GRID CODE AMENDMENTS
Grid Code Amendments are proposed by KOSTT and approved by ERO on 14 January 2008,
by Decision nr. 75.
Based on afore mentioned Grid Code is amended as follows:
a) Connection Code
Article 6.1.1.2 with content:
6.1.1.2 The TSMO will with the user's agreement prepare a responsibility schedule and an
operational diagram showing the agreed ownership boundary. The TSMO and the user
will retain copies of these documents. Changes in the boundary arrangements proposed
by either party must be agreed in advance and will be recorded on the appropriate
operational diagrams.
Is amended with following content:
6.1.1.2 The TSMO will with the user's agreement prepare a responsibility schedule and an
operational diagram showing the agreed ownership boundary. The TSMO and the user
will retain copies of these documents. Changes in the boundary arrangements proposed
by either party must be agreed in advance and will be recorded on the appropriate
operational diagrams after agreement by the regulator.
Articles 7.3.12.1 and 7.3.12.2 with content:
7.3.12.1
Generating units of thermal power plants of above [20]MW capacity must be
equipped with a system to separate the unit including the supply of house-load system
from the system in case of frequency excursions due to emergency conditions.
7.3.12.2
The system for separation of units from the system must provide for adjustment of
frequency within the range of 46 to 50Hz and in terms of time within the range of
zero to three seconds
Grid Code Amendments
Are amended with following content:
7.3.12.1 Generating units of thermal power plants of above the capacity determined by the
UCTE formula must be equipped with a system to separate the unit including the
supply of house-load system from the network in case of frequency excursions due to
emergency conditions.
7.3.12.2 The system for separation of units from the network must provide for adjustment of
frequency within the range of 47.5 to 50 Hz and in terms of time within the range of
zero to three seconds.
Article 7.4 with content as follows:
7.4
Additional Requirements for Generators
7.4.1
General
7.4.1.1 Generators shall operate and maintain their generating unit’s voltage control facilities,
their generating unit’s frequency control facilities and the reactive power control of
the system interconnection facilities, in strict adherence to this grid code and
instructions received from the TSMO for the operation and security of the
transmission system.
7.4.1.2 Each generating unit must be capable of continuously supplying its registered output
within the system frequency range 50 ± [0.5] Hz. Any decrease of output power
occurring in the frequency range [48.5 to 51.5] Hz, should not be more than pro rata
with frequency.
Grid Code Amendments
Units connected on
Units connected on
110 kV
220 and 380 kV
Voltage(%
(%of
ofnominal
nominalVoltage)
Voltage)
Voltage
110%
105%
Frequency(Hz)
(Hz)
Frequency
48.5
48.5
decrease of output power
should not be more than pro
rata with frequency.decrease of output power
should not be more than pro
rata with frequency.
49.5
50.5
49.5
51.5
50.5
51.5
95%
Continuously
supplying its
registered output90%
gWhen a generating unit becomes isolated from the rest of
gWhen a generating unit becomes isolated from the rest of
the total system but is still supplying Customers, the speed
the total system but is still supplying Customers, the speed
governor must also be ableto respond to a system frequency
governor must also be ableto respond to a system frequency
between 47.5 and 52 Hz unless this causes it to operate
between 47.5 and 52 Hz unless this causes it to operate
below its designed Minimum Operating Level, when it is
below its designed Minimum Operating Level, when it is
possible that it may trip after a time.
possible that it may trip after a time.
decrease of output power
should not be more than pro
rata with frequency.
Continuously
supplying its
registered output
decrease of output power
should not be more than pro
rata with frequency.
7.4.1.3 Each generating unit directly connected to the transmission system should not have
its active power output affected by voltage changes in the normal operating range
specified in the voltage control code.
7.4.1.4 Each generating unit must, as a minimum, be capable of supplying rated active
power output (MW) at any point between the limits [0.85] power factor lagging and
[0.95] power factor leading at the generating unit terminals. The short circuit ratio of
generating units shall be not less than 0.5 and the generator must be able to satisfy
the TSMO that his plant will be stable for all credible fault situations.
7.4.1.5 The output voltage limits of generating units must not cause excessive voltage
excursions in excess of ±10% of nominal. The voltage regulating equipment shall be
able to maintain the output voltage level of the associated generating unit.
7.4.1.6 The speed governor of each generating unit must be capable of operating within the
generating unit’s technical limits and in a frequency range defined in paragraph
7.4.1.2.
7.4.1.7 The speed governor in co-ordination with other control devices must control the
generating unit active power output with stability over the entire operating range of
the generating unit and must meet the minimum requirements detailed in the
following.
Grid Code Amendments
7.4.1.8 Each generating unit with a registered capacity of at least [10MW] must be fitted with
suitable equipment to receive LFC signals from the associated TSMO control feature.
The TSMO will determine the selection and use of this function to ensure the overall
Kosovan Power System meets the requirements of the UCTE rules and standards as set
out under the frequency control code (with the balancing code).
7.4.1.9 The LFC system signalling criteria are as follows:

