operation of competitive generation
market and the guiding and directing documents issued by the Ministry of
Industry and Trade to implement Circular 18/2010/TT-BCT May 10, 2010 of the
Minister of Industry and Trade stipulating the operation of competitive generation
markets and Circular 45/2011/TT-BCT dated December 30, 2011, amending and
supplementing a number of Article of Circular No. 18/2010/TT-BCT dated May 10,
2010 of the Minister of Industry and Trade stipulating the operation of
competitive generation market
2. Director of Department electricity
regulation, Chief of Ministerial office, Ministerial Chief Inspector, Directors
of Departments, Director of the General Department of Energy, heads of units
concerned of the Ministry of Industry and Trade and organizations and
individuals are liable to execute this Circular
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