Accuracy 0.5 to 1.5% for active power measurement;

Accuracy 1.5 mHz for frequency measurement;

Regulation update time up to and including [two] seconds;

Associated with the above the TSMO SCADA/EMS system will continuously display
the active power output, higher and lower operating limits and run up / run down
rates:
7.4.1.10 Where a generating unit becomes isolated from the rest of the total system but is still
supplying Customers, the speed governor must also be able to respond to a system
frequency between 47.5 and 52 Hz unless this causes it to operate below its designed
Minimum Operating Level, when it is possible that it may trip after a time.
7.4.1.11 All Gensets with a registered capacity of [10MW] or more must have the capability to
provide primary control (with the response timing and duration set out in the
frequency control code subject to the following minimum requirements:

The control band of the speed governor must be at least [+/-2%] of the generating
unit’s registered capacity, and must be adjustable on instruction by the TSMO;

The speed governor must be capable of being adjusted, on instruction by the TSMO,
so that it operates with an overall speed droop of between 3% and 4%, in case of hydro
generating units, and between 4% and 6% in the case of thermal generating units;

The speed governor insensitivity shall be no greater than +10 mHz;
7.4.1.12 All generating units with a registered capacity of at least [10MW] must have the
capability to provide secondary control, with the response timing and duration set out
in the frequency control code (within the balancing code).
7.4.1.13 A continuous-acting automatic excitation control system, including power system
stabiliser where in the TSMO’s opinion they are required for system reasons, is
required to provide constant terminal voltage control of the generating unit without
instability over the entire operating range of the generating unit.
7.4.1.14 Hydro power plants with a generating unit of registered capacity of at least [10MW]
shall, if stipulated by the TSMO, provide a black start capability. All generating units
Grid Code Amendments
with an approved black start capability will be made available under the terms of an
ancillary services agreement, and meet the operational requirements set out in the
contingency planning code.
7.4.2
Loss of Synchronism Protection
7.4.2.1 Synchronous units, which are registered by the manufacturer to be capable of
asynchronous operation (with or without excitation), shall be tested for stability at the
point of their connection to the transmission system.
7.4.2.2 In the cases when asynchronous operation is not permitted in terms of stability, the
generating units must be equipped with protection against asynchronous operation if
they become disconnected from the system.
Is amended with following content:
7.4
Additional Requirements for Generators
7.4.1
General
7.4.1.1
Generators shall operate and maintain their generating unit’s voltage control
facilities, their generating unit’s frequency control facilities and the reactive power
control of the network interconnection facilities, in strict adherence to this grid
code and instructions received from the TSMO for the operation and security of
the transmission network.
7.4.1.2
Each generating unit must be capable of continuously supplying its registered
output within the system frequency range 50 ± [0.5] Hz. Any decrease of output
power occurring in the frequency range [48.5 to 51.5] Hz, should not be more than
pro rata with frequency.
Grid Code Amendments
Units connected on
110 kV
Voltage (% of nominal Voltage)
110%
Frequency (Hz)
48.5
49.5
50.5
51.5
decrease of output power
should not be more than pro
rata with frequency.
90%
gWhen a generating unit becomes isolated from the rest of
the total system but is still supplying Customers, the speed
governor must also be ableto respond to a system frequency
between 47.5 and 52 Hz unless this causes it to operate
below its designed Minimum Operating Level, when it is
possible that it may trip after a time.
Units connected on
220 and 380 kV
Continuously
supplying its
registered output
decrease of output power
should not be more than pro
rata with frequency.
Voltage (% of nominal Voltage)
105%
Frequency (Hz)
48.5
49.5
50.5
51.5
95%
decrease of output power
should not be more than pro
rata with frequency.
Continuously
supplying its
registered output
gWhen a generating unit becomes isolated from the rest of
the total system but is still supplying Customers, the speed
governor must also be ableto respond to a system frequency
between 47.5 and 52 Hz unless this causes it to operate
below its designed Minimum Operating Level, when it is
possible that it may trip after a time.
Grid Code Amendments
decrease of output power
should not be more than pro
rata with frequency.
7.4.1.3
Each generating unit directly connected to the transmission system should not
have its active power output affected by voltage changes in the normal operating
range specified in the voltage control code.
7.4.1.4
Each generating unit must, as a minimum, be capable of supplying rated active
power output (MW) at any point between the limits [0.85] power factor lagging and
[0.95] power factor leading at the generating unit terminals. Each asynchronous
generating unit must be compensated so as to supply reactive power output at the
connection point such that the power factor is between 0.9 lag and 0.95 lead.
7.4.1.5
The reactive power output under steady state conditions should be fully available
within the voltage range of ± [5]% at 400, 220 and 110 kV.
7.4.1.6
The supply generated must have balanced phase voltages with harmonic distortion of
no greater than [2%].
7.4.1.7
Each generating unit and the power plant in which is located must be capable of
continuous uninterrupted operation during the occurrence of the following:

Overspeed up to 110%;

Unbalanced load 5 – 10%;

Exciter response ratio more than 0.5%;

Negative phase sequence current up to 5%:
7.4.2
Active Power Control
7.4.2.1
All synchronous gas turbines and hydro generating units of capacity over [1] MW
and turbo generating units of over [5] MW must be equipped with turbine speed
and active power automatic control systems
7.4.2.2
The speed governor of each generating unit must be capable of operating within
the generating unit’s technical limits and in a frequency range defined in paragraph
7.4.1.2.
7.4.2.3
The speed governor in co-ordination with other control devices must control the
generating unit active power output with stability over the entire operating range of
the generating unit and must be able to maintain the set active power of the
generating unit with accuracy as follows:

For units of up to 20 MW - not less than  2% of rated power;

For units above 20 MW - not less than  1% of rated power:
Grid Code Amendments
7.4.2.4
Turbine speed governors must be capable of equalising the speed (frequency) of the
synchronous set with the frequency of the transmission system prior to connection
of the generating unit in parallel with an accuracy of at least  0.1%.
7.4.2.5
Automatic speed and power control systems for turbines rated over [10] MW shall
be transformed from ‘power control’ mode to ‘speed control’ mode by rejection of
the nominal load of the turbine by the action of the overspeed protection.
7.4.2.6
Turbine automatic speed control systems must provide for limitation and protection
against overspeed of the synchronous set and adjustment within a range as follows:

For steam turbines - 104 to 112% of their nominal value;

For hydro and gas turbines - 104 to 130% of their nominal value:
7.4.2.7
Each generating unit with a registered capacity of at least [10MW] must be fitted
with suitable equipment to receive LFC signals from the associated TSMO control
feature. The TSMO will determine the selection and use of this function to ensure
the overall Kosovan Power System meets the requirements of the UCTE rules and
standards as set out under the frequency control code (within the balancing
code).
7.4.2.8
The LFC system signalling criteria are as follows:

Accuracy 0.5 to 1.5% for active power measurement;

Accuracy 1.5 mHz for frequency measurement;

Regulation update time no more than [two] seconds;

Associated with the above the TSMO SCADA/EMS system will continuously
display the active power output, higher and lower operating limits and run up /
run down rates:
7.4.2.9
Where a generating unit becomes isolated from the rest of the total system but is
still supplying Customers, the speed governor must also be able to respond to a
system frequency between [47.5] and [52] Hz unless this causes it to operate below
its designed minimum operating level, when it is possible that it may trip after a time.
7.4.2.10
All gensets with a registered capacity of [10MW] or more must have the capability
to provide primary control (with the response timing and duration set out in the
frequency control code subject to the following minimum requirements:

The control band of the speed governor must be at least [+/-2%] of the generating
unit’s registered capacity, and must be adjustable on instruction by the TSMO;
Grid Code Amendments

The speed governor must be capable of being adjusted, on instruction by the
TSMO, so that it operates with an overall speed droop of between 3% and 4%, in
case of hydro generating units, and between 4% and 6% in the case of thermal
generating units;

The speed governor insensitivity shall be no greater than +10 mHz;
7.4.2.11 All generating units with a registered capacity of at least [10MW] must have the
capability to provide secondary control, with the response timing and duration set out
in the frequency control code (within the balancing code).
7.4.3
Blackstart and Island Operation:
7.4.3.1
Hydro power plants with a generating unit of registered capacity of at least [10MW]
shall, if stipulated by the TSMO, provide a black start capability. All generating units
with an approved black start capability will be made available under the terms of an
ancillary services agreement, and meet the operational requirements set out in the
contingency planning code.
7.4.3.2
Turbine speed governors of generating units involved in system restoration after
major system failures (hydro and gas turbines) shall be able to operate with an isolated
load (island mode) in which case regulation will take place after altering the droop
characteristic to insensitive mode. Transition of regulation modes shall take place as
required by the prevailing operational circumstances.
7.4.3.3
7.4.4

by criteria built into the governor - upper and lower limit of frequency, rate of
change in frequency or loading;

by the power plant operator using a control switch;

remotely - by means of a telesignal from the dispatch centre dependent on the
condition of the switchgear:
Turbine speed governors of units involved in the power system restoration after major
system failures shall be able to start rotating initially and reach synchronous speed and
be loaded in the absence of an external ac supply.
Excitation Systems
7.4.4.1
Each generating unit must be capable of contributing to voltage control by
continuous modulation of reactive power supplied to the transmission network.
7.4.4.2
Each generating unit must be fitted with a continuously acting automatic excitation
control system that may include stabilisers, to provide constant terminal voltage of the
generating unit, without instability over the entire operating range of the generating
unit.
Grid Code Amendments
7.4.4.3
The output voltage limits of generating units must not cause excessive voltage
excursions in excess of ±10% of nominal. The voltage regulating equipment shall be
able to maintain the output voltage level of the associated generating unit.
7.4.4.4
The excitation system must provide for increase (forcing) in the excitation current and
voltage of a synchronous generating unit as a factor at nominal load as follows:

hydro generating units up to 25 MVA - min factor (ratio) 1.5 - min time 10s;

hydro generating units above 25 MVA - min factor 1.8 - min time 20s;

turbo generating units of up to 25 MVA - min factor 1.8 - min time 10s;

turbo generating units above 25 MVA - min factor 2.0 - min time 30s:
7.4.4.5 The forcing parameters must be achieved at a generating unit terminal voltage within
the range of [80% to 120%] of the nominal voltage and at a frequency range of [47.5Hz
to 52Hz].
7.4.4.6 The speed of change in the exciting voltage of the synchronous generating unit shall
not be lower than [2] relative units/sec using as reference the exciting voltage under
nominal load of the synchronous generating unit.
7.4.4.7 All synchronous generating units of capacity over [1] MVA must be equipped with an
automatic voltage regulator (AVR).
7.4.4.8 AVRs shall be capable of maintaining the voltage at the generating unit terminals
with an accuracy as follows:

for generating units of up to 25 MVA - not less than  1% of rated voltage;

for generating units above 25 MVA - not less than  0.5% of rated voltage:
7.4.4.9 AVRs must compensate for any drops in the voltage of the Unit Transformer as well as
provide a stable distribution of reactive power between the synchronous generating
units connected to common busbars.
7.4.4.10 AVRs must provide for limitation of the following:

Minimum excitation;

Rotor maximum current;

Synchronous generating unit stator maximum reactive current:
7.4.4.11 The excitation systems of generating units involved in the restoration of the
transmission network after severe system incidents, shall be able to regulate the
excitation of the generating unit in the absence of an external ac supply.
Grid Code Amendments
7.4.5
Loss of Synchronism Protection
7.4.5.1 Synchronous units, which are registered by the manufacturer to be capable of
asynchronous operation (with or without excitation), shall be tested for stability at the
point of their connection to the transmission network.
7.4.5.2 In the cases when asynchronous operation is not permitted in terms of stability, the
generating units must be equipped with protection against asynchronous operation if
they become disconnected from the network.
7.4.6
Plant Subject to Central Dispatch
All eligible generating units must be fitted with LFC and a power system stabiliser.
The requirements for these will be as determined by the TSMO
b) Planning Code
After Article 5.3.1.3 to be inserted Article 5.3.1.4 with this contents:
5.3.1.4 The TNDP shall include information on transmission related projects where this
information is available and is not subject to confidentiality restrictions. This will
include details of the project including progress against plan.
Article 5.4.1.1 with content:
Neni 5.4.1.1 The TSMO shall be responsible for the preparation of the final version of the
TNDP but the TSMO shall take into consideration the needs of the other
parties involved. The final version of the TNDP shall be submitted to the
Regulator for approval.
Is amended with this content as follows:
5.4.1.1 The TSMO shall be responsible for the preparation of the TNDP but the TSMO shall
take into consideration the needs of the other parties involved. The draft version of the
TNDP shall be submitted to the regulator by the end of [October] for consideration
and review. The comments from the regulator will be submitted by the end of
[November] and once agreement is reached between the regulator and the TSMO, the
TSMO shall prepare the final version of the TNDP and submit it to the regulator for
final approval.
Grid Code Amendments
c) Operation Code
Article 4.5.1.1 with content:
4.5.1.1
The organisation of safe operations for both work and testing, with respect to HV
equipment, for the Kosovan transmission system shall comply with (SCOEI).
SCOEI shall be complied with by the TSMO and all users operating on the Kosovan
transmission system
Is amended with following content:
4.5.1.1 The organisation of safe operations for both work and testing, with respect to HV
equipment, for the Kosovan transmission system shall comply with the relevant
Kosovan Laws and rules. These shall be complied with by the TSMO and all users
operating on the Kosovan transmission system.
Is inserted Article 5.5.3.7 with this content:
5.5.3.7 Data from international cross border lines and other lines within connected states should
be made available via the terms of the interconnection agreements.
Article 6.5.3.2 with content:
6.5.3.2 With regard to the load disconnection the DSO will be responsible for the detailed
arrangements and for load grouping but should take account of any customer priority
categories.
Is amended with following content:
6.5.3.2 With regard to the load disconnection the DSO will be responsible for the detailed
arrangements and for load grouping but should take account of any customer priority
categories. The final schedule should be agreed with the regulator.
Grid Code Amendments